Document v7naMo6QMjYqNQkVpZ2z8K3b

EPA Inspection Report - Page 1 of 1969 EPA Inspection Report - Page 2 of 1969 Section I - INTRODUCTION PURPOSE OF THE INSPECTION Environmental Protection Agency (EPA) Region 6 inspectors Debbie Ford and James Haynes, Environmental Resources Group (ERG) contractor for EPA Dan Roper, and New Mexico Environment Department (NMED) Air Quality Bureau staff Cindy Hollenberg, Kate Hauer, and Sherry Bell arrived at the HollyFrontier Navajo Refining LLC (HollyFrontier) / Artesia Refinery (facility or Artesia) at 8:00 a.m. on October 1, 2019 for an unannounced inspection. There was confusion at the main gate about the requirements for our entry. Inspectors initially were instructed to take computer training and testing, but when Mr. Denton was reached, he instructed the group to enter at the Administration Office where the environmental staff were located. We were not instructed to watch a safety video for the facility (see AOC # ). We were accompanied by facility personnel when we were onsite. At 9:10 a.m. we met with Mr. Denton, Artesia Environmental Manager, and Mr. Smalts, Artesia Environmental Specialist, for the opening conference. EPA and ERG inspectors presented their credentials to Mr. Denton. I informed Mr. Denton and Mr. Smalts that this was an EPA inspection triggered by the elevated benzene levels detected by the fenceline monitoring (FLM) required by National Emission Standards for Hazardous Air Pollutants (NESHAP) Subpart CC. The purpose of the inspection was to determine compliance with the facility's Title V Air Permit and the Clean Air Act (CAA), which is authorized under Section 114(a) of the CAA. The scope of the inspection is a partial compliance evaluation (PCE) and includes an evaluation of the compliance of the facility with applicable New Source Performance Standards (NSPS), National Emission Standards for Hazardous Air Pollutants (NESHAP), and NMED regulations in the State Implementation Plan (SIP). On Thursday, October 3, EPA's National Enforcement Investigations Center (NEIC) inspectors Martha Hamre and Richard Helmich, arrived at the facility with the NEIC Geospatial Measurement of Air Pollutants (GMAP) vehicle. After presenting their credentials to Mr. Denton, Ms. Hamre and Mr. Helmich, accompanied by a HollyFrontier employee, began surveying within the refinery boundaries and the nearby community to identify sources of emissions. They continued throughout Thursday and until noon on Friday collecting meteorological and emission data with the GMAP as well as several canisters for analysis by the NEIC laboratory. The NEIC report of monitoring activities and results of canister sampling is separate from this report. During the inspection we took photographs using Nikon COOLPIX AW120 digital cameras and videos using FLIR Systems GF320 infrared cameras. The FLIR GF320 infrared camera is designed to visually detect hydrocarbons in the infrared spectrum that are typically emitted by facilities such as refineries, oil and gas sites, and other similar industries. At the end of the inspection, we shared copies with HollyFrontier of all videos and photographs taken. EPA Inspection Report - Page 3 of 1969 FACILITY DESCRIPTION The Artesia Refinery is owned by HollyFrontier Navajo Refining LLC. It began operation as the Navajo Refining Company in the 1930s by Continental Oil Company. Holly purchased the facility in 1969. Holly merged with Frontier in 2013 to create HollyFrontier Corporation, of which HollyFrontier Navajo Refining LLC is a subsidiary. The facility is a 40,000 barrels per day (bpd), fully-integrated petroleum refinery with crude distillation, vacuum distillation, Fluidized Catalytic Cracking (FCC), solvent deasphalter, hydrofluoric acid alkylation, catalytic reforming, hydrodesulfurization, isomerization, sulfur recovery, and product blending units. The Artesia Refinery receives crude oil via truck and pipeline. The facility has approximately 300 employees and averages 150 contractors per day. Although separate facilities, HollyFrontier considers the Lovington Refinery (Lovington), located approximately 70 miles from Artesia, to be a part of the Artesia Refinery. Lovington uses a crude distillation unit and associated vacuum distillation units to process approximately 74,000 bpd of crude into intermediates which are transported to Artesia via pipeline. Vacuum bottoms are transported to Artesia via tank truck. The combined capacity is 110,000 bpd. The Artesia refinery is a major source of hazardous air pollutants (HAPs) as well as a major source for volatile organic compounds (VOCs). As a major source, it is required to operate under a CAA Title V operating permit. The current New Source Review operating permit for the facility is PSD-NM-0195M37 issued August 12, 2016 and the current Title V operating permit is P051-R2M1 issued January 22, 2016. P051-R2M1 is an Administrative Amendment to P051-R2 for a name change of the company. The full Title V Permit with applicable conditions is P051-R2 issued May 6, 2015. The facility also has an active Consent Decree CIV-01 1422LH that was entered March 5, 2002 under EPA's Refinery Consent Decree Initiative https://www.epa.gov/enforcement/petroleum-refinery-national-case-results. NESHAP Subpart CC Fenceline Monitoring Program for Benzene Emissions NESHAP Subpart CC requires biweekly sampling of benzene using passive monitors at fenceline sampling points. NESHAP Subpart CC also requires that the facility collect meteorological data to help determine sources of any elevated emissions detected by the fenceline monitors. After twenty-six (26) 2-week periods, Subpart CC requires the facility to calculate an annual average benzene concentration (c) and compare the results to the action level of 9 g/m3. Artesia began the required FLM program January 30, 2018 and have 19 sampling locations (see Appendix 9, page 5). Prior to the start of the required monitoring, Artesia began 2-week sampling on October 4, 2016 (beginning date of the sampling period). Artesia reported that the initial annual average c was 290 g/m3, which was the highest reported concentration in the nation. HollyFrontier submitted the May 15, 2019 Corrective Action Plan (see Appendix 9) required by 40 C.F.R. 63.658(h) to report the actions taken by the facility to determine the root cause of elevated benzene readings and the actions taken to address them. HollyFrontier submitted Amended Corrective Action EPA Inspection Report - Page 4 of 1969 Plans on July 3, 2019, September 3, 2019, and October 11, 2019 (see Appendices 10-12). The Corrective Action Plans detailed the use of temporary samplers and FLIR infrared camera to determine the source(s) of the elevated benzene emissions. HollyFrontier identified external floating roof (EFR) tanks T57, T-401, and T-450 as contributors to elevated benzene readings; in response, in December 2017, Artesia installed socks on the legs and vacuum breakers. The socks seemed effective for T-401 and T450, but not Tank-57. The refinery installed a more effective sock for the vacuum breaker of T-57 in July 2018. HollyFrontier also identified plugged tubes in a heat exchanger that is used to cool naphtha going to T-57. The heat exchanger should cool the material to 80oF, but HollyFrontier reported the temperature of the naphtha was 100oF going into T-57. HollyFrontier also reported T-11 maintenance activities and a T-106 overflow and damage as contributors to elevated benzene. Section II - OBSERVATIONS Mr. Denton stated that the facility has seven employees on the environmental staff. Currently, he said there are two employees who manage the air requirements: Ray Smalts and Staci Hammond. There was also one open position. Applicability and Inspections of Storage Vessels I asked about the inspections performed on the EFR and internal floating roof (IFR) tank and what regulations the facility is complying with for Group 1 storage vessels since the operating permit only stated that the tanks were subject to NESHAP Subpart CC. The original NESHAP Subpart CC Storage Vessel Provisions at 40 C.F.R. 63.646 required compliance with the Hazardous Organic NESHAP (HON) tank requirements in NESHAP Subpart G. In 2015 NESHAP Subpart CC added new Storage Vessel Provisions at 40 C.F.R. 63.660 which have different breakdowns of tank size, vapor pressure, and HAP content for identifying tanks as Group 1 or Group 2 and require compliance with NESHAP Subpart WW. Table 11 in Subpart CC provides which requirements apply to new or existing tanks. The table provides for transitioning to Subpart WW for existing tanks. Mr. Smalts stated that they are following NESHAP Subpart WW. I asked how long the facility had been following Subpart WW and he replied, "Forever." He provided his book of Tank Applicability (see CBI Appendix A) which Mr. Smalts stated that he worked with a consultant to develop. I reviewed the details of the tanks, and it appears that the current applicability is based upon the 2015 changes to Subpart CC. Mr. Omar Dominquez from the Inspections Department at Artesia performs tank inspections which include the rooftop inspections for IFR tanks, primary and secondary seal gap measurements for EFR tanks, as well as the out-of-service inspections required for IFR tanks and the API 653 inspections required for IFR and EFR tanks. Mr. Dominguez keeps a spreadsheet to track when each inspection is due. The regulations (NSPS Subpart Kb, NESHAP Subpart G, and NESHAP Subpart WW) require that notification be made at least 30 days prior to the NSPS and NESHAP inspections to allow the regulatory EPA Inspection Report - Page 5 of 1969 agency to have an observer present. Artesia submits a schedule in December each year for the following year's inspections. Artesia sent NMED the 2019 schedule in a letter dated December 12, 2018 (see Appendix 15). The letter begins by referencing the HON (40 C.F.R. 63.120(b)(9)), "as applicable to Group 1 storage vessels subject to 40 C.F.R. 63.660 (MACT Subpart CC storage vessel provisions)." EPA modified NESHAP Subpart CC in 2015. There are now two (2) sections for "storage vessel provisions": 40 C.F.R. 63.646 which requires Group 1 tanks to follow the HON 40 C.F.R. 63.660, which requires Group 1 tanks to comply with NEHAP Subpart WW if the Max TVP < 11.1 psia, or SS if the Max TVP 11.1 psia. The definition of Group 1 tanks in NESHAP Subpart CC changed with the 2015 revision to the rule. Prior to February 1, 2016, the old Group 1 definition applied. On or after February 1, 2016, the new definition applies. NESHAP Subpart CC transitions tanks from complying with the HON to WW or SS as they are emptied and degassed or by January 30, 2026, whichever occurs first. The regulations require the use of probes to determine the width of gaps between the primary or secondary seal and the wall of the tank: NSPS Subpart Kb and NESHAP Subpart G describe the measurement tool as a 1/8" uniform probe that identifies a measurable gap, and the use of varying width probes to calculate the area of the gap and to determine if any width exceeds 1/2" for secondary seals or 1.5" for primary seals. NESHAP Subpart WW describes the measurement tools as 1/8" probe and additional probes at 1/8" increments. The maximum widths are the same as for NSPS Subpart Kb and NESHAP Subpart G. Mr. Dominguez informed us that he uses a 1/8" metal rod (carbon steel) initially. The other probes he uses are wooden dowels in 1/16" increments from 3/16" to 1/2" (3/16", 1/4", 5/16", 3/8", 7/16", 1/2"). For primary seals greater than 1/2", he uses a tape measure to determine the gap width (see AOC #23). The methodology for calculating the seal gap areas is also different from NSPS Subpart Kb or NESHAP Subpart G compared NESHAP Subpart WW. Under NSPS Subpart Kb and the HON, a gap area is the sum of a series of smaller gaps of varying widths (e.g. a gap may have 1/8" gaps at the edges, 1/4", 3/8", or 1/2" in the middle of a single long gap. Each segment is documented, and the areas of each of the segments are summed. Under NESHAP Subpart WW, the smallest and the largest gap width is determined within the single gap. The average of the 2 widths is then multiplied by the total gap length to determine the gap area. When Mr. Dominguez performs his inspections, he keeps notes in a notepad that he carries with him. He uses the notepad to prepare the inspection report that is submitted as part of the NESHAP Subpart CC Reports. The inspection reports do not specify which regulation is applicable for the tank. Mr. Dominguez categorizes gap shapes as triangular (T) or square (S) when he performs primary and secondary seal gap measurements. If the shape is a square, he calculates the area of the gap = length (L) X width (W). If the shape is a triangle, he calculates area of the gap =[ length (L) X width (W) ] / 2 (see AOC # 1). EPA Inspection Report - Page 6 of 1969 Facility Tour We toured the various tank areas at the facility (for Appendices 4-8 - green tanks are EFR tanks and yellow tanks are IFR tanks. Tanks with no color are fixed roof or pressure tanks). West Tank Area (see Appendix 4) North Center (Wastewater) Area (see Appendix 5) East Tank Area (see Appendix 6) South Tank Area (see Appendix 7) Center Tank Area (see Appendix 8) James observed tanks and other equipment with the FLIR infrared GF320 camera to determine if any visible hydrocarbon emissions could be detected, which could indicate potential benzene sources. If he observed emissions, he recorded his observations. Below is a cross-reference table of location area, equipment, photos, and videos: Table 1 - Cross-reference Table Area West Tank West Tank West Tank North Center North Center North Center North Center North Center North Center North Center East Tank East Tank East Tank East Tank East Tank East Tank East Tank East Tank East Tank East Tank South Tank South Tank South Tank South Tank Equipment T-57 Control Room (for T-57 feed) T-737 SRU #2 DOR component 2720 API Separator Carbon Canisters Sump Lift Station (near API Separator) Bundle Cleaning Area New Sump New Carbon Canisters T-49 FLM Sample Pt. 7 T-11 T-12 T-108 T-109 T-401 T-401 Base #3 Blending Pit T-415 T-437 T-1225 T-124 T-417 T-431 T-432 Tank Type EFR Permitted Contents* Naphtha EFR Sour Water Wastewater Wastewater Wastewater Wastewater Fixed Slop oil IFR Gasolines IFR Gasolines IFR Gasolines IFR Gasolines EFR Gasolines EFR IFR EFR EFR IFR IFR Fixed Fixed Gasolines Crude Oil Naphtha Gasolines Gasolines Distillates Distillates Capacity (barrels) 50,400 Photo # 1-6 23 20,000 63-66 60-62 19-22 20, 67-69 70-71 667 32,600 32,300 22,900 22,300 53,000 29,900 85,000 100,000 6,200 9,300 56,500 55,000 76 72, 74 73, 75 16-18 24-25 26-28, 31 26, 29, 30 32, 35 34, 36 37-42 56-59 43-44 33 46 45-51 15 14, 55 52 53 Video # 32 2-7 33-34 35-36 8 9 10, 13 12 14-19 28-31 11 20-22 1 27 23 24-25 EPA Inspection Report - Page 7 of 1969 Area South Tank Equipment T-434 Y-11 Cooling Tower Tank Type Fixed Permitted Contents* Distillates Capacity (barrels) 78,400 Photo # 54 7-13 Video # 26 *HollyFrontier provided a Tank List with actual contents at the time of the inspection (see CBI Appendix B). T-57 Tank T-57 tank was originally built in 1955. HollyFrontier replaced the floating roof and put the tank into light naphtha service on February 12, 2012. HollyFrontier provided the construction drawings for the new floating roof (see CBI Appendix C) which had the latest revision date of October 25, 2011. The drawings included the primary mechanical shoe seal but did not include the secondary seal that the tank currently has installed (see AOC # 2). At the time of the inspection, I observed that the tank level was 8' - 9/16". James noted the vacuum breaker sock that was installed to control benzene emissions was damaged (see Appendix 1, photo 2). During the September 9, 2019 call with HollyFrontier, I asked at what level does the vacuum breaker engage or open on T-57. HollyFrontier stated that the vacuum breaker opens at 8.5 feet. The drawings for the T-57 bleeder vent, aka vacuum breaker, requires a 12-foot pipe and a notation to "field determine" the length (see CBI Appendix C, pg 7 - Drawing 8) (see AOC # 3). T-737 Tank T-737 was out of service (OOS) at the time of the inspection. The EFR tank is a sour water tank that was constructed in 2009 and according to the Tank Applicability book, the tank is a Group 2 tank under NESHAP Subpart CC. As a new tank, for overlapping regulations with NESHAP Subpart CC and NSPS Subpart Kb, the facility should follow NSPS Subpart Kb regulations. The annual secondary seal gap measurements have two criteria that must be met for the tank to pass inspection: 1) the accumulated gap area shall not exceed 1 in2/foot of tank diameter and 2) no single gap width shall exceed 1/2". For primary seal gap measurements, 1) the accumulated gap area shall not exceed 10 in2/foot of tank diameter, 2) no tears or holes in the primary seal fabric, and 3) no single gap width shall exceed 1.5". If a seal inspection fails to meet these criteria, the company is required to submit a report within 30 days of the inspection and provide specific information about the seal inspection in the report. The company is to make the repairs or empty the tank within 45 days of the inspection. If the repairs cannot be made within the 45 days, a 30-day extension may be requested if there is no alternate tank space available. T-737 was the subject of additional FLM sampling (Temporary Sampler TS8 in September 2017) to determine the source of the benzene at nearby sample points. Artesia determined that T-57 was likely the source of the benzene due to the predominant wind direction during the sample period. HollyFrontier provided the following inspection documents for T-737 (see CBI Appendix M): January 30, 2019 - EPA Inspection Report - Page 8 of 1969 March 27, 2019 - July 9, 2019 - . The Corrective Action Plan Amendment dated July 3, 2019 (see Appendix 10) stated that on "March 18, 2019, during routine tank inspections, Navajo identified that Tank 737 (sour water tank) has a damaged seal that may be contributing to detected benzene fenceline concentrations on the west side of the refinery." Artesia did not provide a report detailing the failed inspection within 30 days of the March 18, 2019 inspection as required by NSPS Subpart Kb (see AOC # 4). On July 16, 2019 Artesia provided a Notice of Seal Inspection and Refill (see Appendix 14) to NMED for Tanks T-106, T-107, T-451, and T-737. Artesia submitted the report of the failed inspection of T-737 beyond 30 days after the March 27, 2019 inspection (see AOC # 4). In the July 3, 2019 Corrective Action Plan Amendment, Artesia stated that cleaning and repair has required more than 45 days to complete. Artesia did not request a 30-day extension. Artesia's letter did not detail the exact date when the tank was emptied, but if the June 16, 2019 roof landing date is conservatively used as the emptied date, that is 90 days after the March 18, 2019 inspection (see AOC # 5). Leak Detection and Repair (LDAR) - Delay of Repair (DOR) Components We asked for the current DOR list (see Appendix 23). One of the components, a 3/4" valve (Unit 30, Tag # 2720) had been on the DOR list since May 13, 2009. Since the LDAR programs under the Refinery Consent Decree Initiative requires companies to continue to monitor DOR components, I asked for the monitoring history to review. The history for Unit 30's Tag # 2720 (see Appendix 24) noted that the valve has recorded readings as high as 127,700 ppm on July 26, 2017, and 500,000 ppm on April 20, 2018 (see AOC # 6). At the time of the inspection, James observed with the FLIR camera visible emissions from the plug (see Appendix 2 - Video 32, Appendix 1 - Photo 60-62). API Separator and Adjacent Sump Lift Station Artesia has an aboveground API separator (see Appendix 1 - Photos 19-22) in its wastewater unit that is comprised of a west separator tank (D-0829) and an east separator tank (D-0830) with a total capacity of 1,200 gallons/minute (gpm). The aboveground API Separator is subject to NSPS Subpart QQQ and emissions from the separator are permitted (see Appendix 13) to be controlled by a carbon canister system (D-808 and D-809) (see Appendix 1 - Photos 20, 67-69), referred to as the Old API Canisters by the facility. Under NSPS Subpart QQQ at 40 C.F.R. 60.692-3 Standards: Oil-Water Separators, each oil-water separator tank shall be equipped with a fixed roof installed to completely cover the separator tank. Roof seals, access door, and other opening shall be checked visually initially and semiannually thereafter to EPA Inspection Report - Page 9 of 1969 ensure no cracks or gaps occur and that access doors and other openings are closed and gasketed properly. Oil-water separator tanks with a design capacity to treat more than 250 gpm of refinery wastewater shall also be equipped and operated with a closed vent system and control device. Standards for closed vent systems and control devices, specified at 40 C.F.R. 60.692-5, state that the closed vent system shall be designed and operated with no detectible emissions, as indicated by an instrument reading of < 500 ppm above background, as determined during the initial and semiannual inspections using EPA Method 21. The standards also state that a flow indicator shall be installed on a vent stream to a control device to ensure that the vapors are being routed to the device. Monitoring for a carbon adsorber control using carbon canisters, as specified at 40 C.F.R. 60.695, requires the facility to monitor the exhaust vent stream on a regular basis to detect breakthrough. The API Separator roof has a gasket to seal the roof to the separator tank, and I observed that the clamps holding the roof were spaced closer together on the north end as compared to the south end. Using the FLIR infrared camera, James observed visible hydrocarbon emissions at several locations on both the west and east separator tanks of the API separator (see Appendix 2 - Videos 2-7). I asked Mr. Denton if they monitor the API Separator gasket under their LDAR program. He stated that they only inspect it for visible gaps as required by NSPS Subpart QQQ . Artesia uses their LDAR contractor, Dexter, to perform daily monitoring of the U.S. Filter Westates Carbon Canister system (or the Old API Canister system) to detect breakthrough. Artesia previously performed the monitoring weekly but increased the frequency to daily. We observed the Dexter contractor monitor the carbon canisters, beginning at the outlet of the second (or lag) canister, progressing to between the canisters, then to the inlet of the first (or lead) canister. The following are the results of the monitoring: Background Minimum: 4 ppm Maximum: 7 ppm Lead canister Inlet: 286 ppm Outlet: 4 ppm Lag canister Inlet: 4 ppm Outlet: 3 ppm I asked Mr. Smalts when the facility last changed out the carbon in the canisters and he replied, "Never." He said they had reviewed records and could not locate when Artesia had purchased carbon to replace the old carbon. I asked if they had flow through the system, and he replied that they must have since the numbers got lower from the inlet to the outlet. James asked the Dexter contractor to monitor the edge of the API roof where he had observed hydrocarbon emissions with the FLIR camera. Using the TVA monitoring instrument, Dexter measured a concentration of 1,300 ppm. I reviewed the P&ID drawings for the API Separator (see CBI Appendix N) to determine if Artesia had designed and operated the closed vent system with a flow indicator. I could not locate one on the vent line to the carbon canisters (see AOC # 7). Just north of the aboveground API Separator was a sump lift station. I observed a lot of sealant around each of the two access hatches (see Appendix 1 - Photos 70-71). James observed the hatches with the FLIR camera and saw visible hydrocarbon emissions (see Appendix 2 - Videos 33-34) (see AOC # 8). Bundle Cleaning Area EPA Inspection Report - Page 10 of 1969 We looked at the bundle cleaning area where heat exchanger tube bundles are cleaned. The area slopes and the water routes to the wastewater system. The vacuum trucks that collect spills throughout the facility empty their trucks at this area. We observed a lot of oil staining at the junction box adjacent to the cleaning area (see Appendix 1, Photo 76). New Stormwater Lift Station and Carbon Canister System The facility provided records of daily carbon canister monitoring (see Appendices 25-26), and the refinery is monitoring a second canister system (D-8000 and D-8001) (see Appendix 1 - Photos 73 and 75). Artesia said it was installed in approximately 2012 (see CBI Appendix O) to control emissions from the new stormwater lift station (T-0846) (see Appendix 1 - Photos 72 and 74). Artesia designed and installed the equipment as part of a project to separate stormwater and prevent wastewater upset, surge flows, and air emissions. The project does include an oil skimmer. The facility's current permit does not show the new carbon canister system which also appears to be subject to NSPS Subpart QQQ (see AOC # 9). James observed the hatches on the stormwater lift station with the FLIR camera and noted hydrocarbon emissions from two access hatches (see Appendix 2 - Videos 35-36) (see AOC # 8). When I asked when the carbon was last changed on the new system, Artesia representatives stated that since installation, they have not had breakthrough which would require replacement of the carbon. I reviewed the 2017-2019 daily monitoring data, and the inlet concentration was usually well below 50 ppm. In May 2018 (see Appendix 25) the concentration was 22,000 ppm and after that the concentration ranged typically from 2,000 to 6,000 ppm. In January 2019 (see Appendix 26), I noted a concentration of 37,916 ppm. In March 2019, I saw 20,100 ppm. The concentrations never returned to the pre-May 2018 levels. I later reviewed the P&ID for the new canister system (see CBI Appendix N) and could not locate a flow indicator as required by NSPS Subpart QQQ (see AOC # 7). T-49 Slop Oil Tank - NESHAP Subpart FF - Benzene Waste Organic NESHAP (BWON) Sampling I asked Artesia for the End of Line (EOL) Sampling Plan required by the BWON requirements under the 2002 Refinery Consent Decree. The facility provided the February 6, 2003 plan, to which EPA provided conditional approval in a letter dated January 23, 2004, and the March 31, 2004 plan (see Appendix 27), which has never been approved by EPA. The 2004 plan listed seven (7) sample points: Table 2 - EOL Sample Points Sample Point S-1 Description Oil from Surge Tank after Wastewater API S-2 Oil from Surge Tank after Alky API Consent Decree Reports* Artesia made changes to the wastewater system and the slop oil from the Alky API is diverted through the Wastewater API.** EPA Inspection Report - Page 11 of 1969 Sample Point S-3 S-4 S-5 S-6 S-7 Description Combined water lines from Wastewater and Alky API to Surge/Biological Treatment Tanks Sludge after Contractor Centrifuge/ Heating System - product is cement kiln fuel Aqueous waste from T-40 Caustic Tank Aqueous waste from T-41 Caustic Tank Skimmed hydrocarbon common line from T-40 and T-41 Caustic Tanks Consent Decree Reports* Artesia generated no sludge from 1Q 2016 - 1Q 2019 except for 4Q 2017 (see Appendix 30)*** Artesia has taken T-41 OOS permanently. Last sampling performed 5/9/2019 Samples have not been taken. Comments state that hydrocarbon layer was between the sample point draws on the tank. *Information on sampling is listed in Attachment 3 of the quarterly reports. The report generated for the 2Q 2019 (see Appendix 32) did not have the Attachment 3 included in the report. **At the time of the inspection, Mr. Denton stated that the facility no longer has an Alky API. ***Sample Point S-4 is for shipments of sludge after a contractor centrifuge/heating system. I requested the manifests for shipments for 2017 and 2018. Artesia provided a 15-page document (see Appendix 28) that detailed fifteen (15) shipments of sewer sludge to US Ecology in Robstown, TX from March 18, 2019 through May 15, 2019. Artesia did not provide a manifest for the generated sludge reported in the 4Q 2017 Consent Decree Report and did not include the EOL sampling records in the Consent Decree Quarterly Reports for 4Q 2017, 1Q 2019, and 2Q 2019 (see Appendices 30-32 respectively) (see AOC # 10). Artesia did not report any sludge waste for Sample Point S-4 in the 1Q 2019 Consent Decree Report (see Appendix 31), yet Artesia provided five manifests for March 2019. The calculation for Sample Point S-3 indicated the daily volume to the wastewater tanks was consistently 720,000 gal/day in every Consent Decree Quarterly Report since 1Q 2016 equivalent to 500 gpm. The wastewater system is rated at 1,200 gpm (see AOC # 11). We observed the NESHAP Subpart FF sampling that is performed at EOL Sampling Point S-3 which is the water phase from T-49 Slop Oil tank. T-49 receives material from two (2) sources: 1) oil from the aboveground API separator and 2) a stream that resulted from the 2012 improvements to the wastewater treatment system. Artesia uses a contractor, Aqua Microbics, for their NESHAP Subpart FF sampling. The Consent Decree (see Appendix 29) requires that if changes in processes, operations, or other factors lead Navajo (Artesia) to conclude that the sampling locations no longer provide an accurate measure of the EOL benzene quantity, the company shall submit a revised plan to EPA for approval. The wastewater improvements from 2012 were not a part of the original EOL Sampling Plan and Sample Point S-2 was EPA Inspection Report - Page 12 of 1969 modified. Artesia failed to submit a revised EOL Sampling Plan as required by the Consent Decree (see AOC # 21). Visible Hydrocarbon Emissions from Tanks Observed with FLIR Camera James noted visible hydrocarbon emissions when looking at the following tanks (refer to Table 1 for photos/videos): IFR tanks T-11, T-12, T-108, T-109, T-415, T-124, and T-417. o T-124 and T-417 have reported Maximum True Vapor Pressure (Max TVP) > 11.0 pounds per square inch absolute (psia). EFR tanks T-401, T-437, and T-1225. o T-401 and T-1225 had water on top of the floating roof. T-401's roof did not appear to be floating completely on the liquid surface. The roof was tilted approximately one foot out of level. Fixed Roof tanks T-431, T-432, T-434. o The Title V permit lists these tanks as storing low vapor pressure material. The presence of visible hydrocarbon emissions with the FLIR camera warrant a review of the actual conditions and operation to ensure the tanks are operating within permit limits (see AOC # 12). T-401 Emissions at the bottom of the tank The NEIC inspectors recorded benzene emissions near T-401 using the GMAP, and they observed and recorded hydrocarbon emissions from the base of the tank when using a FLIR camera to survey the area to locate the source of the benzene. They reported this to the field group, and we walked the circumference of T-401 with a FLIR camera (see Appendix 2 - Videos 28-31) and an MSA Sirius 4-gas meter with a photoionization detector (PID). We observed that the tank had a second floor that was installed. Mr. Denton explained that they had left the old floor in place, put a layer of compacted sand on top, and then installed the new floor on the sand layer. We also observed some small piping from the sand layer and below the original floor. Mr. Denton explained that the piping was a Praxair monitoring system used to detect leaks in the tank floor. The company can put a tracer chemical into the tank's contents, then monitor at the sample piping for the tracer chemical. The emissions we observed using the FLIR did not appear to be emanating from the Praxair monitoring points. The following are the main areas where we observed issues: On the north side of the tank, I detected 400 ppm VOCs. At the water draw and roof drain on the southwest side, James observed emissions and an active drip from the water draw. The operator tightened all of the valves associated with the piping, but the leaks continued. I detected 360 ppm VOCs at the water draw. At the south-southeast side (under the stairs), I detected 290 ppm VOCs. On the east side and the left side of the manway, we observed a large stained area on the gravel. I detected 730 ppm VOCs and the LEL meter detected 13% LEL, calibrated to methane. Y-11 and Y-12 Cooling Towers Artesia has Y-1, Y-2, Y-8, Y-11, and Y-12 Cooling Towers that are subject to NESHAP Subpart CC which requires monthly sampling of Heat Exchange Systems using the modified El Paso Method to detect leaks of hydrocarbons into the cooling water. The leak action level is defined as a total strippable hydrocarbon EPA Inspection Report - Page 13 of 1969 HollyFrontier Navajo Refinery LLC / Artesia Refinery Inspection Dates 10/1-4/2019 concentration (as methane) in the stripping gas of 6.2 ppmv. The results of the sampling are included in the NESHAP Subpart CC Semi-annual Reports. We observed the monthly sampling for Cooling Tower (C/T) Y-11 (see Appendix 1 - Photos 7-13). I reviewed the NESHAP CC Reports and noted the following sampling in which the monitoring detected a leak: Table 3 - Heat Exchange System Sampling Cooling Tower Y-8 Sample Date 5/16/18 FID concentration (ppmv) 31.40 Cooling Tower Circulation Rate (gpm) 12,500 Y-12 2/26/18 13.43 10,000 2/28/18 8.81 10,000 3/1/18 12.46 10,000 3/6/18 8.74 10,000 3/9/18 5.34 10,000 3/27/18 13.87 10,000 4/2/18 15.00 10,000 4/3/18 23.35 10,000 4/19/18 30.48 10,000 5/7/18 108.50* 10,000 5/16/18 33.95 10,000 6/22/18 58.72 10,000 7/12/18 35.34 10,000 8/6/18 19.22 10,000 9/20/18 27.88 10,000 10/25/18 25.15 10,000 11/26/18 60.24 10,000 12/28/18 36.36 10,000 1/9/19 42.40 10,000 Emission Rate (lb/hr) 2.5418 0.9043 0.5992 0.8444 0.5926 0.3507 0.9331 0.9509 1.5203 1.9873 6.7290 2.1823 3.7182 2.2264 1.2279 1.8123 1.4329 4.1033 2.5644 3.0143 Title V Permit Limit - Table 106.H (lb/hr) 6.5 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 Yellow-highlighted cells are over the permitted emission rate. *The 2018 Emission Inventory (EI) calculation data did not use the highest leak (108.5 ppmv) for May 2018. They used the only other May monitoring (33.95 ppmv). All of the other months that had multiple monitoring, the EI calculation data reflected the higher/highest of each month (see AOC # 13). Artesia had several leaks in Y-12 Cooling Tower beginning in February 2018 and one in Y-8 in May 2018. According to the facility, if they detect a leak and sample each of the HAP-containing heat exchangers, and none are the source of the leak, that is all they are required to do. The leak that started March 27, 2018 has never dropped below the leak definition of 6.2 ppmv through the January 9, 2019 monitoring. 13 EPA Inspection Report - Page 14 of 1969 HollyFrontier Navajo Refinery LLC / Artesia Refinery Inspection Dates 10/1-4/2019 The contractor, Dexter, is not recording the water circulation rate of the C/T at the time of sampling, but using the permitted water circulation rate, the VOC emissions have exceeded the permitted emission rate in Title V Permit P051R2 (see AOC # 14). Artesia did not report these permit rate exceedances in its Title V Annual Compliance Certification Deviation Reports (see AOC # 15). Table 4 - Cooling Tower Permit Limit Exceedance - VOCs Title V Permit Limit - Table 106.H C/T (tpy) 2016 EI (tpy) 2017 EI (tpy) Y-1 7.9 0.230 0.215 Y-2 7.9 0.150 0.255 Y-8 28.3 7.634 0.235 Y-11 5.5 11.573 2.359 Y-12 1.8 39.616 5.356 2018 EI (tpy) 0.028 0.029 0.964 0.314 8.168 Yellow-highlighted cells are permit limit exceedances. The Artesia Refinery exceeded their permitted VOC emission limit in 2016 for the Y-11 C/T and in 20162018 for the Y-12 C/T (see AOC # 16). The refinery did not report the Y-11 and Y-12 VOC permit exceedances in its Title V Annual Compliance Certifications (see AOC # 15). Emission Inventory According to Mr. Smalts, Artesia contracts with Leidos to prepare their annual EI required by NMED. The vapor pressure and chemical speciation of HAPs in the various refinery products used for calculating tank emissions is detailed in the Chemicals tab in the Tank Calcs spreadsheet (see CBI Appendices E, G, I, K) for each year's Emission Inventory (EI). Most of the sources of the vapor pressure and speciation seemed to be from sources such as AP-42 or other technical sources. During the onsite inspection, we had a conference call with the primary Leidos employees who work on the project: Ms. Kirsten Bates, a Senior Environmental Engineer, and Mr. John Vierow, a Senior Chemical Engineer. Leidos began doing EI and other project for Artesia since the reporting year 2016. Ms. Bates visits the refinery each year to collect the data needed to prepare the EI, Mr. Vierow prepares the EI and enters it in the NMED website, and Artesia submits it. We asked if the chemical speciations were from actual sampling of materials in tanks at Artesia, and Mr. Vierow said he didn't know. He stated that most of the speciations were historic from prior to 2016. We asked if the speciations were from American Petroleum Institute (API) or AP-42 tables, and Mr. Vierow stated that AP-42 doesn't typically have speciations. He had not compared the products to API. We asked how they know which speciation to use when a product changes since some of the products have very similar names (e.g. naphtha, light cat naphtha, heavy naphtha). Ms. Bates stated that Leidos relies on the facility. According to HollyFrontier, that decision is made by the Environmental Department and Operations at the refinery. 14 EPA Inspection Report - Page 15 of 1969 I had obtained the reported 2015 through 2018 EI data from NMED prior to the inspection. I noted that in 2016, Artesia reported no benzene emissions. The benzene emissions for 2017 and 2018 were comparable to those reported in 2015. I asked Ms. Bates and Mr. Vierow why no benzene emissions had been reported for 2016, and they stated that they would need to look at their records. The Toxics Release Inventory data had 1,900 lbs emitted from stacks and 430 lbs emitted as fugitives. I asked if Leidos was aware of the FLM monitoring for benzene. Mr. Vierow stated he was not very aware of it, but Ms. Bates was aware of it. I asked if the results of the FLM had been incorporated into the EI data, and Ms. Bates stated that she didn't believe it had been. Following the conference call with Leidos, we interviewed Ms. Jo Lynn Schneider, Laboratory Manager at the Artesia Refinery. She stated that they test the blend product tanks regularly for vapor pressure, gravity, and detailed hydrocarbon analysis (DHA). Recently they sampled field tanks due to sulfur issues. The data is stored in the LIMS system. Typical methods used at Artesia are as follows: Modified ASTM Method D3606 - Benzene. This modified method was developed by Artesia to shorten the test time to 5 minutes duration since they analyze a large number of samples. ASTM Method D3710 - Simulated distillation of petroleum products ASTM Method D5134 - DHA ASTM Method D5453 - Total sulfur content ASTM Method D4052 - Density, relative density, and API Gravity Ms. Schneider stated that the lab tests the overhead stream from Unit 13 which feeds T-57. Also, she stated that each Thursday they sample the feed from T-57 to Unit 20 for benzene, sulfur, DHA, and API gravity. In the 2018 Tank Calcs spreadsheet, there is a notation for Isom Feed that it was changed per August 2018 lab tests for T-57. The notation stated that the molecular weight was changed to gasoline. We asked for those results and any other testing of the material in T-57. Subsequent to the inspection, we received information of testing of Isom Feed for various dates from August 10, 2018 through September 11, 2019. Only the August 10, 2018 analysis indicated it was from T-57 since the name of the sample was "57TK IF." All of the other samples were named "ISOM FD," "ISOMFEED," or "IF," but T-57 was filled with naphtha bottoms on September 7, 2019, and the VP remained the same. It is not clear where Artesia obtained the samples . For T-57 HollyFrontier has called the material stored since 2012 until late 2019 a "light naphtha stream" in its Corrective Action letters. The 2018 EI used the product titled "Isom Feed" for emission calculations. The Chemicals tab for Isom Feed shows HAPs, but the Tank Emission Summary tab doesn't indicate HAP emissions from T-57. This is not accurate since the light naphtha stream is the feed for the BenFree unit which removes the benzene from the naphtha. Also, the speciation for Desalter Water doesn't list any benzene. Desalter water is typically a significant source of benzene. The tank that does store desalter water is listed as storing Sour Water in the Tank Emission Summary. This material doesn't have HAP emissions shown on the Chemicals tab. Artesia stated in the July 3, 2019 Amended Corrective EPA Inspection Report - Page 16 of 1969 Action Plan that T-737 may be contributing to benzene fenceline concentrations. The EI Tank Calcs files do not have any HAP speciation for T-737 Sour Water tank. I reviewed the tank landing information for the four years of EI calculations: 2015 tank landing are on the Tank SSM tab of the EI file (see CBI Appendix D). Landings or Idle/degas loss (13 tanks): T-402, T-835, T-79, T-412, T-402, T-108, T-412, T-109, T-415, T-450, T-12, T-106, T-108 2016 tank landings are on the Tank SSM tab of the EI file (see CBI Appendix F). Landing (2 tanks): T-835 (diesel 0.02 lbs), T-56 (naphtha 57 lbs) 2017 tank landings are on the Tank SSM tab of the EI file (see CBI Appendix H). Notes on the spreadsheet state that the data source used for 2016 is no longer maintained by the refinery, so the contractor reviewed individual event files and found no landing events. The contractor verified this with Ms. Staci Hammond. 2018 EI file (see CBI Appendix J) did not have a Tank SSM tab. I am not able to determine if Artesia included tank landing data in the EI reporting. The accuracy of the reported emissions to the EI database is of concern (see AOC # 17). As part of the Emission Inventory preparation, the calculated emissions are compared to permitted limits and limits to operating conditions (e.g. temperature, maximum true vapor pressure) and the comparison is reflected as a percent of the allowable or with a notation "Max Over" if the Max TVP exceeded the limit in the permit, or "Both Over" if the Max TVP and Average TVP exceeded the limit in the permit. The following permit exceedances were noted in the EI and Tank Calcs data: Table 5 - Emission and Operational Permit Deviations noted in EI files Year Category Description 2015 Permit Throughput Sour Water Actual Permitted 45,051 bbl/yr Actual % of Allowable 2016 Tank Temp - VP EI Summary Permit Throughput Tank Temp - VP T-107 Max TVP T-411 Max TVP T-422 Max TVP T-423 Max TVP Hydrogen Plant Reformer Furnaces NOx Hydrogen Plant Reformer NOx Distillates Sour Water T-107 Max TVP T-411 Max TVP T-422 Max TVP T-423 Max TVP 11.05 psia 11.05 psia 0.95 psia 0.89 psia 21.43 tpy 24.86 tpy 11.86 psia 11.86 psia 1.04 psia 1.36 psia 11.0 psia 11.0 psia 0.5 psia 0.5 psia 18.4 tpy 116% 18.5 tpy 134% 55,076,590 bbl/yr** 45,051 bbl/yr** 11.0 psia 11.0 psia 0.5 psia 0.5 psia EPA Inspection Report - Page 17 of 1969 Year 2017 2018 Category SSM SRU2-TGI SSM Flare Cap EI Summary Permit Throughput Tank Temp-VP EI Summary Permit Throughput Tank Emission Summary Tank Temp - VP Description T-435 Max TVP Actual 11.21 psia Permitted 11.0 psia Actual % of Allowable T-437 Max TVP 11.21 psia 11.0 psia T-452 Max TVP 1.91 psia 1.82 psia T-452 Avg TVP 0.82 psia (blank) T-1225 Max TVP 11.21 psia 11.0 psia SO2 1.76 tpy 0.4 tpy 440% VOC 27.79 tpy 13.2 tpy 211% SO2 15.92 tpy 14.9 tpy 107% North Flare VOCs 1.06 tpy 0.7 tpy 151% South Flare VOCs 0.26 tpy 0.2 tpy 132% Alky Flare VOCs 0.26 tpy 0.2 tpy 132% Y-11 Cooling 11.57 tpy 5.5 tpy 210% Tower VOCs Y-12 Cooling 39.62 tpy 1.8 tpy 2201% Tower VOCs Distillates 55,076,590 bbl/yr** Sour Water 45,051 bbl/yr** Not in file provided by HollyFrontier although it is referenced in the Tank Temp Entry tab. North Flare VOCs 1.06 tpy 0.7 tpy 151% South Flare VOCs 0.26 tpy 0.2 tpy 132% Alky Flare VOCs 0.26 tpy 0.2 tpy 132% Y-12 Cooling 5.36 tpy 1.8 tpy 298% Tower VOCs SRU3 SSM SO2 0.72 tpy 0.4 tpy 181% SRU2 SSM SO2 1.76 tpy 0.4 tpy 440% Flare SSM Cap 27.79 tpy 13.2 tpy 211% VOCs Flare SSM Cap 15.92 tpy 14.9 tpy 107% SO2 Sour Water 45,051 bbl/yr** Distillates 55,076,590 bbl/hr** Floating Roof Tank 104.9 tpy 87.6 tpy 119.7% VOCs T-49 Max TVP 2.58 psia 1.5 psia T-57 Max Temp 107.8oF * 90oF (ambient) T-57 Max TVP 15.21 psia 11.0 psia T-106 Max TVP 11.38 psia 11.0 psia T-107a Max TVP 14.58 psia 11.0 psia EPA Inspection Report - Page 18 of 1969 Year Category EI Summary Description T-111 Max TVP T-124 Max TVP FUG-RLOASPHALT VOC Y-11 Cooling Tower VOC SSM Flare Cap VOC Flares Malfunction Cap SO2 Actual 19.65 psia 12.97 psia 2.95 tpy 8.17 tpy 70.96 tpy 14.43 tpy Permitted 11.0 psia 11.0 psia 2.9 tpy 1.8 tpy 18.3 tpy 10 tpy Actual % of Allowable 102% 454% 538% 144% * Artesia provided the PI data for T-57, including tank temperature (see CBI Appendix L). This data revealed that the maximum tank temperature was . **The permitted throughput of Sour Water and Distillates was increased to 15,030,000 bbl/yr and 158,185,540 bbl/yr, respectively, with the Permit PSD-NM-0195-M37 issued August 12, 2016 (see Appendix 21). The EI consultant continued to use the old limits. Maximum True Vapor Pressure The Tank Applicability file also has information about the Max TVP. According to the spreadsheet, Artesia obtained this information from the 2018 Emission Inventory. When a tank operated with more than one product during the year, the applicability of the tank for each operating scenario is denoted with a letter behind the tank name (e.g. T-57a for light naphtha operation and T-57b for heavy naphtha operation). For T-57a, we noted a Max TVP of There is a Tank Table tab in the Tanks Applicability file that lists tanks with a Max TVP > . T-101B is a tank at the Lovington Refinery. When reviewing each of the tank tabs, I noted an additional tank T-107a. The following table is a list of tanks with a Max TVP > from the individual tank worksheets in the Tank Applicability file: Table 6 - Tanks with Max TVP 11.1 psia Tank Max TVP (psia) Tank Type T-57a EFR T-106 IFR T-107a IFR T-111 IFR T-124 IFR T-0411a EFR T-417 IFR Permitted Content Naphtha Distillates Gasolines Naphtha Gasolines Gasolines Gasolines Group 1 2* 1 1 1 1 1 *T-106 is listed as a Group 2 tank because the HAP weight % is listed as 0 for this product. This tank actually stores desalter water, one of the highest benzene contributors in the NESHAP Subpart FF Total Annual Benzene (TAB) Report (see AOC # 18). EPA Inspection Report - Page 19 of 1969 For NESHAP Subpart CC Group 1 tanks subject to 40 C.F.R. 63.646 and NESHAP Subpart G, if the Max TVP 11.1 psia, the tank must have a closed vent system with a control device to control emissions. For NESHAP Subpart CC Group 1 tanks subject to 40 C.F.R. 63.660 and the Max TVP 11.1 psia, NESHAP Subpart CC requires compliance with NESHAP Subpart SS which requires a closed vent system and a control device. Artesia has several tanks that they document in the Tank Applicability file a Max TVP 11.1 psia (see Table 6) and in the EI files (see Table 5) that do no currently have a closed vent system and control device. (see AOC # 19). Tank 49 - Slop Oil Tank Information T-49 is permitted as a fixed roof tank that is permitted to store moderate vapor pressure material. In the Tank Applicability file, T-49 is described as being a pressure vessel (PRS Roof Type) and exempt from Subpart CC group applicability. In the 2018 Tank Calcs (see Appendix K) file for Emission Inventory reporting, T-49 is reflected as a fixed roof tank. T-49 is not included in the Tank List (see CBI Appendix B) that was provided as part of the records request during the inspection (see AOC #20). T-451 and T-452 Tank Information The construction date for T-451 and T-452 is 2015 and each have a capacity of 6,900 bbls. The permit is unclear about the applicability and operation of these tanks. The following table is a history of the applicability and operations to help identify the correct applicability: Table 7 - T-451 and T-452 history Title V Permit P051R2M1 (1/22/16) Modification with the renewal is to install 2 new tanks. Table 103.C Applicability Table 106.B(2) EFR Tanks Table 106.C Fixed Roof Tanks Table 106.D Storage Tank Throughput and Temperature Limits PSD-NM-0195-M37 (8/12/16) (see Appendix 21) Tanks constructed as IFR tanks rather than EFR and fixed roof. Added tank ID numbers. Table 103.C Applicability Table 106.B(1) IFR Tanks Table 106.D Storage Tank Throughput and Temperature Limits Tank Applicability spreadsheet Biodiesel Tank TK-NEWBIODIESEL (low VP) Biodiesel: 949,000 bbl/yr NESHAP Subpart CC T-0451 Biodiesel (high VP) Biodiesel: 949,000 bbl/yr T-0451 Biodiesel IFR Group 2 Ethanol Tank NSPS Subpart Kb TK-NEWETHANOL (high VP) NSPS Subpart Kb T-0452 Ethanol (high VP) Ethanol: 142,350 bbl/yr T-0452 Ethanol IFR Group 2 EPA Inspection Report - Page 20 of 1969 Title V Permit application (May 2019) (see Appendix 22) Table 2-A: Regulated Emission T-0451 IFR Sources (formerly TK-NEWETHANOL) Table 2-L: Tank Data Installed: 2016 Low VP IFR Floating Roof Tank SSM Not listed Potential to Emit Tank List (see CBI Appendix B) Not Listed T-0452 IFR (formerly TK-NEWBIODIESEL) Installed: 2016 High VP IFR Not listed Not listed Yellow-highlighting is used to document the inconsistency of information from earlier permits, within a permitting action, or from other documents from Artesia. Artesia has conflicting information about tanks T-49, T-451, and T-452, and in some cases, the tanks are not included in tank inventories (see AOC # 20). Title V Reporting of Permit Deviations I reviewed the Title V Annual Compliance Certifications (ACC) for the September - August periods ending in August 2016 - 2019 (see Appendices 17-20). The permit deviations detailed in the EI files for each year and compiled in Table 2 above, with the exception of the Distillates and Sour Water throughputs for 2016-2018, were not reported in the Deviation Reports that are submitted as part of each ACC (see AOC # 15). At the end of each of the ACC reports are Excess Emission Reports (EER). The 2016 ACC had six (6) EERs from November 2015. Those same EERs are also in the reports for 2017, 2018, and 2019. It is unclear why they continue to be reported. Closeout Conference EPA inspectors Debbie Ford, James Haynes, and Richard Helmich and ERG inspector Dan Roper held a closeout conference on Friday, October 4, 2019. Attendees representing the Artesia Refinery were Scott Denton, Ray Smalts, Staci Hammond, Theresa Wheeler, and Parrish Miller. Also, representing the facility via phone were Sucheta Gokhale, Ray Bagherian, HollyFrontier Corporation Counsel, and Tom Shetina, Senior Vice-President Refinery Operations. I reviewed twenty (20) preliminary Areas of Concern during the close-out conference. Afterward, I received a list of documents requested during the inspection which was color-coded to indicate the documents received and the documents that were still outstanding. Section III - AREAS OF CONCERN 1. Artesia is not calculating the gap areas correctly for primary and secondary seal gap measurements. 2. Artesia does not maintain a current drawing of T-57 and its floating roof fittings. EPA Inspection Report - Page 21 of 1969 3. At the time of the inspection, the tank was below the 8.5' level that the company said triggers the opening of the vacuum breaker. 4. Artesia failed to provide a written report of within 30 days of the March 18 and 27, 2019 failed seal inspections of T-737. 5. Artesia took more than 45 days to empty tank T-737 to repair defects found during inspections on March 18 and 27, 2019. 6. Artesia has left DOR component Tag # 2720 in Unit 30 leaking for over 10 years. LDAR monitoring has detected VOCs as high as 500,000 ppm (50% in atmosphere). 7. Artesia did not design and operate the API Separator and New Stormwater Lift Station closed vent systems and control devices with a flow indicator to ensure that vapors are routed to the carbon canisters. 8. Artesia did not route emissions from the sump lift station near the aboveground API Separator and the New Stormwater Lift Station to the carbon canister systems. 9. Artesia designed and installed new equipment and a closed vent system with carbon canister controls in the wastewater system in 2012 that would be subject to NSPS Subpart QQQ but failed to include this information in their operating permits. 10. Artesia did not include the EOL sampling records for the sewer sludge disposed in 4Q 2017, 1Q 2019, and 2Q 2019 in the Consent Decree Quarterly Reports. 11. Artesia may not be including all information when calculating the quarterly benzene quantity and the estimated annual benzene quantity. 12. Artesia may have unauthorized emissions from some tanks at the facility. 13. The Artesia EI for 2018 did not correctly calculate VOC emissions for Y-12 Cooling Tower. 14. Artesia exceeded the permitted emission rate for the Y-12 Cooling Tower from February - January 2019. 15. Artesia failed to report in Title V Annual Compliance Certifications that the facility had exceeded the permitted VOC emission rate at Y-12 cooling tower, that the facility had exceeded the permitted VOC emission limit for Y-11 Cooling Tower in 2016 and Y-12 Cooling Tower in 2016, 2017, and 2018; and the permit limit exceedances that were detailed in the Emission Inventory data files. 16. Artesia failed to operate the Y-11 Cooling Tower in 2016 and the Y-12 Cooling Tower in 20162018 within its permitted annual VOC emission limit. 17. The Emission Inventory reporting may not be accurate. Artesia did not report any benzene emissions for 2016. Artesia did not report benzene emissions from T-57 tank, T-737 Sour Water tank, and the Desalter Water tank. Artesia did not report any emissions that would reflect the elevated benzene emissions detected by the FLM program. Artesia may not be including all of the tank maintenance or tank landing emissions. Artesia doesn't use actual product sampling for calculating emissions from tanks. 18. Artesia did not accurately make group determinations for tanks as required by NESHAP Subpart CC. 19. Artesia has stored materials with maximum true vapor pressures 11.1 psia in tanks T-57, T106, T-107, T-111, T-124, T-411, T-417, T-435, T-437, T-1225 that are not controlled by a closed vent system and control device. EPA Inspection Report - Page 22 of 1969 20. Artesia provided conflicting information about T-49 (described as a pressure vessel and as a fixed roof tank but not included in the Tank List for the facility), T-451 (originally described as a biodiesel fixed roof tank with low VP material, later as a IFR high VP tank, then low VP, not included in permit application SSM potential to emit tables, not included in the Tank List for the facility), and T-452 (not included in permit application SSM potential to emit tables, not included in the Tank List for the facility). 21. Artesia failed to submit a revised EOL Sampling Plan when improvements were made to the wastewater system in 2012. 22. Artesia did not require inspectors to watch a safety videos or instruct inspectors on basic emergency procedures such as muster points or warning sirens. 23. Artesia is not performing gap measurements of EFR tanks properly for primary seal measurements greater than 1/2" and is not using the proper probes to measure gaps for tanks subject to NESHAP Subpart WW. Section IV - FOLLOW-UP Subsequent to the inspection, the outstanding documents were submitted to EPA on October 16, 2019 (HFNA-VOL02-10.16.2019.zip) and October 18, 2019 (HFNA-VOL03-10.18.2019.zip). The documents that were received on October 4, 2019 were re-submitted to EPA on October 25, 2019 (HFNA-VOL0110.04.2019.zip). On Friday, October 18, 2019, James Haynes and I held a video conference with HollyFrontier to interview Mr. Omar Dominguez, tank inspector for the Artesia Refinery. Mr. Bagherian participated in the call. Ms. Cheryl Barnett, EPA Office of Regional Counsel, participated in the call for EPA Region 6. At that time, I requested additional records which HollyFrontier provided on October 29, 2019 (HFNA-VOL0410.29.2019.zip). HollyFrontier provided records submitted to EPA subsequent to the inspection via Sidley sharefile and documents were Bates stamped. On October 11, 2019, HollyFrontier submitted a third amendment to the NESHAP Subpart CC Corrective Action Plan (see Appendix 12). Section V - LIST OF APPENDICES Appendix 1 - Photo Log - 76 photos taken 10/1-4/2019 Appendix 2 - Video Log - 36 FLIR videos taken 10/2-4/2019 Appendix 3 - Inspection sign-in sheet Appendix 4 - West Tank Area map Appendix 5 - North Center (Wastewater) Area map Appendix 6 - East Tank Area map Appendix 7 - South Tank Area map Appendix 8 - Center Tank Area map EPA Inspection Report - Page 23 of 1969 HollyFrontier Navajo Refinery LLC / Artesia Refinery Inspection Dates 10/1-4/2019 Appendix 9 - Corrective Action Plan dated 5/15/2019 Appendix 10 - Corrective Action Plan Amendment dated 7/3/2019 Appendix 11 - Corrective Action Plan Amendment 2 dated 9/3/2019 Appendix 12 - Corrective Action Plan Amendment 3 dated 10/11/2019 Appendix 13 - Title V Permit P051-R2 issued 5/6/2015, selected pages Appendix 14 - NESHAP Subpart CC Notice of Seal Inspections dated 7/16/2019 Appendix 15 - NESHAP Subpart CC Notice of 2019 Tank Inspections dated 12/12/2018 Appendix 16 - (not referenced in the inspection report) Appendix 17 - Title V Annual Compliance Certification Aug 2016 Appendix 18 - Title V Annual Compliance Certification Aug 2017 Appendix 19 - Title V Annual Compliance Certification Aug 2018 Appendix 20 - Title V Annual Compliance Certification Aug 2019 Appendix 21 - Permit PSD-NM-0195-M37 issued 8/12/2016, selected pages Appendix 22 - Title V Permit P051-R3 Application, selected pages Appendix 23 - Leak Detection and Repair Delay of Repair Report Appendix 24 - SRU #2 DOR Component 2720 Monitoring History Appendix 25 - Carbon Canister Daily Monitoring 2018 Appendix 26 - Carbon Canister Daily Monitoring 2019 Appendix 27 - End-of-Line Sampling Plan dated 3/31/2004 Appendix 28 - Sewer Sludge Manifests for March - May 2019 Appendix 29 - Artesia Refinery Consent Decree, selected pages Appendix 30 - Consent Decree Report for 4Q 2017 Appendix 31 - Consent Decree Report for 1Q 2019 Appendix 32 - Consent Decree Report for 2Q 2019 CBI Appendices - Do not publish CBI Appendix A - Tank Applicability (HFNA-5934) CBI Appendix B - Tank List (HFNA-5955) CBI Appendix C - T-57 Floating roof design (HFNA-6141) CBI Appendix D - 2015 Artesia EI.xlsx (HFNA-0001) CBI Appendix E - 2015 Tank Calcs.xls (HFNA-0002) CBI Appendix F - 2016 Artesia EI.xlsx (HFNA-0003) CBI Appendix G - 2016 Tank Calcs.xls (HFNA-0004) CBI Appendix H - 2017 Artesia EI.xlsx (HFNA-0005) CBI Appendix I - 2017 Tank Calcs.xls (HFNA-0006) CBI Appendix J - 2018 Artesia EI.xlsx (HFNA-0007) CBI Appendix K - 2018 Tank Calcs.xlsx (HFNA-0008) CBI Appendix L - T-57 PI Data (HFNA-6186) CBI Appendix M - T-737 Inspection Records (HFNA-5949) CBI Appendix N - Wastewater API drawings (HFNA-6646) CBI Appendix O - Wastewater system 2012 project (HFNA-6642) 23 EPA Inspection Report - Page 24 of 1969 Appendix 1 Photograph Log EPA Inspection Report - Page 25 of 1969 DATE/TIME: 10/1/2019 3:26 p.m. FILENAME: DSCN0359-01.jpg 1 DESCRIPTION: T-57 roof and slotted gauge hatch. TAKEN BY: James Haynes EPA Inspection Report - Page 26 of 1969 DATE/TIME: 10/1/2019 3:27 p.m. FILENAME: DSCN0360.jpg 2 T-57 roof. Note socks on legs. The sock on the vacuum breaker, indicated by DESCRIPTION: the red arrow, was damaged when the roof was landed. TAKEN BY: James Haynes EPA Inspection Report - Page 27 of 1969 DATE/TIME: 10/1/2019 3:27 p.m. FILENAME: DSCN0361.jpg 3 T-57 roof. The bulge in the wall on the pontoon was to allow the automatic DESCRIPTION: gauge cable to pass through the roof deck. At the time of the inspection, the cable was broken. TAKEN BY: James Haynes EPA Inspection Report - Page 28 of 1969 DATE/TIME: 10/1/2019 3:28 p.m. FILENAME: DSCN0362.jpg 4 DESCRIPTION: T-57 roof looking down the tank ladder. TAKEN BY: James Haynes EPA Inspection Report - Page 29 of 1969 DATE/TIME: 10/1/2019 3:29 p.m. FILENAME: DSCN0363.jpg 5 DESCRIPTION: T-57 roof, left side. TAKEN BY: James Haynes EPA Inspection Report - Page 30 of 1969 DATE/TIME: 10/1/2019 3:41 p.m. FILENAME: DSCN0364.jpg 6 DESCRIPTION: T-57 nameplate. TAKEN BY: James Haynes EPA Inspection Report - Page 31 of 1969 DATE/TIME: 10/2/2019 2:18 p.m. FILENAME: DSCN0392.jpg 7 DESCRIPTION: TVA 1000 and calibration gases for cooling tower sampling. TAKEN BY: Debbie Ford EPA Inspection Report - Page 32 of 1969 DATE/TIME: 10/2/2019 2:21 p.m. FILENAME: DSCN0393.jpg 8 DESCRIPTION: Return line from heat exchangers for CY-11 Cooling Tower. TAKEN BY: Debbie Ford EPA Inspection Report - Page 33 of 1969 DATE/TIME: 10/2/2019 2:22 p.m. FILENAME: DSCN0394.jpg 9 DESCRIPTION: Sample line being connected to heat exchanger return line for CY-11 Cooling Tower sampling. TAKEN BY: Debbie Ford EPA Inspection Report - Page 34 of 1969 DATE/TIME: 10/2/2019 2:55 p.m. FILENAME: DSCN0365.jpg 10 DESCRIPTION: Sampling apparatus for Modified El Paso Method. TAKEN BY: James Haynes EPA Inspection Report - Page 35 of 1969 DATE/TIME: 10/2/2019 2:56 p.m. FILENAME: DSCN0395-01.jpg 11 DESCRIPTION: Run #1 for CY-11 Cooling Tower. TAKEN BY: Debbie Ford EPA Inspection Report - Page 36 of 1969 DATE/TIME: 10/2/2019 3:09 p.m. FILENAME: DSCN0366.jpg 12 DESCRIPTION: CY-11 Cooling Tower sampling point on heat exchanger return line. TAKEN BY: James Haynes EPA Inspection Report - Page 37 of 1969 DATE/TIME: 10/2/2019 3:10 p.m. FILENAME: DSCN0367.jpg 13 DESCRIPTION: Close-up of Modified El Paso Method sampling apparatus. TAKEN BY: James Haynes EPA Inspection Report - Page 38 of 1969 EPA Inspection Report - Page 39 of 1969 DATE/TIME: 10/2/2019 3:32 p.m. FILENAME: DSCN0402.jpg 15 DESCRIPTION: T-124 tank. Visible emissions observed with FLIR infrared camera. TAKEN BY: Debbie Ford EPA Inspection Report - Page 40 of 1969 DATE/TIME: 10/2/2019 4:00 p.m. FILENAME: DSCN0404.jpg 16 DESCRIPTION: T-49 Slop Oil Tank - BWON sampling in Wastewater Unit. TAKEN BY: Debbie Ford EPA Inspection Report - Page 41 of 1969 DATE/TIME: 10/2/2019 4:05 p.m. FILENAME: DSCN0405.jpg 17 DESCRIPTION: T-49 Slop Oil Tank BWON sampling in Wastewater Unit. Collection of sample after passing through the chiller. TAKEN BY: Debbie Ford EPA Inspection Report - Page 42 of 1969 DATE/TIME: 10/2/2019 4:08 p.m. FILENAME: DSCN0406.jpg 18 DESCRIPTION: T-49 Slop Oil Tank BWON sampling in Wastewater Unit. Collection of sample after passing through the chiller. TAKEN BY: Debbie Ford EPA Inspection Report - Page 43 of 1969 DATE/TIME: 10/2/2019 4:18 p.m. FILENAME: DSCN0407.jpg 19 Aboveground API Separator - west side. Note the clamps for sealing DESCRIPTION: the roof of the separator. Visible emissions observed with the FLIR infrared camera. TAKEN BY: Debbie Ford EPA Inspection Report - Page 44 of 1969 DATE/TIME: 10/2/2019 4:18 p.m. FILENAME: DSCN0408.jpg Aboveground API Separator (west side) with carbon canister 20 DESCRIPTION: system used as the control device. Note the clamps for sealing the roof of the separator. Visible emissions observed with the FLIR infrared camera. TAKEN BY: Debbie Ford EPA Inspection Report - Page 45 of 1969 DATE/TIME: 10/2/2019 4:23 p.m. FILENAME: DSCN0409.jpg Aboveground API Separator. West separator on the right. East 21 DESCRIPTION: separator on the left. Note the clamps for sealing the roof of the separator. Visible emissions observed with the FLIR infrared camera on both separators. TAKEN BY: Debbie Ford EPA Inspection Report - Page 46 of 1969 EPA Inspection Report - Page 47 of 1969 DATE/TIME: 10/2/2019 4:52 p.m. FILENAME: DSCN0369.jpg 23 Control Room display of temperatures into and out of fin-fan cooler X-187 DESCRIPTION: and heat exchangers X-571, X-572, X-172. The stream out of the coolers/heat exchangers is the feed to T-57. TAKEN BY: James Haynes EPA Inspection Report - Page 48 of 1969 DATE/TIME: 10/3/2019 9:45 a.m. FILENAME: DSCN0370.jpg 24 DESCRIPTION: Fenceline Monitoring System - Sample Point 7 on the east side of the facility near T-11. TAKEN BY: James Haynes EPA Inspection Report - Page 49 of 1969 DATE/TIME: 10/3/2019 9:43 a.m. FILENAME: DSCN0411.jpg 25 DESCRIPTION: Fenceline Monitoring System - Sample Point 7. Holder open to show the passive sample tubes. TAKEN BY: Debbie Ford EPA Inspection Report - Page 50 of 1969 DATE/TIME: 10/3/2019 9:49 a.m. FILENAME: DSCN0412.jpg 26 DESCRIPTION: T-11 tank (left). To the north is T-12 tank (right). Visible emissions observed with the FLIR infrared camera from both tanks. TAKEN BY: Debbie Ford EPA Inspection Report - Page 51 of 1969 DATE/TIME: 10/3/2019 9:52 a.m. FILENAME: DSCN0371.jpg 27 DESCRIPTION: T-11 vent. TAKEN BY: James Haynes EPA Inspection Report - Page 52 of 1969 DATE/TIME: 10/3/2019 9:53 a.m. FILENAME: DSCN0372.jpg 28 DESCRIPTION: T-11. TAKEN BY: James Haynes EPA Inspection Report - Page 53 of 1969 DATE/TIME: 10/3/2019 10:07 a.m. FILENAME: DSCN0373.jpg 29 DESCRIPTION: T-12 tank. Visible emissions observed with the FLIR infrared camera. TAKEN BY: James Haynes EPA Inspection Report - Page 54 of 1969 DATE/TIME: 10/3/2019 10:08 a.m. FILENAME: DSCN0374.jpg 30 DESCRIPTION: T-12 tank. TAKEN BY: James Haynes EPA Inspection Report - Page 55 of 1969 DATE/TIME: 10/3/2019 10:16 a.m. FILENAME: DSCN0375.jpg 31 DESCRIPTION: T-11 tank. TAKEN BY: James Haynes EPA Inspection Report - Page 56 of 1969 DATE/TIME: 10/3/2019 10:21 a.m. FILENAME: DSCN0376.jpg 32 DESCRIPTION: T-108 tank. Visible emissions observed with the FLIR infrared camera. TAKEN BY: James Haynes EPA Inspection Report - Page 57 of 1969 DATE/TIME: 10/3/2019 10:32 a.m. FILENAME: DSCN0377.jpg 33 DESCRIPTION: T-415 tank. Visible emissions observed with the FLIR infrared camera. TAKEN BY: James Haynes EPA Inspection Report - Page 58 of 1969 DATE/TIME: 10/3/2019 10:36 a.m. FILENAME: DSCN0378.jpg 34 DESCRIPTION: T-109 tank. Visible emissions observed with the FLIR infrared camera. TAKEN BY: James Haynes EPA Inspection Report - Page 59 of 1969 DATE/TIME: 10/3/2019 10:44 a.m. FILENAME: DSCN0379.jpg 35 DESCRIPTION: T-108 tank back. TAKEN BY: James Haynes EPA Inspection Report - Page 60 of 1969 DATE/TIME: 10/3/2019 10:46 a.m. FILENAME: DSCN0380.jpg 36 DESCRIPTION: T-109 tank. TAKEN BY: James Haynes EPA Inspection Report - Page 61 of 1969 DATE/TIME: 10/3/2019 10:52 a.m. FILENAME: DSCN0414.jpg 37 DESCRIPTION: T-401 tank. Visible emissions observed with the FLIR infrared camera from the top of the floating roof and the base of the tank. TAKEN BY: Debbie Ford EPA Inspection Report - Page 62 of 1969 DATE/TIME: 10/3/2019 11:03 a.m. FILENAME: DSCN0381.jpg T-401 tank left side. Roof not floating on liquid surface. Right side 38 DESCRIPTION: approximately 1 foot lower than the left side. Water observed on approximately of the surface of the roof deck. Visible emissions observed with the FLIR camera. TAKEN BY: James Haynes EPA Inspection Report - Page 63 of 1969 DATE/TIME: 10/3/2019 11:03 a.m. FILENAME: DSCN0382.jpg T-401 tank center view. Roof not floating on liquid surface. Right side 39 DESCRIPTION: approximately 1 foot lower than the left side. Water observed on approximately of the surface of the roof deck. Visible emissions observed with the FLIR camera. TAKEN BY: James Haynes EPA Inspection Report - Page 64 of 1969 DATE/TIME: 10/3/2019 11:03 a.m. FILENAME: DSCN0383.jpg T-401 tank right side. Roof not floating on liquid surface. Right side 40 DESCRIPTION: approximately 1 foot lower than the left side. Water observed on approximately of the surface of the roof deck. Visible emissions observed with the FLIR camera. TAKEN BY: James Haynes EPA Inspection Report - Page 65 of 1969 DATE/TIME: 10/3/2019 11:04 a.m. FILENAME: DSCN0384.jpg T-401 tank right side. Roof not floating on liquid surface. Right side 41 DESCRIPTION: approximately 1 foot lower than the left side. Water observed on approximately of the surface of the roof deck. Visible emissions observed with the FLIR camera. TAKEN BY: James Haynes EPA Inspection Report - Page 66 of 1969 DATE/TIME: 10/3/2019 11:17 a.m. FILENAME: DSCN0385.jpg T-401 tank slotted Guidepole on right side. Roof not floating on liquid 42 DESCRIPTION: surface. Right side approximately 1 foot lower than the left side. Water observed on approximately of the surface of the roof deck. Visible emissions observed with the FLIR camera. TAKEN BY: James Haynes EPA Inspection Report - Page 67 of 1969 DATE/TIME: 10/3/2019 11:21 a.m. FILENAME: DSCN0386.jpg 43 DESCRIPTION: #3 Blending Pit. TAKEN BY: James Haynes EPA Inspection Report - Page 68 of 1969 DATE/TIME: 10/3/2019 11:21 a.m. FILENAME: DSCN0387.jpg 44 DESCRIPTION: #3 Blending Pit. TAKEN BY: James Haynes EPA Inspection Report - Page 69 of 1969 DATE/TIME: 10/3/2019 11:31 a.m. FILENAME: DSCN0415.jpg 45 DESCRIPTION: T-1225 Crude oil tank. TAKEN BY: Debbie Ford EPA Inspection Report - Page 70 of 1969 DATE/TIME: 10/3/2019 11:31 a.m. FILENAME: DSCN0416.jpg 46 DESCRIPTION: T-1225 Crude oil tank (foreground); T-437 Crude oil tank (background) TAKEN BY: Debbie Ford EPA Inspection Report - Page 71 of 1969 DATE/TIME: 10/3/2019 11:37 a.m. FILENAME: DSCN0388.jpg 47 DESCRIPTION: T-1225 Crude Oil Tank left side. Water observed on surface of roof deck. Visible emissions observed with the FLIR infrared camera. TAKEN BY: James Haynes EPA Inspection Report - Page 72 of 1969 DATE/TIME: 10/3/2019 11:37 a.m. FILENAME: DSCN0389.jpg 48 DESCRIPTION: T-1225 Crude Oil Tank left side. Water observed on surface of roof deck. TAKEN BY: James Haynes EPA Inspection Report - Page 73 of 1969 DATE/TIME: 10/3/2019 11:37 a.m. FILENAME: DSCN0390.jpg 49 DESCRIPTION: T-1225 Crude Oil Tank center view. Water observed on surface of roof deck. TAKEN BY: James Haynes EPA Inspection Report - Page 74 of 1969 DATE/TIME: 10/3/2019 11:38 a.m. FILENAME: DSCN0391.jpg 50 DESCRIPTION: T-1225 Crude Oil Tank right side. Water observed on surface of roof deck. TAKEN BY: James Haynes EPA Inspection Report - Page 75 of 1969 DATE/TIME: 10/3/2019 11:38 a.m. FILENAME: DSCN0392.jpg 51 DESCRIPTION: T-1225 Crude Oil Tank right side. Water observed on surface of roof deck. TAKEN BY: James Haynes EPA Inspection Report - Page 76 of 1969 DATE/TIME: 10/3/2019 12:01 p.m. FILENAME: DSCN0393.jpg 52 DESCRIPTION: T-431 tank. Visible emissions observed with the FLIR infrared camera at the staining on the right side of the tank. TAKEN BY: James Haynes EPA Inspection Report - Page 77 of 1969 DATE/TIME: 10/3/2019 12:09 p.m. FILENAME: DSCN0394.jpg 53 T-432 tank. Visible emissions observed with the FLIR infrared camera from DESCRIPTION: the tank vent on the right (at the tank staining) and possible emissions at the edge of the roof where the tank staining is on the left. TAKEN BY: James Haynes EPA Inspection Report - Page 78 of 1969 DATE/TIME: 10/3/2019 12:15 p.m. FILENAME: DSCN0395.jpg 54 DESCRIPTION: T-434 Raw Diesel tank. Visible emissions observed with the FLIR infrared camera. TAKEN BY: James Haynes EPA Inspection Report - Page 79 of 1969 DATE/TIME: 10/3/2019 12:21 p.m. FILENAME: DSCN0396.jpg 55 DESCRIPTION: T-417 tank (middle tank). Visible emissions observed with the FLIR infrared camera. TAKEN BY: James Haynes EPA Inspection Report - Page 80 of 1969 EPA Inspection Report - Page 81 of 1969 DATE/TIME: 10/4/2019 10:04 a.m. FILENAME: DSCN0398.jpg 57 T-401 Isom (gasoline) tank. Water draw valves on the left allowing liquid to DESCRIPTION: drip into drain. Visible emissions observed with the FLIR infrared camera. After tightening valves, the drip and visible emissions continued. TAKEN BY: James Haynes EPA Inspection Report - Page 82 of 1969 DATE/TIME: 10/4/2019 10:10 a.m. FILENAME: DSCN0399.jpg 58 T-401 Isom (gasoline) tank. Praxair monitors to detect leaks located between DESCRIPTION: the old tank floor and the new one as well as below the concrete foundation. Visible emissions observed with the FLIR camera. TAKEN BY: James Haynes EPA Inspection Report - Page 83 of 1969 DATE/TIME: 10/4/2019 10:14 a.m. FILENAME: DSCN0400.jpg 59 T-401 Isom (gasoline) tank. Visible emissions observed with the FLIR DESCRIPTION: infrared camera. Location of the highest readings with the MSA Sirius 4-gas with PID monitor: 730 ppm VOCs and 13% LEL. TAKEN BY: James Haynes EPA Inspection Report - Page 84 of 1969 DATE/TIME: 10/4/2019 11:18 a.m. FILENAME: DSCN0423.jpg 60 DESCRIPTION: Delay of Repair (DOR) component in SRU #2 unit. Tag 2720. TAKEN BY: Debbie Ford EPA Inspection Report - Page 85 of 1969 DATE/TIME: 10/4/2019 11:26 a.m. FILENAME: DSCN0401.jpg 61 Delay of Repair (DOR) valve 2720 in SRU #2 Unit. Originally put on DOR DESCRIPTION: list 5/13/09. Monthly monitoring records since 2016 document emissions from the valve as high as 127,700 and 500,000 ppm at times. TAKEN BY: James Haynes EPA Inspection Report - Page 86 of 1969 DATE/TIME: 10/4/2019 11:26 a.m. FILENAME: DSCN0402.jpg 62 Back side of LDAR leak tag for DOR valve 2720 in SRU #2 Unit. Originally DESCRIPTION: put on DOR list 5/13/09. Monthly monitoring records since 2016 show emissions from the valve as high as 127,700 and 500,000 ppm at times. TAKEN BY: James Haynes EPA Inspection Report - Page 87 of 1969 DATE/TIME: 10/4/2019 11:32 a.m. FILENAME: DSCN0424.jpg 63 T-737 tank view through open doorsheet. Tank is out of service for new floor DESCRIPTION: installation. Steel sheet panels being aligned and positioned under the wall of the tank prior to rewelding. TAKEN BY: Debbie Ford EPA Inspection Report - Page 88 of 1969 DATE/TIME: 10/4/2019 11:32 a.m. FILENAME: DSCN0425.jpg 64 DESCRIPTION: T-737 tank view of tank wall edge aligned with new steel sheet panels prior to rewelding. TAKEN BY: Debbie Ford EPA Inspection Report - Page 89 of 1969 DATE/TIME: 10/4/2019 11:34 a.m. FILENAME: DSCN0426.jpg 65 DESCRIPTION: T-737 tank view of underside of roof deck. Roof is on legs, but also cribbing is installed to hold roof. TAKEN BY: Debbie Ford EPA Inspection Report - Page 90 of 1969 DATE/TIME: 10/4/2019 11:35 a.m. FILENAME: DSCN0427.jpg 66 DESCRIPTION: T-737 tank view from open doorsheet to opposite side of tank. The equipment in the foreground is used to push the steel plates into position for welding. TAKEN BY: Debbie Ford EPA Inspection Report - Page 91 of 1969 DATE/TIME: 10/4/2019 2:02 p.m. FILENAME: DSCN0428.jpg 67 DESCRIPTION: Old carbon canister sampling at above ground API Separator. HollyFrontier uses their LDAR contractor Dexter to perform the daily sampling. TAKEN BY: Debbie Ford EPA Inspection Report - Page 92 of 1969 DATE/TIME: 10/4/2019 2:02 p.m. FILENAME: DSCN0429.jpg 68 DESCRIPTION: Hose and piping configuration at the old carbon canister sampling at above ground API Separator. The inlet canister is on the right. TAKEN BY: Debbie Ford EPA Inspection Report - Page 93 of 1969 EPA Inspection Report - Page 94 of 1969 DATE/TIME: 10/4/2019 2:18 p.m. FILENAME: DSCN0430.jpg 70 North cover on sump at lift station north of aboveground API Separator near DESCRIPTION: pump P-8005 Lift Basin Pump. Visible emissions observed with FLIR infrared camera. TAKEN BY: Debbie Ford EPA Inspection Report - Page 95 of 1969 DATE/TIME: 10/4/2019 2:20 p.m. FILENAME: DSCN0431.jpg 71 West cover on sump at lift station north of aboveground API Separator near DESCRIPTION: pump P-8005 Lift Basin Pump. Visible emissions observed with FLIR infrared camera. TAKEN BY: Debbie Ford EPA Inspection Report - Page 96 of 1969 DATE/TIME: 10/4/2019 2:41 p.m. FILENAME: DSCN0406.jpg 72 Cover at new sump installed in 2012 for receipt of all wastewater from the DESCRIPTION: facility. Visible emissions observed with the FLIR infrared camera from the sump cover. TAKEN BY: James Haynes EPA Inspection Report - Page 97 of 1969 DATE/TIME: 10/4/2019 2:47 p.m. FILENAME: DSCN0434.jpg 73 DESCRIPTION: New carbon canister system: Carbon Filter D-8001 on left and D-8000 on the right. TAKEN BY: Debbie Ford EPA Inspection Report - Page 98 of 1969 DATE/TIME: 10/4/2019 2:47 p.m. FILENAME: DSCN0407.jpg 74 Cover at new sump installed in 2012 for receipt of all wastewater from the DESCRIPTION: facility. Visible emissions observed with the FLIR infrared camera from the sump cover. TAKEN BY: James Haynes EPA Inspection Report - Page 99 of 1969 DATE/TIME: 10/4/2019 2:52 p.m. FILENAME: DSCN0408.jpg 75 DESCRIPTION: New carbon canisters that control the new sump installed in 2012. TAKEN BY: James Haynes EPA Inspection Report - Page 100 of 1969 DATE/TIME: 10/4/2019 3:04 p.m. FILENAME: DSCN0409.jpg 76 Junction box at bundle cleaning area west of the wastewater system. Slight DESCRIPTION: visible emissions observed with FLIR infrared camera from end of gooseneck pipe on the lid. TAKEN BY: James Haynes EPA Inspection Report - Page 101 of 1969 Appendix 2 Video Log EPA Inspection Report - Page 102 of 1969 Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 1 10/02/2019 15:35 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 124 at vent Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 2 10/02/2019 16:21 James Haynes Hydrocarbon emissions observed with the FLIR camera from the west aboveground API separator at roof seals Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 3 10/02/2019 16:22 James Haynes Video from a different angle than Video No. 2 of hydrocarbon emissions observed with the FLIR camera from the west aboveground API separator Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 4 10/02/2019 16:26 James Haynes Additional view from a higher angle than Video Nos. 2 and 3 of hydrocarbon emissions observed with the FLIR camera from the west aboveground API separator EPA Inspection Report - Page 103 of 1969 Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 5 10/02/2019 16:30 James Haynes Hydrocarbon emissions observed with the FLIR camera from the west side of the east aboveground API separator roof seals Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 6 10/02/2019 16:33 James Haynes Hydrocarbon emissions observed with the FLIR camera from the east side of the west aboveground API separator roof seals Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 7 10/02/2019 16:37 James Haynes Hydrocarbon emissions observed with the FLIR camera from the east side of the east aboveground API separator roof seals near the vapor collection system Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 8 10/03/2019 09:50 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 11 at vent EPA Inspection Report - Page 104 of 1969 Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 9 10/03/2019 10:02 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 12 at vent Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 10 10/03/2019 10:20 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 108 at vent Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 11 10/03/2019 10:30 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 415 at vent Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 12 10/03/2019 10:36 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 109 at vent Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 13 10/03/2019 10:42 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 108 at vent EPA Inspection Report - Page 105 of 1969 Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 14 10/03/2019 11:09 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 401 along secondary seal viewing right from the tank's platform Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 15 10/03/2019 11:10 James Haynes Additional hydrocarbon emissions observed with the FLIR camera from Tank 401 along secondary seal viewing right from the tank's platform Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 16 10/03/2019 11:11 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 401 along secondary seal across from the tank's platform Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 17 10/03/2019 11:13 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 401 along secondary seal viewing left from the tank's platform EPA Inspection Report - Page 106 of 1969 Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 18 10/03/2019 11:14 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 401 along secondary seals below the tank's platform Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 19 10/03/2019 11:16 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 401 along secondary seal below the tank's platform Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 20 10/03/2019 11:47 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 1225 along secondary seal viewing left of the tank's platform Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 21 10/03/2019 11:48 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 1225 along secondary seal below the tank's platform EPA Inspection Report - Page 107 of 1969 Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 22 10/03/2019 11:50 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 1225 along secondary seals below the tank's platform Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 23 10/03/2019 12:00 James Haynes Hydrocarbon emissions observed with the FLIR camera from fixed roof Tank 431 at vent Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 24 10/03/2019 12:05 James Haynes Hydrocarbon emissions observed with the FLIR camera from fixed roof Tank 432 at vent Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 25 10/03/2019 12:07 James Haynes Potential hydrocarbon emissions observed with the FLIR camera from fixed roof Tank 432 at area to left of vent near stained insulation Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 26 10/03/2019 12:15 James Haynes Hydrocarbon emissions observed with the FLIR camera from fixed roof Tank 434 at vent EPA Inspection Report - Page 108 of 1969 Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 27 10/03/2019 12:20 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 417 at vent Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 28 10/04/2019 09:46 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 401 along the base of the tank Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 29 10/04/2019 10:03 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 401 at the closed water draw valve Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 30 10/04/2019 10:09 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 401 along the base of the tank Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 31 10/04/2019 10:14 James Haynes Hydrocarbon emissions observed with the FLIR camera from Tank 401 along the base of the tank (without the Praxiar sample ports) EPA Inspection Report - Page 109 of 1969 Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 32 10/04/2019 11:20 James Haynes Hydrocarbon emissions observed with the FLIR camera from LDAR Tag # 2720-000 in Unit 30 (Sulfur Recovery Unit #2); component has been on DOR since 2009 Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 33 10/04/2019 14:20 James Haynes Hydrocarbon emissions observed with the FLIR camera from the north cover on the sump at the lift station north of the aboveground API separator (near pump P-8005 Lift Basin Pump) Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 34 10/04/2019 14:24 James Haynes Hydrocarbon emissions observed with the FLIR camera from the west cover on the sump at the lift station north of the aboveground API separator (near pump P-8005 Lift Basin Pump). Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 35 10/04/2019 14:41 James Haynes Hydrocarbon emissions observed with the FLIR camera from the cover of the new sump installed in 2012 for receipt of all wastewater from the facility; emissions from the sump are controlled by the New Carbon Canister System EPA Inspection Report - Page 110 of 1969 Video Number: Video File Name: Date of Video: Time of Video: Videographer: Description: 36 10/04/2019 14:47 James Haynes Hydrocarbon emissions observed with the FLIR camera from a second new sump cover near the New Carbon Canister System EPA Inspection Report - Page 111 of 1969 Appendix 3 Sign-In Sheet EPA Inspection Report - Page 112 of 1969 EPA Inspection Report - Page 113 of 1969 Appendix 4 West Tank Area EPA Inspection Report - Page 114 of 1969 West Tank Area near Fenceline Monitoring Sites 13, 14, 15 EPA Inspection Report - Page 115 of 1969 Appendix 5 North Center (Wastewater) Area EPA Inspection Report - Page 116 of 1969 North Center (Wastewater) Area near Fenceline Monitoring Points 19, 1 EPA Inspection Report - Page 117 of 1969 Appendix 6 East Tank Area EPA Inspection Report - Page 118 of 1969 EPA Inspection Report - Page 119 of 1969 Appendix 7 South Tank Area EPA Inspection Report - Page 120 of 1969 South Tank Area near Fenceline Monitoring Sites 8, 9, 10, 11, 12 EPA Inspection Report - Page 121 of 1969 Appendix 8 Center Tank Area EPA Inspection Report - Page 122 of 1969 Center Tank Area near Fenceline Monitoring Points 13, 14, 5, 6 EPA Inspection Report - Page 123 of 1969 EPA Inspection Report - Page 124 of 1969 EPA Inspection Report - Page 125 of 1969 EPA Inspection Report - Page 126 of 1969 EPA Inspection Report - Page 127 of 1969 ________ - bEt tr r C (;5 --------- 8. - i. 1%.. - A - 4 1. 0 (I ----I F --I T-18 T9 T8 T-29 1' I'. 91 `-5 -8 I (23 I 5O r1-.:-: . w 0 - - . A : T42 7-81 _I a- -T-44 74T.73 r ` T.116 9,. ,01 114 t2 T-115 11 FA T-12 T415 T-107 T-l09 T1OB1 4 32 - `. 8--42-.;; I T420T422 4i - !. i: - T-423 I ` ;i'!":: r `- I 1.4 fA - "----i A I- - -- `.--- `8 IF-:. I EXPLANATION A GPS LOCATION SITE BOUNDARY (320.72 ACRES) FIGURE 1 IrihL1dro N FENCELINE MONITORING SAMPLING STATIONS CORPIRAFION 1252 Commerce Drive HOLLYFRONTIER NAVAJO REFINING LLC Laramie, WY 82070 www.trihydm.com ARTESIA, NEW MEXICO 0 500 (P) 3071745.7474 (F) 3071745.7729 Drawn By: CF Checked By: JS Sca(e: V = 500' Date: 11/17/161 File: HF_NavaJo_FencelineMonitonng.mxd EPA Inspection Report - Page 128 of 1969 EPA Inspection Report - Page 129 of 1969 EPA Inspection Report - Page 130 of 1969 EPA Inspection Report - Page 131 of 1969 EPA Inspection Report - Page 132 of 1969 EPA Inspection Report - Page 133 of 1969 EPA Inspection Report - Page 134 of 1969 EPA Inspection Report - Page 135 of 1969 EPA Inspection Report - Page 136 of 1969 EPA Inspection Report - Page 137 of 1969 EPA Inspection Report - Page 138 of 1969 TABLE OF CONTENTS Part A FACILITY SPECIFIC REQUIREMENTS .....................................................................3 A100 Introduction................................................................................................................. 3 A101 Permit Duration (expiration)....................................................................................... 3 A102 Facility: Description.................................................................................................... 4 A103 Facility: Applicable Regulations and Non-Applicable Regulations........................... 5 A104 Facility: Regulated Sources ........................................................................................ 7 A105 Facility: Control Methods ........................................................................................... 8 A106 Facility: Allowable Emissions .................................................................................. 10 A107 Facility: Allowable Startup, Shutdown, & Maintenance (SSM) and Malfunction Emissions .................................................................................................................................. 12 A108 Facility: Hours of Operation ..................................................................................... 15 A109 Facility: Reporting Schedules ................................................................................... 16 A110 Facility: Fuel and Fuel Sulfur Requirements (as required)....................................... 16 A111 Facility: 20.2.36 NMAC ........................................................................................... 17 A112 Facility: 20.2.37 NMAC ........................................................................................... 18 A113 Facility: 20.2.38 NMAC ........................................................................................... 19 A114 Facility: Relocation Requirements - Not Required .................................................. 20 A115 Alternative Operating Scenario - Not Required ....................................................... 20 A116 Compliance Plan - Not Required ............................................................................. 20 A117 Reducing Facility Emissions - Not Required ........................................................... 20 A118 Facility: MACT Subpart UUU.................................................................................. 20 A119 40 CFR 61 Subpart FF, National Emission Standard for Benzene Waste Operations 20 EQUIPMENT SPECIFIC REQUIREMENTS ..............................................................................21 Oil and Gas Industry ......................................................................................................................21 A200 Oil and Gas Industry ................................................................................................. 21 A201 Engines...................................................................................................................... 21 A202 Glycol Dehydrators - Not Required ......................................................................... 22 A203 Tanks......................................................................................................................... 22 A204 Heaters/Boilers.......................................................................................................... 24 A205 Turbines not required ................................................................................................ 34 A206 Flares......................................................................................................................... 35 A207 Sulfur Recovery Plant (SRP), Tail Gas Incinerator (TGI)........................................ 36 A208 Amine Unit - Not Required ...................................................................................... 38 A209 Fugitives.................................................................................................................... 38 A210 Loading Racks .......................................................................................................... 40 A211 Fluid Catalytic Cracking Unit (FCC)........................................................................ 41 A212 Cooling Towers......................................................................................................... 43 A213 Wastewater Systems ................................................................................................. 44 Part B GENERAL CONDITIONS ...........................................................................................47 B100 Introduction............................................................................................................... 47 B101 Legal ......................................................................................................................... 47 B102 Authority ................................................................................................................... 49 EPA Inspection Report - Page 139 of 1969 B103 B104 B105 B106 B107 B108 B109 B110 B111 B112 B113 B114 B115 B116 B117 Part C C100 C101 C102 Part D Annual Fee ................................................................................................................ 50 Appeal Procedures .................................................................................................... 50 Submittal of Reports and Certifications.................................................................... 50 NSPS and/or MACT Startup, Shutdown, and Malfunction Operations ................... 51 Startup, Shutdown, and Maintenance Operations..................................................... 51 General Monitoring Requirements ........................................................................... 51 General Recordkeeping Requirements ..................................................................... 53 General Reporting Requirements.............................................................................. 55 General Testing Requirements.................................................................................. 57 Compliance ............................................................................................................... 60 Permit Reopening and Revocation............................................................................ 61 Emergencies .............................................................................................................. 62 Stratospheric Ozone .................................................................................................. 62 Acid Rain Sources..................................................................................................... 63 Risk Management Plan ............................................................................................. 63 MISCELLANEOUS ......................................................................................................64 Supporting On-Line Documents ............................................................................... 64 Definitions................................................................................................................. 64 Acronyms .................................................................................................................. 66 ATTACHMENTS ..........................................................................................................67 PART A FACILITY SPECIFIC REQUIREMENTS A100 Introduction A. PSD-NM-0195-M31 issued August 01, 2011, contained permit limits and control methods based on Best Available Control Technology (BACT). B. The permittee is under a Consent Decree CIV-01 1422LH Lodged 12/20/2001, Entered 3/5/2002 and referenced throughout this document as the "Consent Decree" or "CD" with reference numbers from that document. A101 Permit Duration (expiration) A. The term of this permit is five (5) years. It will expire five years from the date of issuance. Application for renewal of this permit is due twelve (12) months prior to the date of expiration. (20.2.70.300.B.2 and 302.B NMAC) B. If a renewal permit is not issued prior to the expiration date, the permittee may continue to operate beyond the expiration date, provided that a timely and complete renewal application is submitted no later than twelve (12) months prior to the expiration date. (20.2.70.400.D NMAC) EPA Inspection Report - Page 140 of 1969 A103 Facility: Applicable Regulations and Non-Applicable Regulations A. The permittee shall comply with all applicable sections of the requirements listed in Table 103.A. Table 103.A: Applicable Requirements Applicable Requirements NSR Permit No: PSD 0195-M35 (Per 20.2.72 NMAC) 20.2.1 NMAC General Provisions 20.2.7 NMAC Excess Emissions 20.2.33 NMAC Gas Burning Equipment -- Nitrogen Dioxide 20.2.36 NMAC Petroleum Refinery - Sulfur 20.2.37 NMAC Petroleum Processing Facilities 20.2.38 NMAC Hydrocarbon Storage Facilities 20.2.70 NMAC Operating Permits 20.2.71 NMAC Operating Permit Emission Fees 20.2.72 NMAC Construction Permit 20.2.73 NMAC Notice of Intent and Emissions Inventory Requirements 20.2.74 NMAC Prevention of Significant Deterioration 20.2.77 NMAC New Source Performance 20.2.78 NMAC Emission Standards for Hazardous Air Pollutants (HAPs) 20.2.82 NMAC MACT Standards for Source Categories of HAPS 40 CFR 50 National Ambient Air Quality Standards 40 CFR 60, Subpart A, General Provisions 40 CFR 60, Subpart Db "Standards of Performance for IndustrialCommercial-Institutional Steam Generating Units" 40 CFR 60, Subpart Dc "Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units, Which Construction, Reconstruction, or Modification Commenced After June 9, 1989" 40 CFR 60, Subpart J, "Standards of Performance for Petroleum Refineries" 40 CFR 60, Subpart Ja, "Standards of Performance for Petroleum Refineries for which Construction, Reconstruction, or Modification Commenced After May 14, 2007" 40 CFR 60, Subpart K, "Standards of Performance for Storage Vessels for Petroleum Liquids for Which Construction, Reconstruction, or Modification Commenced After June 11, 1973, and Prior to May 19, 1978" Federally Enforceable X X X X X X X X X X X X X X X X X X Unit No. Entire Facility Entire Facility Entire Facility Affected sources in Table 103.E Entire Facility Entire Facility Entire Facility Entire Facility Entire Facility Entire Facility Entire Facility Entire Facility Units subject to 40 CFR 60 Units subject to 40 CFR 61 Units subject to 40 CFR 63 Entire Facility See Tables 103.B to 103.K See Tables 103.B to 103.J X H-0464; H-3101 X See Tables 103.B to 103.J See Tables X 103.B to 103.J See Tables X 103.B to 103.J EPA Inspection Report - Page 141 of 1969 Table 103.A: Applicable Requirements Applicable Requirements 40 CFR 60, Subpart Ka, "Standards of Performance for Storage Vessels for Petroleum Liquids for Which Construction, Reconstruction, or Modification Commenced After May 18, 1978, and Prior to July 23, 1984" 40 CFR 60, Subpart Kb, "Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification Commenced After January 23, 1984" 40 CFR 60, Subpart GGG, Standards of Performance for Equipment Leaks of VOC in Petroleum Refineries for which construction, reconstruction, or modification commenced after January 4, 1983, and on or before November 7, 2006. 40 CFR 60, Subpart GGGa, Standards of Performance for Equipment Leaks of VOC in Petroleum Refineries for which construction, reconstruction, or modification commenced after November 7, 2006. 40 CFR 60, Subpart QQQ, Standards of Performance for VOC Emissions From Petroleum Refinery Wastewater Systems 40 CFR 60, Subpart IIII, Standards of Performance for Stationary Compression Ignition Internal Combustion Engines 40 CFR 61, Subpart A, General Provisions 40 CFR 61, Subpart FF, National Emission Standards for Benzene Waste Operations 40 CFR 63, Subpart A, General Provisions 40 CFR 63, Subpart Q, National Emission Standards for Hazardous Air Pollutants for Industrial Process Cooling Towers 40 CFR 63, Subpart CC 40 CFR 63 Subpart DDDDD 40 CFR 63 Subpart UUU, Petroleum Refineries: Catalytic Cracking Units, Catalytic Reforming Units, and Sulfur Recovery Units 40 CFR 63, Subpart ZZZZ, National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines 40 CFR 68, (RMP), Section 112(r) Accidental Release Consent Decree CIV-01 1422LH Lodged 12/20/2001, Entered 3/5/2002 Note: Tables 103.B through 103.L are located in Attachment D. B. Table 103.B, Summary Applicability - Fugitives C. Table 103.C, Summary Applicability - Tanks Federally Enforceable X X X X X X X X X X X X X X X X Unit No. See Tables 103.B to 103.k See Tables 103.B to 103.K See Tables 103.B to 103.K See Tables 103.B to 103.K See Tables 103.B to 103.K See Tables 103.B to 103.K Entire Facility Benzene Waste Operations Entire Facility See Table 103.F See Tables 103.B to 103.K See Tables 103.B to 103.K See Tables 103.B to 103.KJ See Tables 103.B to 103.KJ Entire Facility Entire Facility EPA Inspection Report - Page 142 of 1969 D. Table 103.D, Summary Applicability - Loading E. Table 103.E, Summary Applicability - Heaters and Boilers F. Table 103.F, Summary Applicability - Cooling Towers G. Table 103.G, Summary Applicability - Wastewater H. Table 103.H, Summary Applicability - FCC-CCR I. Table 103.I, Summary Applicability - SRU J. Table 103.J, Summary Applicability - Engines K. Table 103.K, Summary Applicability - Flares L. Table 103.L lists requirements that are not applicable to this facility. This table only includes those requirements cited in the application as applicable and determined by the Department to be not applicable, or the Department determined that the requirement does not impose any conditions on a regulated piece of equipment. Table 103.L: Non-Applicable Requirements Non-Applicable Requirements (1) (2) Justification For Non-Applicability None X None X 1. Not Applicable For This Facility: No existing or planned operation/activity at this facility triggers the applicability of these requirements. 2. No Requirements: Although these regulations may apply, they do not impose any specific requirements on the operation of the facility as described in this permit. M. Compliance with the terms and conditions of this permit regarding source emissions and operation demonstrate compliance with national ambient air quality standards specified at 40 CFR 50, which were applicable at the time air dispersion modeling was performed for the facility's NSR Permit 0195-M35. A104 Facility: Regulated Sources A. Table 104.A (attached, page 68) lists the emission units authorized for this facility. Emission units that were identified as NSR exempt or Title V Insignificant activities and/or equipment not regulated pursuant to the Act are not included. EPA Inspection Report - Page 143 of 1969 A105 Facility: Control Methods A. Table 105.A lists all the pollution control equipment required for this facility. Each emission point is identified by the same number that was assigned to it in the permit application. Table 105.A: Control Methods: Control Equipment Unit Control Description No. Fluid Catalytic FCC Regenerator Cracking Unit Scrubber Regenerator Cyclones + Wet Gas Scrubber CHLOR SORB CCR Regenerator Vent Control BACT Pollutant being Yes or No controlled NO PM & SO2 NO Chloride FL-0400 North Plant Flare NO VOC & H2S FL-0401 South Plant Flare NO VOC & H2S FL-0402 FCC Flare NO VOC & H2S FL-0403 Alky Flare NO VOC FL-0404 GOH Flare NO VOC & H2S Portable Flare for Holly FL-HEP-PORT Energy Partners (HEP) Pipeline Pigging NO VOC Operations Sulfur Recovery Units H-0473 No. 1 & 2 Tail Gas NO Sulfur Incinerator Selective Catalytic SCR Reduction + ultra-low YES NOx NOx burners Sulfur Recovery Unit SRU3-TGI No. 3 Tail Gas YES Sulfur Incinerator SRU3/TGTU3/TGI3 Best Work Practices, A207.B (BACT) YES SO2 D-0829/0830 Main API Carbon Canisters NO VOC Control for Unit Number(s)1 FCC Regenerator CCR Regenerator Vent Refinery process units Refinery process units Refinery process units Refinery process units Refinery process units Pipeline Pigging Operations SRU1 and SRU2 H-9851 SRU3 SRU3 MAIN API EPA Inspection Report - Page 144 of 1969 Table 105.A: Control Methods: Control Equipment Unit Control Description No. Drift Eliminators on Y-0011, Y-0012 Cooling Towers (BACT) T-0737, T-1225 External Floating Roofs (BACT) See Tables 106.B(1) and (2) External and Internal Floating Roofs (NoneBACT) B-0009 Energy Efficiency, A204.N (BACT) H-2501, H-3402, H- ultra-low NOx burners 3101 (BACT) BACT Yes or No YES YES NO Yes Yes Pollutant being controlled PM VOC VOC Greenhouse Gases NOx SRU-TGI, H-2501, H-3402, H-3101 Combust gaseous fuels only Yes VOC, PM 1 Control for unit number refers to a unit number from the Regulated Equipment List Control for Unit Number(s)1 Y-0011, Y0012 T-0737, T-1225 See Tables 106.B(1) and (2) B-0009 H-2501, H3402, H-3101 SRU-TGI, H2501, H-3402, H-3101 B. In accordance with the requirement that Navajo Refining prevent exceedances of the 24- hour and 3-hour National Ambient Air Quality Standards (NAAQS) for SO2 during major refinery malfunctions, Navajo Refining shall only flare acid gas from existing Flare FL- 0403 according to Navajo Refining's "Phase Two" plan dated January 5, 1996 and received by the Department on January 8, 1996, or from Flare FL-0400. Navajo shall undertake the following measures for acid gas flaring from FL-0400 and FL-0403. (1) Existing Flare FL-0400 shall be equipped CHART NO. 1 SUPP FUEL FOR SO2 NAAQS COMPLIANCE, FL-400 with a flare tip or burners to supply supplemental fuel gas to provide enough 90.0 80.0 heat to supplement the heat released by 70.0 combustion of the acid gas itself and the 60.0 Acid Gas FLow (Mscfh) heat provided by smoke-suppressing 50.0 steam. The minimum flow rate of 40.0 supplemental fuel gas to be supplied 30.0 20.0 during acid gas flaring such that 10.0 compliance with the NAAQS for SO2 is 0.0 assured shall be determined using Chart No. 1. The fuel gas used for this purpose 0 10 20 30 40 50 60 70 Supp Fuel Gas Flow (Mscfh) shall be natural gas (see definition at C101.F). EPA Inspection Report - Page 145 of 1969 (2) Existing Flare FL-0403 shall be equipped with a flare tip or burners to supply supplemental fuel gas to provide enough CHART NO. 2 supplemental heat. The volume of SUPP. FUEL FOR SO2 NAAQS COMPLIANCE, FL-403 40 supplemental fuel gas to be provided to 35 Supp. Fuel Gas generate enough supplemental heat to 30 ensure compliance with NAAQS for SO2 25 shall be determined using Chart No. 2. 20 The supplemental heat to be provided 15 when flaring the maximum quantity of 10 acid gas has been determined to be 52.9 5 million BTU per hour which is generated 0 0 20 40 60 80 100 by burning 96,200 SCFH of supplemental Supp. Fuel Gas (Thousand SCFH) fuel gas. This assumption has been made to ensure compliance with the NAAQS for SO2. The fuel gas used for this purpose shall be natural gas (see definition at C101.F). C. Beginning December 20, 2001 no fuel oil shall be burned in combustion units except as follows: (CD 17.C) (1) Torch Oil may be burned in the FCC Regenerator during FCC start-ups; and. (2) Fuel Oil may be burned in combustion units after the establishment of FCC NOx emissions limits pursuant to permit condition A110.A, provided that emissions from any such combustion units are routed through the FCC Wet Gas Scrubber and Navajo demonstrates, with the approval of EPA, that the NOx emissions limits contained therein and the SO2 emissions limits stated in A106.A and A107.A will continue to be met. D. The Artesia Refinery FCC was initially limited to less than 20,000 BPD capacity. Following the December 2003 expansion of the Artesia refinery's FCC as authorized by permit 195-M15, the catalyst regenerator for the FCC is subject to the minimum requirements for continuous emission monitoring and recording set forth in Appendix P to 40 CFR Part 51. Consent Decree Paragraph 15 required the FCC to be subject to NSPS Subpart J for opacity as of December 31, 2003. A wet gas scrubber was installed in 2003. An Alternative Monitoring Plan (AMP) request was submitted to EPA on December 31, 2003 because a continuous opacity monitoring system (COMS) will not work on a wet gas scrubber exhaust because of the interference from the water vapor. The AMP satisfies the requirements for both NSPS Subpart J and 40 CFR Part 51 Appendix P. A106 Facility: Allowable Emissions A. The following Section lists the emission units, and their allowable emission limits. (See Table 103.A for all applicable regulations) EPA Inspection Report - Page 146 of 1969 Table 106.A: Allowable Emissions (See Part D, and page 82) B. The permitted emission sources at the refinery shall consist only of the sources listed in Table 106.A and Tables 106.B through 106.I of this permit. C. Compliance with Allowable Emission Limits Requirement: The allowable mmBtu/hr, lb/mmBtu, lb/hr, and tpy emission limits for equipment listed in Table 106.A construction of which predates the effective date of 20.2.72 NMAC (August 31, 1972), and have not been modified since August 31, 1972, shall be the "potential emission rate" of that unit as defined in 20.2.72.107 NMAC and the potential to emit of that unit defined under 20.2.74 NMAC. The mmBtu/hr, lb/hr and lb/mmBtu limits are based on an hourly rolling 3-hour average. (NSR 0195M35, Condition A106.C and revised) Monitoring: For units with lb/mmBtu emission limits in Table 106.A, the Permittee shall monitor the lb/mmBtu to demonstrate compliance with the mmBtu/hr, lb/hr, and tpy emission limits. Recordkeeping: To demonstrate compliance, records shall be kept showing the correlation between lb/mmBtu and the mmBtu/hr and lb/hr, and the monthly rolling 12-month tpy totals. The records shall also document any non-compliance with emission limits. For each unit, a summary of the method used to determine compliance shall be recorded. The permittee shall maintain records in accordance with Section B109. Reporting: The permittee shall report in accordance with Section B110. D. BACT SO2 Limit - Fuel sulfur limit Refinery-Wide for all units burning refinery fuel gas (excluding units H-8801, H-8802 and H-9851 which burn only natural gas) shall not exceed 60 ppmv H2S on a daily rolling 365-day average. The ton/yr emission rates for SO2 in Table 106.A of this permit are based on this daily rolling 365-day average 60 ppmv H2S limit. Compliance with this limit shall be demonstrated per the methods described in Condition A110.A. E. BACT NOx Limit - In addition to the emission limits shown in Table 106.A, Boiler Unit B-0009 has a BACT NOx limit of 0.02 lb/MM Btu, and CO2 limit of 112.1 lb/MM Btu. F. BACT SO2 Limit - The Sulfur Recovery Unit No. 3 Tail Gas Incinerator (SRU3-TGI) is limited to 192 ppmvd SO2 at zero percent oxygen on a hourly rolling 12-hour average basis. In addition, SRU3-TGI is limited to 192 ppmvd SO2 at zero percent oxygen on a daily rolling 365-day average basis. G. BACT VOC Limit - The naphtha storage tank T-1225 and sour water storage tank T-0737 shall be equipped with an external floating roof using double seals to reduce VOC emissions to the atmosphere. The maximum true vapor pressure of any volatile organic EPA Inspection Report - Page 147 of 1969 liquid stored in either tank shall not exceed 11.0 psia. Demonstration of compliance is through the NSPS Kb and MACT emission limits. H. VOC - All fugitive piping components in VOC service associated with the process units proposed in Permit 195-M25 (Units FUG-25-ROSE-2, FUG-31-SRU3/TGI3/TGI3, and FUG-34-Hydorcracker) shall be monitored under the MACT subpart CC leak detection and repair program, or an approved equivalent program, to reduce VOC emissions. I. VOC - Consistent with MACT Subpart CC, the gasoline truck loading rack (TLO-4) shall be limited to 10 mg of VOC emissions per liter of gasoline loaded. J. PM10 - Cooling towers, Units Y-0011 and Y-0012, shall be equipped with high-efficiency drift eliminators to reduce PM10 emissions. Demonstration of compliance is through annual inspection in accordance with in Condition A212.B. A107 Facility: Allowable Startup, Shutdown, & Maintenance (SSM) and Malfunction Emissions A. The maximum allowable SSM and Malfunction emission limits for this facility are listed in Table 107.A and were relied upon by the Department to determine compliance with applicable regulations. Table 107.A: Allowable SSM and Malfunction Emissions Units, Activities, and Emission Limits (See Part D, and page 92) B. The authorization of emission limits for startup, shutdown, maintenance, and malfunction does not supersede the requirements to minimize emissions according to Conditions B101.C and B107.A. C. SSM Flaring and combustion Emissions Requirement: The permittee shall comply with the flaring and combustion SSM NOx, CO, VOC, SO2, TSP, PM10, PM2.5, and H2S emission limits at Table 107.A for the following SSM events: 1) SSM H-9851, Emissions during SCR downtime 2) SSM SRU-TGI, Emissions from SRU3 startup and shutdown 3) SSM FL-HEP-PORT, Temporary, portable flare for natural gas pipeline maintenance 4) SSM SRU2-TGI (H-0473), Emissions from SRU2 startup and shutdown 5) SSM Flare Cap, Emissions from venting SSM activity gases to FL-400, FL-401, FL-402, FL-403, or FL-404 6) SSM Misc 2, Low-Emitting Maintenance Activities such as de-inventorying small equipment, clearing piping associated with emission units, and routine maintenance activities such as heat exchanger repair. (NSR 0195M35, Condition A107.C and revised) EPA Inspection Report - Page 148 of 1969 Monitoring: The permittee shall monitor all flaring and combustion due to routine and predictable startups, shutdowns, and scheduled maintenance events. This shall be accomplished by collecting all the SSM flaring and combustion information specified in A107C. Recordkeeping. Recordkeeping: The permittee shall record the date, start and end times, and duration of every SSM flaring or combustion event. The NOx, CO, VOC, SO2, TSP, PM10, and H2S emissions shall be calculated for each event based on the volume of gas sent to the flare and the total sulfur content of the flared gas. Compliance with the hourly emission rates shall be demonstrated by calculating the hourly emission rates for each event and comparing the results to the hourly emission rate at Table 107.A. The annual emission rate shall be calculated as follows: 1) To demonstrate compliance during the first 12 months of monitoring, the permittee shall calculate and sum the monthly cumulative total of NOx, CO, VOC, SO2, TSP, PM10, PM2.5, and H2S emissions; and 2) After the first 12 months of monitoring, the permittee shall calculate and sum the total of NOx, CO, VOC, SO2, TSP, PM10, PM2.5, and H2S emissions on a monthly rolling 12 month basis. 3) The permittee shall maintain all records in accordance with Section B109. Reporting: The permittee shall report in accordance with Section B110. D. SSM VOC Emissions (Facility-Wide, Non-Combustion Sources) Requirement: The permittee shall comply with the SSM VOC emission limit at Table 107.A. Monitoring: The permittee shall monitor all VOC emission activities due to routine and predictable startups, shutdowns, and scheduled maintenance events. This shall be accomplished by collecting VOC emission calculation information for the following SSM VOC emission activities: 1) SSM T-0737, Emissions from roof landing 2) SSM T-0078, Emissions from roof landing and tank refilling 3) SSM T-0079, Emissions from roof landing and tank refilling 4) SSM T-1225, Emissions from roof landing 5) SSM Tanks Miscellaneous Recordkeeping: The annual SSM VOC emission rate shall be calculated as follows: 1) To demonstrate compliance during the first 12 months of monitoring the permittee shall calculate and sum the monthly cumulative total of VOC emissions; and 2) After the first 12 months of monitoring the permittee shall calculate and sum the total of VOC emissions on a monthly rolling 12 month basis, including the methodology and/or assumptions used in the calculation(s). The permittee shall keep records to demonstrate compliance in accordance with Condition B109C, except the requirement in B109.C(2) to record the start and end times of SSM events shall not apply to known quantities of VOC emissions. 3) The permittee shall maintain all records in accordance with Section B109. EPA Inspection Report - Page 149 of 1969 Reporting: The permittee shall report in accordance with Section B110. E. SSM Particulate Emissions (Unit SSM Misc 1) Requirement: The permittee shall minimize particulate emissions due to SSM events. Monitoring: The permittee shall monitor all particulate emissions due to routine and predictable startups, shutdowns, and scheduled maintenance events. For the event type of FCCU Catalyst Loading, the maximum material usage shall not exceed 1 hr-duration, 1 loading event/yr; and 237,048 lb/event/yr. Recordkeeping: For each event, the permittee shall maintain records of the duration in hours, events per year, and material usage for the particulate matter emitting SSM event - FCCU Catalyst Loading. The annual material usage shall be based on monthly rolling 12-month total. The permittee shall maintain all records in accordance with Section B109. Reporting: The permittee shall report in accordance with Section B110. F. SSM and Malfunction Flaring Emissions (SSM Flare Cap and Flares Malf Cap) Requirement: The permittee shall not exceed the pound per hour (pph) and ton per year (tpy) emission limits in Table A107.A and shall demonstrate compliance with these limits by calculating and summarizing these emission rates as required in recordkeeping. Monitoring: A gas flowmeter and flow totalizer, equipped with a chart recorder or electronic data logger, shall be installed in the flare line to measure and record the total standard cubic feet (scf) of all gas (process gas, purge gas, pilot gas, and supplemental fuel gas) sent to the flare during each hour and each month. The permittee shall measure the H2S content, the total sulfur content, the VOC content, and the heating value (Btu/scf) of the gas sent to the flare for combustion. H2S shall be measured at least once every 24-hours on each of the inlet gas types/streams using a stain tube of the appropriate size range or an inline H2S monitor. The total sulfur content, VOC content, and heating value (Btu/scf) of the natural gas sent to the flare shall be measured at least once annually with an extended gas analysis. The flow meter and flow totalizer shall be operated, calibrated, and maintained as specified by the manufacturer and as necessary to ensure correct and accurate readings. If used, the inline monitor shall be operated, calibrated, and maintained as specified by the manufacturer and as necessary to ensure correct and accurate readings. Recordkeeping: The following records shall be kept: stain tube and/or inline H2S measurements annual extended gas analysis both the hourly and monthly volume (scf) of gas sent to the flare Each month, the permittee shall record and summarize in a table format the following. H2S and the total sulfur content EPA Inspection Report - Page 150 of 1969 A109 Facility: Reporting Schedules A. A Semi-Annual Report of monitoring activities is due within 45 days following the end of every 6-month reporting period. The six month reporting periods start on September 1st and March 1st of each year. B. The Annual Compliance Certification Report is due within 30 days of the end of every 12month reporting period. The 12-month reporting period starts on September 1st of each year. C. In addition to the reports required by the applicable NSPS, NESHAP and MACT Subparts (including any voluntary programs referencing NSPS, NESHAP, or MACT Subparts) and by the applicable parts of 20.2 NMAC, the reporting required by the Consent Decree shall be submitted to the Department. The reports shall be submitted to the Air Quality Bureau within forty five (45) days of the end of each calendar quarter. If any reports indicate potential non-compliance with the terms of this permit, the Bureau may impose a more frequent reporting time-frame. The Department shall handle any confidential information in accordance with the provisions of 20.2.1.115 NMAC. D. Reporting required by the Consent Decree (not an exhaustive listing) (1) The permittee shall notify the Department's Enforcement Section, Air Quality Bureau in writing of the annual progress of installation of NOx Control Technology required by Paragraph 16 of the Consent Decree. The report shall be submitted to the EPA and the NMED on or before December 31st of each calendar year commencing with the year 2002. (CD 16.E) (2) No later than forty-five (45) days following the end of an AG Flaring or TG Incident, the permittee shall submit to EPA and the NMED a report that sets forth the items detailed in the Consent Decree. (CD 20, CD21) A110 Facility: Fuel and Fuel Sulfur Requirements (as required) A. Fuel, Fuel Sulfur, and NSPS J, Ja Sulfur Requirements (See Tables 103.E, H, I, & K, Summary of Applicable Requirements) Requirement: (NSR 0195M35, Condition A110.A and revised) (1) To comply with NSPS Subpart J, NSPS Subpart Ja, and the PSD BACT requirements in Section 106, the permittee shall install, calibrate and maintain a continuous monitoring system (CMS) to continuously measure and record either the hydrogen sulfide (H2S) in the refinery fuel gas streams being burned in the Heaters and Boilers or the concentration of sulfur dioxide emissions to the atmosphere. (2) All stationary combustion equipment shall be fired with NSPS quality fuel gas with a maximum H2S content of 0.1 grains/dscf (approx. 162 ppmv), based on a hourly rolling 3-hour average. (3) All stationary combustion equipment shall not combust gas with an annual average sulfur EPA Inspection Report - Page 151 of 1969 content exceeding 60 ppmv (approx. 0.037 grains) as a daily rolling 365-day average. (4) All stationary combustion equipment shall be affected facilities, as defined in NSPS 40 CFR Part 60, Subparts A and J or Ja, if refinery-produced fuel gas is combusted in the heaters and boilers, and shall comply with all applicable requirements of NSPS Subparts A and J or Ja. (See Table 103.E, Summary of Applicable Requirements) Monitoring: (1) The permittee shall install, certify, calibrate, maintain and operate a fuel gas continuous monitoring system (CMS) at the fuel gas mix drum outlet in accordance with the requirements of 40 CFR 60.11, 60.13, and Part 60 Appendix A, and the applicable performance specification of 40 CFR Part 60 Appendices B and F. (2) The following CMS shall be certified initially and recertified annually: D-0019 Low Pressure Fuel Gas H2S CMS D-0770 High Pressure Fuel Gas H2S CMS (3) As required by the EPA-approvable alternative monitoring procedure (AMP), CCR off-gas streams that enter the refinery fuel gas system downstream of the H2S CMS shall be monitored quarterly for H2S using gas detector tubes or an equivalent method as follows: (a) CCR stabilizer off gas stream, (b) H2 recycle gas stream, and c) CCR feed stream. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60, Subparts A, J, and Ja. (1) Records of the quantity of the refinery fuel gas and the monthly average heating value of the refinery fuel gas. This is used to demonstrate compliance with lb/mmBTU and lb/hr limits shown in Table 106.A. (permit limit) (2) Records of repairs, maintenance, and calibrations performed for the instruments that measure flow or concentration for an applicable permit limit shall be kept. Examples include, but are not limited to, CMS, acid gas flow meters, and fuel gas flow meters. (40 CFR 60, Appendix F) (3) Records shall be kept of Alternative Monitoring Plan (AMP) H2S analyses of the CCR offgas streams that enter the refinery fuel gas system downstream of the fuel gas H2S CMS. (NSPS J or Ja) Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subparts A, J, and Ja, and Section B110. A111 Facility: 20.2.36 NMAC A. Facility: 20.2.36 NMAC Requirement: 20.2.36 NMAC (Petroleum Refinery - Sulfur, 11/30/95) applies to the refinery as a whole. Quarterly refinery-wide sulfur balance reports shall be filed in accordance with 20.2.36.113 NMAC. All flares and stacks shall meet the applicable height requirements of 20.2.36.114 NMAC as demonstrated through air dispersion modeling done at the time of unit EPA Inspection Report - Page 152 of 1969 installation. (NSR 0195M35, Condition A111.A) Monitoring: Quarterly monitoring of refinery-wide sulfur balance. Recordkeeping: The permittee shall keep record of a copy of the Facility-Wide Sulfur Balance Report and the actual height of flares and stacks. Reporting: The permittee shall report in accordance with 20.2.36.113A NMAC. A112 Facility: 20.2.37 NMAC A. 20.2.37 NMAC Requirement: (NSR 0195M35, Condition A112.A) (1) Section 200.A (Mercaptans) and section 200.B (Hydrogen Sulfide) apply to mercaptan and H2S emissions from the refinery. Section 200.C applies to FL-0400, FL-0401, FL-0402, FL0403, and FL-0404, and requires an alarm in good working order to signal non-combustion of the gas. (2) Section 201.A (CO), applies to the refinery's FCC regenerator stack. The owner or operator of an existing petroleum processing facility shall not permit, cause, suffer or allow carbon monoxide emissions to the atmosphere from a catalyst cracking recirculation or regeneration unit in excess of 20,000 ppm by volume in the undiluted effluent gas stream or streams. (3) Section 202.C(1) (PM), The owner or operator of a new petroleum processing facility shall not permit, cause, suffer or allow particulate matter emissions to the atmosphere from the catalytic cracking regenerator vessel in excess of 1.0 Kg/1000 Kg (1.0 lb/1000 lb) of coke burnoff or visible emissions of thirty percent (30%) opacity or greater except for one six-minute average opacity reading in any one-hour period. (4) Section 203 (Ammonia, undiluted emissions 25 ppmv) applies to all emission points of the refinery. The owner or operator of a petroleum processing facility shall not permit, cause, suffer or allow ammonia emissions to the atmosphere in excess of 25 ppm by volume in the undiluted effluent gas stream or streams. (5) Section 204 (Hydrocarbon Separation Facility) applies to all oil/water separators at the refinery. Compliance with this condition is met by complying with the applicable NSPS Subpart QQQ requirements. (6) Section 205 (Facilities - Storage - Handling - Pumping - Blowdown System) applies to certain of the following: storage tanks for organic compounds, loading and unloading of organic compounds, seals on pumps and compressors, and disposal (flaring) of hydrocarbon gases. The permittee shall not permit, cause, suffer or allow the operation of a blowdown system without disposing of the gases in a manner which will minimize hydrocarbon emission to the atmosphere. If combustion is the means of disposal, it shall be by: smokeless flare; or any other method that is equally effective to achieve complete combustion. (20.2.37.205.E NMAC) Monitoring: (1) For Units FL-0400, FL-0401, FL-0402, FL-0403, and FL-0404: The permittee shall install EPA Inspection Report - Page 153 of 1969 and maintain a flare pilot flame monitoring system. (20.2.37.200.A.2 NMAC) (2) A CO CMS has been installed to monitoring the emissions from the FCC. (3) The annual EPA Method 9 Opacity Test and annual Stack test on Unit FCC (lb/hr PM emissions) and the calculated Coke burn rate will be used for the annual determination of pounds of PM per 1000 pounds of Coke burned. (4) None (5) No additional monitoring since compliance is met by complying with the applicable NSPS Subpart QQQ requirements. See other conditions of this permit for applicable NSPS or MACT requirements. (6) Compliance is demonstrated through NSPS K, NSPS Ka, NSPS Kb, or MACT CC for Tanks; through MACT CC for Loading Racks; through NSPS GGG, NSPS GGGa or MACT CC for Pumps and Compressors; and through NSPS Subpart A for Blowdowns. Recordkeeping: (1) Pilot flame monitoring records (2) CO CMS measurements (3) Copy of annual coke burn rate determination, stack test report, and opacity test report (4) None (5) Applicable NSPS Subpart QQQ requirements (6) Applicable NSPS K, NSPS Ka, NSPS Kb, or MACT CC for Tanks; through MACT CC for Loading Racks; through NSPS GGG, NSPS GGGa or MACT CC for Pumps and Compressors; and through NSPS Subpart A for Blowdowns requirements Reporting: The permittee shall report in accordance with applicable NSPS or MACT requirements and Section B110. A113 Facility: 20.2.38 NMAC A. 20.2.38 NMAC Requirement: 20.2.38 NMAC (Hydrocarbon Storage Facilities, 11/30/95) applies to the refinery as follows: 1. Section 109 (Tank Storage Associated with Petroleum Production or Processing Facility [Sour Hydrocarbon Liquids]) applies to the loading and storing of hydrocarbons containing H2S. 2. Section 110 (Tank Battery or Storage Facility - Within Municipality [Sour Hydrocarbon Liquids]) applies to certain tanks storing sour hydrocarbon liquids whose vapors contain >24 ppm H2S. 3. Section 113 (New Tank Battery and the Pecos-Permian Interstate Air Quality Control Region [Sour Hydrocarbon Liquids]) applies to certain tanks storing sour hydrocarbon liquids whose EPA Inspection Report - Page 154 of 1969 vapors contain >24 ppm H2S. (NSR 0195M35, Condition A113.A) Monitoring: 1. None 2. and 3. Demonstrated through NSPS K, Ka, Kb, and MACT CC floating roof seal inspection. Recordkeeping: 1. Records of Tank design showing inlet piping connections. 2. and 3. No additional requirements other than applicable requirements of NSPS and MACT. Reporting: The permittee shall report in accordance with Section B110. A114 Facility: Relocation Requirements - Not Required A115 Alternative Operating Scenario - Not Required A116 Compliance Plan - Not Required A117 Reducing Facility Emissions - Not Required A118 Facility: MACT Subpart UUU A. 40 CFR 63, Subpart UUU FCC, FUG-70-CCR, SRUs 1, 2,and 3 Requirement: The permittee shall comply with all applicable requirements of 40 CFR 63, Subpart UUU, National Emission Standards for Hazardous Air Pollutants for Petroleum Refineries: Catalytic Cracking Units, Catalytic Reforming Units, and Sulfur Recovery Units, for all affected sources shown in Tables 103H&I attached. (63.1560 and 63.1570). Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 63, Subpart UUU. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 63, Subpart UUU. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 63, Subpart UUU. A119 40 CFR 61 Subpart FF, National Emission Standard for Benzene Waste Operations A. 40 CFR 61 Subpart FF, National Emission Standard for Benzene Waste Operations (Units subject in Table 103.C & G) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 61, Subpart FF, National Emission Standard for Benzene Waste Operations for the affected sources EPA Inspection Report - Page 155 of 1969 in Tables 103.C, G. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 61, Subpart FF. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 61.356. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 61.357. EQUIPMENT SPECIFIC REQUIREMENTS OIL AND GAS INDUSTRY A200 Oil and Gas Industry A. This section has common equipment related to most Oil and Gas Operations. A201 Engines A. Maintenance and Repair Monitoring (Units G-0100, G-0101, V-0543, V-0545, V-0546, E8010, E-0600W, E-0601M, E-0602E, E-0603, and E-0901; Units G-0100, G-0101, V-0543, V-0545, V-0546, E-8010, E-0600W, E-0601M, E-0602E, E-0603, and E-0901) Requirement: These units are subject to Title V since they are subject to NSPS and/or MACT requirements. No emission limits were established since their emissions are small. The permittee shall ensure these units are properly maintained and repaired. Monitoring: Maintenance and repair shall meet the minimum manufacturer's or permittee's recommended maintenance schedule. Activities that involve maintenance, adjustment, replacement, or repair of functional components with the potential to affect the operation of an emission unit shall be documented as they occur for the following events: (1) Routine maintenance that takes a unit out of service for more than two hours during any twenty-four hour period. (2) Unscheduled repairs that require a unit to be taken out of service for more than two hours in any twenty-four hour period. Recordkeeping: The permittee shall maintain records in accordance with Section B109, including records of maintenance and repairs activities and a copy of the manufacturer's or permittee's recommended maintenance schedule. Reporting: The permittee shall report in accordance with Section B110. EPA Inspection Report - Page 156 of 1969 B. 40 CFR 63, Subpart ZZZZ (Units G-0100, G-0101, V-0543, V-0545, V-0546, E-8010, E0600W, E-0601M, E-0602E, E-0603, and E-0901) (Units subject in Table 103.J) Requirement: The units listed as subject in Table 103.J are subject to 40 CFR 63, Subpart ZZZZ and the permittee shall comply with all applicable requirements of Subpart A and Subpart ZZZZ. Monitoring: The permittee shall comply with all applicable monitoring and testing requirements of 40 CFR 63, Subpart A and Subpart ZZZZ. Recordkeeping: The permittee shall comply with all applicable recordkeeping requirements of 40 CFR 63, Subpart A and Subpart ZZZZ, including but not limited to 63.6655 and 63.10. Reporting: The permittee shall comply with all applicable reporting requirements of 40 CFR 63, Subpart A and ZZZZ, including but not limited to 63.6645, 63.6650, 63.9, and 63.10. C. 40 CFR 60, Subpart IIII (Diesel Engines subject in Table 103.J) Requirement: The units listed as subject in Table 103.J are subject to 40 CFR 60, Subparts A and IIII and shall comply with the notification requirements in Subpart A and the specific requirements of Subpart IIII. Monitoring: The permittee shall comply with all applicable monitoring and testing requirements in 40 CFR 60, Subpart A and Subpart IIII, including but not limited to 60.4211. Recordkeeping: The permittee shall comply with all applicable recordkeeping requirements in 40 CFR 60, Subpart A and Subpart IIII, including but not limited to 60.4214. Reporting: The permittee shall comply with all applicable reporting requirements in 40 CFR 60, Subpart A and Subpart IIII, including but not limited to 60.4214. A202 Glycol Dehydrators - Not Required A203 Tanks A. NSPS Subpart K, Standards of Performance for Storage Vessels for Petroleum Liquids for Which Construction, Reconstruction, or Modification Commenced After June 11, 1973, and Prior to May 19, 1978 (Tanks subject in Table 103.C) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 60, Subparts A & K for the affected sources in Table 103.C. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart K. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60, Subpart K. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart K. EPA Inspection Report - Page 157 of 1969 B. NSPS Subpart Ka, Standards of Performance for Storage Vessels for Petroleum Liquids for Which Construction, Reconstruction, or Modification Commenced After May 18, 1978, and Prior to July 23, 1984 (Tanks subject in Table 103.C) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 60, Subparts A & Ka for the affected sources in Table 103.C. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart Ka. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60, Subpart Ka. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart Ka. C. NSPS Subpart Kb, "Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification Commenced After January 23, 1984" (Tanks subject in Table 103.C) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 60, Subparts A & Kb for the affected sources in Table 103.C. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart Kb. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60, Subpart Kb. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart Kb. D. MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" (Tanks subject in Table 103.C) Requirement: The permittee shall comply with all applicable requirements of MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" for all affected sources shown in Table 103.C attached. (63.640). Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 63, Subpart CC. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 63.655. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 63.655. E. Tank Throughput, Temperature, and VOC and H2S Limits (Units shown in Tables 106.B & C) EPA Inspection Report - Page 158 of 1969 Requirement: Compliance with the allowable throughput limits and emission limits in Table 106.D & E shall be demonstrated by not exceeding the monthly rolling 12-month total throughput to the unit(s) of gallons per year (barrels/year) shown in Table 106.D and not exceeding the allowable vapor pressure listed in Tables 106.B & C. Monitoring: The permittee shall monitor the monthly total throughput, maximum temperature once per month and the vapor pressure of each tank. Recordkeeping: The permittee shall record the monthly total throughput of liquids and the vapor pressure of each tank. Each month, during the first 12 months of monitoring, the permittee shall record the cumulative total liquid throughput and vapor pressure and after the first 12 months of monitoring, the permittee shall calculate and record a monthly rolling 12month total liquid throughput and the vapor pressure of each tank. The permittee has calculated the VOCs and H2S annually based on the 12-month total. Tank breathing and working emissions were calculated using the USEPA Tanks program Version 4.0.9.d or more current. Emission rates computed using the same parameters, but with a different Department approved algorithm that exceed these values will not be deemed noncompliance with this permit. Records shall also be maintained in accordance with Section B109. Reporting: The permittee shall report in accordance with Section B110. A204 Heaters/Boilers A. Operational Inspection (All heaters/boilers in Tables 103.E & 104.A) Requirement: Compliance with the allowable emission limits in Table 106.A shall be demonstrated by performing periodic inspections to ensure proper operations. Monitoring: The permittee shall conduct annual operational inspections to determine that the heater(s)/boiler(s) are operating properly. The operational inspections shall include operational checks for indications of insufficient excess air, or too much excess combustion air. These operational checks shall include observation of common physical indications of improper combustion, including indications specified by the heater/boiler manufacturer, and indications based on operational experience with the/these unit(s). Recordkeeping: The permittee shall maintain records of operational inspections, describing the results of all operational inspections noting chronologically any adjustments needed to bring the heater(s)/boiler(s) into compliance. The permittee shall maintain records in accordance with Section B109. Reporting: The permittee shall report in accordance with Section B110. Within ninety (90) days of permit issuance, the permittee shall submit for Department approval a procedure which the permittee will use to carry out the operational inspections. The permittee may at any time submit revisions for Department approval. EPA Inspection Report - Page 159 of 1969 B. Periodic Emissions Tests (Units Heaters H-0019, H-0020, H-0362, H-0363, H-0364, H2421, H-3402, and H-3403) Requirement: Compliance with allowable emission limits in Table 106.A shall be demonstrated by performing periodic emissions tests. (NSR 0195M35, Condition A204.A, revived) Monitoring: The permittee shall conduct annual periodic portable analyzer emission tests or EPA Reference Method Tests for NOx and CO. Test results that demonstrate compliance with the CO emission limits shall also be considered to demonstrate compliance with the VOC emission limits. Section B108 General Monitoring Requirements apply to this condition. The permittee shall meet the testing requirements in Section B111. Recordkeeping: Records of periodic emission tests shall include the flow rate and the stack gas exhaust temperature. If a combustion analyzer is used to measure NOx, CO, and/or excess air in the flue gas, records shall be kept of the make and model of the instrument and instrument calibration data. If an ORSAT apparatus or other gas absorption analyzer is used, the permittee shall record all calibration results. Records shall be kept of all raw data used to determine flue gas flow and of all calculations used to determine flow rates and emission rates. The permittee shall maintain records in accordance with Section B109, B110, and B111. Reporting: The permittee shall summarize in tabular form the results of the initial or subsequent periodic emissions tests for NOx and CO, specifying the mass emissions rates in pounds per hour. The table shall include the average concentration of all relevant pollutant species. The permittee shall report in accordance with Section B109, B110, and B111. C. Summary of Compliance Methods for Heaters and Boilers for Table 106.A, 20.2.33 NMAC, 20.2.37 NMAC (Boilers and Heaters in Tables 103.E and 104.A) Requirement: (NSR 0195M35, Condition A204.B) (1) Demonstrate compliance with Table 106.A Allowable Emissions. (2) 20.2.33 NMAC (Gas Burning Equipment - Nitrogen Dioxide, 10/31/02) applies to existing and new gas burning equipment having a heat input of greater than 1,000,000 million British Thermal Units per year. It applies to process heaters identified in Tables 103.E and 104.A. These units shall be equipped with burners emitting less than 0.2 lb NOx per MM Btu. Compliance with 20.2.33 NMAC is demonstrated by compliance with the NOx lb per MM Btu limits in Table A106.A. Monitoring: (1) The permittee shall monitor the fuel usage of the all boilers and heaters. The fuel usage shall be monitored for specific heaters and boilers subject to 20.2.33 NMAC. (2) For specific heaters and boilers subject to 20.2.33 NMAC, the permittee shall collect and analyze samples of the refinery fuel gas at least once per week. The refinery fuel gas analysis EPA Inspection Report - Page 160 of 1969 shall include the composition of the refinery fuel gas, the gross heating value, and the net heating value. (3) See Condition A110.A for H2S monitoring requirements. (4) All process heaters and boilers shall fire only refinery gas in accordance with Application, Section 2, Table 2-J. (5) For those combustion sources required to have a continuous monitoring system (CMS) (listed in (a) below), the permittee shall install, certify, calibrate, maintain, and operate the CMS for each required pollutant in accordance with the applicable requirements of 40 CFR 60 or 63. The hourly average CMS data, the refinery fuel gas usage data, and the refinery fuel gas composition data shall be used to estimate the actual emission rates. (a) The following CMS shall be recertified annually: Boiler B-0007 NOx and O2 CMS Boiler B-0008 NOx and O2 CMS Boiler B-0009 NOx and O2 and CO2 CMS H-9851 NOx O2 CMS H-2501 NOx O2 CMS (6) For those combustion sources required to conduct periodic stack exhaust testing as stated in Condition A204.B, the test reports shall be used to demonstrate compliance with the NOx, CO, and VOC limits in Table 106.A. (7) For those units and pollutants that are not required to have a CMS or a periodic stack test, (Units H-009, H-0011, H-0018, H-0028, H-0030, H-0040, H-0303, H-0312, H-0352, H-0353, H-0354, H-0355, H-0421, H-0464, H-0473, H-0600, H-0601, H-8801, H-8802, and H-3101) the permit application emission factor, the fuel usage, and the refinery fuel gas analysis shall be used to calculate the emission rates of NOx, CO, VOC, and PM. (8) Compliance with the particulate emission limitation set forth in 20.2.37.202.A NMAC shall be determined as specified in 20.2.37.202.D(3) NMAC. Combustion of only gaseous fuel has been approved by the Department as the compliance method under 20.2.37.202.D(3) NMAC. Recordkeeping: The permittee shall maintain the following records: (1) By March 31, the annual fuel usage for all boilers and heaters for the previous calendar year. (2) By March 31, the average fuel composition and heating value for all boilers and heaters for the previous calendar year. (3) For those units required to have a CMS (B-0007, B-0008, B-0009, H-9851 and H-2501), the CMS hourly average data. (4) For those units required to conduct periodic stack exhaust testing, the periodic test report. (5) For all boilers and heaters, a summary spreadsheet shall be maintained comparing the actual annual emissions with the allowable emission limits expressed in tons per year and lb/MMBtu using the appropriate method of compliance demonstration. This spreadsheet shall EPA Inspection Report - Page 161 of 1969 be updated by March 31 of each year for the previous calendar year. Reporting: The permittee shall report in accordance with Sections B110. D. Consent Decree NOx Emission Limits for Boilers B-0007, B-0008, and B-0009 (new as of 2013) Requirement: (NSR 0195M35, Condition A204.C) (1) In accordance with the Consent Decree lodged December 20, 2001, NOx emissions from boilers B-0007 (no later than December 31, 2002), B-0008 (no later than December 31, 2003), and B-0009 (new as of 2013) shall not exceed the limit in Table 106.A during any hourly rolling 3-hour period. Demonstration of compliance with the NOx limit for B-0007, B-0008, and B-0009 shall be established by averaging the CMS Data over any 3-hour period and comparing the average concentration to the parametric limit of 42.1 ppm NOx, corrected to 6.1% O2 as determined by the CMS. (CD16.D) This also satisfies the requirement in 20.2.33.108.A NMAC that NOx emissions shall not exceed 0.2 lb/MMBTU. (2) Navajo is authorized to operate all three boilers (B-0007, B-0008, and B-0009) simultaneously as needed. Monitoring: For the Controlled Boilers (B-0007, B-0008) as listed in the Consent Decree and B-0009 (new as of 2013), continuous compliance with their respective NOx permit emissions limits shall be demonstrated by monitoring as follows: (CD16.C) (1) For boilers (B-0007, B-0008, and B-0009) with a heat input capacity greater than 150 MMBTU/hr of HHV, the permittee shall install or continue to operate CMS to measure NOx and O2. Each CMS shall be installed, certified, calibrated, maintained, and operated in accordance with the requirements of 40 CFR 60.11, 60.13, and Part 60 Appendix A and the applicable performance specification test of 40 CFR Part 60 Appendices B and F. These CMS shall be used to demonstrate compliance with emission limits. The permittee shall make CMS and process data available to the applicable Federal and State Agencies upon demand as soon as practicable; (CD16.C.i) Recordkeeping: The permittee shall keep records of the CMS recertification's monitored in Condition A204.B, Summary of Compliance. Reporting: The permittee shall report in accordance with Section B110. E. NOx Monitoring and Testing for Controlled Heaters Subject to the Consent Decree (Units H-0020, H-0352, H-0353, H-0354, H-0600, and H-0601) Requirement: For the Controlled Heaters as listed in the Consent Decree, continuous compliance with all NOx emissions limits shall be demonstrated by monitoring as follows. (CD16.C) (NSR 0195M35, Condition A204.D) Monitoring: EPA Inspection Report - Page 162 of 1969 (1) For heaters with a heat input capacity of equal to or less than 150 MMBTU/hr (HHV) but greater than 100 MMBTU/hr (HHV), Navajo shall (a) install or continue to operate CMS to measure NOx and O2 by no later than the date of the installation of the applicable NOx Control Technology on the heater or boiler; or (b) submit for EPA approval, by no later than 60 days after the date of installation of the applicable NOx Control Technology on the heater or boiler, a proposal for monitoring based on operating parameters, including but not limited to, firebox temperature, air preheat temperature, heat input rate, and combustion O2. Navajo shall evaluate the necessity of using firebox or bridgewall temperatures and additional operating parameters and agrees to use such parameters as a means of monitoring performance where Navajo and EPA mutually-agree to their effectiveness. (CD16.C.ii). As of January 23, 2014 (notarized date of application), there are no heaters or boilers at the Artesia Refinery with a capacity of equal to or less than 150 MMBTU/hr (HHV) but greater than 100 MMBTU/hr (HHV) subject to Monitoring requirement (1). (2) For heaters with a heat input capacity of equal to or less than 100 MMBTU/hr of HHV, the permittee shall conduct an initial performance tests for NOx. The results of these tests shall be reported based upon an average of three (3) one-hour testing periods and shall be used to develop representative operating parameters for each unit, which will be used as indicators of compliance. (CD16.C.iii). This condition applies to the following heaters: Heaters H-0352, H-0353, and H-0354 Heater H-0020 Heaters H-0600 and H-0601 The permittee has completed all of the initial performance tests. (3) For heater H-0601 compliance shall be demonstrated by continuously monitoring stack oxygen (O2) to maintain a 3-hour average below 6.0 vol%. As a further check of compliance, Navajo shall monitor stack NOx at least twice a month using a portable analyzer to assure that the measured NOx value does not exceed the compliance threshold of 38 ppmv NOx. (CD16.C.iii) Recordkeeping: (1) The permittee shall keep records of the Fuel firing rates and Sulfur limits monitored for Condition A110.A. (2) The permittee shall keep records of the initial performance tests. (3) The permittee shall keep records of the stack oxygen monitoring and the portable analyzer tests. Reporting: The permittee shall report in accordance with Section B110. Condition B.111.D(7) does not apply to portable analyzer tests. EPA Inspection Report - Page 163 of 1969 F. NOx Monitoring and Testing for Heaters permitted after the Consent Decree (Units Heaters H-0019, H-0362, H-0363, H-0364, H-2421, H-3402, H-3403, H-2501, H8801/8802, and H-9851) Requirement: For the Heaters permitted after the Consent Decree, continuous compliance with their respective NOx permit emissions limits in Table 106.A shall be demonstrated by monitoring as follows. (NSR 0195M35, Condition A204.E) Monitoring: (1) For heaters with a heat input capacity greater than 150 MM Btu/hr (LHV Basis), the permittee shall install and operate CMS to measure NOx and O2 by the startup date of each heater. Each CMS shall be installed, certified, calibrated, maintained, and operated in accordance with the requirements of 40 CFR 60.11, 60.13, and Part 60 Appendix A and the applicable performance specifications of 40 CFR Part 60 Appendices B and F. These CMS shall be used to demonstrate compliance with emission limits. The permittee shall make CMS and process data available to the applicable Federal and State Agencies upon demand as soon as practicable. Condition A204.F(1) applies to heater H-9851. (2) For heaters with a heat input capacity of equal to or less than 150 MM Btu/hr (LHV) but greater than 100 MM Btu/hr (LHV), Navajo shall: (a) install and operate CMS to measure NOx and O2 by the startup date of each heater; or (b) submit to the Permit Program Manager for NMED approval, by no later than 90 days after the startup date of each heater, a proposal for monitoring based on operating parameters. Operating parameters to consider include, but are not limited to, firebox temperature, air pre-heat temperature, heat input rate, and combustion O2. Navajo agrees to use such parameters as a means of monitoring performance. Condition A204.F(2) applies to heaters H-2501 and H-8801/8802 (3) For heaters with a heat input capacity of equal to or less than 100 MM Btu/hr (LHV basis), the permittee shall conduct an initial performance test by no later than 180 days after the startup date. The results of this test shall be reported based upon an average of three (3) onehour testing periods and shall be used to develop representative operating parameters for each unit, which will be used as indicators of compliance. This condition applies to the following heaters: Heaters H-0362, H-0363, H-0364, and H-2421 Heater H-0019 Heaters H-3402 (AMP approved by EPA, see (4)) , initial performance test completed on July 10, 2013 Heater H-3403, initial performance test completed on April 30, 2013 (4) US EPA has approved an Alternative Monitoring Plan (AMP) for Unit H-3402 for utilizing the oxygen monitor on the H-3402 Unit 34 Hydrocracker Reboiler 1 as a parametric means for demonstrating compliance with NSPS Ja, NOx monitoring via a CMS. In accordance with the AMP, the permittee shall accomplish the following: EPA Inspection Report - Page 164 of 1969 (a) Install flow indication on the fuel line to provide historical data of the fuel to the Mild Hydrocracker (Unit 34) by January 1st, 2015. (b) Monitor the process historical data of the HEP purchased natural gas pressure, and the high pressure fuel balance drum (D-0770). (c) Upgrade the existing the Mild Hydrocracker (Unit 34) Reboiler Heater (H-3402) oxygen monitor to perform daily calibrations as required in 40 CFR60.13(d)(1). (Note that the sample placement does not conform to CMS requirements for process reasons). (d) Conduct biennial performance tests according to the requirements in 40CFR 60.104a(i). (e) Establish a maximum or curve excess O2 operating limit - (MOPV) as required under 40 CFR60.107a(c)(6) utilizing the existing monitor. (f) Include Reboiler Heater (H-3402) hours of refinery fuel gas usage and any deviations during such time as required by 40 CFR 60.7 for periodic reporting. Recordkeeping: (1) The permittee shall keep records of the monitoring proposals submitted to the Permit Program Manager for approval and whether the submittal was approved. (2) The permittee shall keep records of the CMS data, calibration, and recertification's monitored in Condition A204.A, Summary of Compliance. (3) The permittee shall keep records of the performance tests. (4) The permittee shall keep records of the implementation of the AMP and all required monitoring specified in the AMP. Reporting: The permittee shall report in accordance with Section B110. G. NSPS Subpart Db, Standards of Performance for Industrial-Commercial-Institutional Steam Generating Units (Boilers and heater subject in Table 103.E) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 60, Subparts A & Db (NOx-60.44b, SO2-60.42b, & PM-60.43b) for the affected sources in Table 103.E. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60.48b, Subpart Db. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60.49b, Subpart Db. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60.49b, Subpart Db. Compliance Test: The permittee shall comply with the methods and procedures stipulated in 40 CFR 60, Section 60.45b and 60.46b. EPA Inspection Report - Page 165 of 1969 H. NSPS Subpart Dc, Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units (Boilers and heater subject in Table 103.E) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 60, Subparts A & Dc (NOx-60.44c, SO2-60.42c, & PM-60.43c) for the affected sources in Table 103.E. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60.47c, Subpart Dc. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60.48c, Subpart Dc. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60.48c, Subpart Dc. Compliance Test: The permittee shall comply with the methods and procedures stipulated in 40 CFR 60, Section 60.44c and 60.45c. I. NSPS Subpart J, Standards of Performance for Petroleum Refineries (Boilers and heater subject in Table 103.E) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 60, Subparts A & J for the affected sources in Table 103.E. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart J. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60, Subpart J. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart J. J. NSPS Subpart Ja, Standards of Performance for Petroleum Refineries for which Construction, Reconstruction, or Modification Commenced After May 14, 2007 (Boilers and heater subject in Table 103.E) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 60, Subparts A & Ja for the affected sources in Table 103.E. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart Ja. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60, Subpart Ja. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart Ja. K. BACT NOx Limit, Continuous Monitoring System (CMS) (Unit B-0009) EPA Inspection Report - Page 166 of 1969 Requirement: The permittee shall comply with the allowable emission limits in Table 106.A and Condition A106.E that represent NOx BACT limits for the BACT requirements. (NSR 0195M35, Condition A204.I and revised) Monitoring: (1) The Permittee shall comply with the CMS monitoring as detailed in Condition A204.D. (2) The permittee shall conduct an EPA Method test within six (6) months of permit issuance using EPA reference test methods in 40 CFR 60 for NOx and O2 and CO2. Data from the CMS RATA testing may be used to satisfy this testing requirement. Recordkeeping: (1) The permittee shall keep records of the CMS initial calibration and recertification monitored in Condition A204.B, Summary of Compliance. (2) Records of EPA Methods tests shall be maintained for the Boiler. Reporting: (1) The permittee shall report in accordance with Section B110, to include the CMS initial calibration and recertification. (2) The permittee shall summarize in tabular form the results of the EPA Methods tests for NOx and O2 and CO2, specifying the emissions rates in pounds per hour and lb/MMBtu. The table shall include the average concentration of all relevant pollutant species. L. MACT Subpart DDDDD, Industrial, Commercial, and Institutional Boilers and Process Heaters (Boilers and heater subject in Table 103.E) Requirement: The units are subject to 40 CFR 63, Subpart DDDDD and the permittee shall comply with the applicable requirements of 40 CFR 63, Subpart A and Subpart DDDDD. Monitoring: The permittee shall comply with all applicable monitoring and testing requirements of 40 CFR 63, Subpart A and Subpart DDDDD. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 63, Subpart A and Subpart DDDDD. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 63, Subpart A and Subpart DDDDD. M. EPA Methods Test (Unit B-0009) Requirement: Compliance with CO BACT Limit and allowable emission limits in Table 106.A shall be demonstrated by emissions tests ensuring the unit is operating correctly and within desired parameters. (NSR 0195M35, Condition A204.K and revised) Monitoring: The permittee shall conduct an EPA Method test no later than 180 days after permit issuance using EPA reference test methods in 40 CFR 60. Emission testing is required for CO. Test results that demonstrate compliance with the CO EPA Inspection Report - Page 167 of 1969 emission limits shall also be considered to demonstrate compliance with the VOC emission limits. Recordkeeping: Records of EPA Methods tests shall be maintained for the Boiler. Reporting: The permittee shall report in accordance with the requirements of Section B111.D and summarize in tabular form the results of the EPA Methods test for CO, specifying the emissions rates in pounds per hour. The table shall include the average concentration of all relevant pollutant species. N. Verification of Energy Efficiency BACT Control Requirements (Unit B-0009) Requirement: The permittee shall comply with the allowable emission limits and the following BACT requirements. (NSR 0195M35, Condition A204.L and revised) 1. Operation and Maintenance (BACT #6): a. Periodic Boiler Tuning - The boiler shall be tuned annually to maintain optimal thermal efficiency. b. Periodic Boiler Inspection and Repair for air leakage - The boiler shall be inspected annually to maintain optimal thermal efficiency. c. Periodic Boiler Inspection and Cleaning for tube fouling - The boiler shall be inspected annually and necessary cleaning performed to prevent tube fouling. 2. Next Generation Ultra-low-NOx high efficiency burners (NGULNB) (#5) shall be installed in the boiler design. 3. Flue gas economizer (BACT #2) - A heat exchanger shall be installed to recover heat from the exhaust gas to preheat incoming boiler feedwater to attain industry standard performance (IMO) for thermal efficiency. 4. Boiler insulation (BACT #4) - The boiler shall be designed and installed with boiler insulation to an optimum insulation thickness and material to achieve maximum energy efficiency. The OMP shall include the insulation design and maintenance schedule. 5. Oxygen Trim Control (BACT #7) - An Oxygen Trim Control system shall be designed and installed on the boiler to monitor oxygen concentration in the flue gas, and the inlet air flow is adjusted to maximize thermal efficiency. 6. Boiler blowdown minimization using manual analysis (BACT #3) - The Operation and Maintenance Plan (OMP) shall include methods and procedures to minimize blowdowns from the boiler to keep emissions at a minimum. 7. Condensate recovery (BACT #8): Condensate shall be recovered as represented in the application to achieve maximum energy efficiency. Condensate recovery shall be maximized through annual steam trap inspections and repairs. Monitoring: The Permittee shall develop an Operation and Maintenance Plan (OMP) to include at least the requirements listed above within 12 months of commencement of operations. The Permittee shall review the OMP annually to ensure it's effectiveness in EPA Inspection Report - Page 168 of 1969 meeting the requirements above and recommend changes. Recordkeeping: (1) Records demonstrating compliance with the energy efficiency requirement shall be recorded and summarized in the OMP. (2) The Permittee shall maintain a copy of the OMP onsite and available for inspection. Reporting: (1) The permittee shall notify the Department when the OMP has been prepared and available for review. (2) The permittee shall report in the semi-annual report a summary of actions covered in accordance with the OMP, and in accordance with Section B110. O. Periodic Emissions Tests (Unit B-009, CO BACT Limit) Requirement: Compliance with the CO BACT Limit and allowable emission limits in Table 106.A shall be demonstrated by performing periodic emissions tests. Monitoring: The permittee shall conduct periodic portable analyzer emission tests or EPA Reference Method Tests for CO at the intervals in the following schedule: First Test --- in accordance with the schedule in Section B111.A(2). Second Test --six (6) months after the first test is completed. All subsequent testing shall be done annually. Section B108 General Monitoring Requirements apply to this condition. The permittee shall meet the testing requirements in Section B111. Recordkeeping: Records of periodic emission tests shall include the boiler fuel flow rate and the stack gas exhaust temperature. If a combustion analyzer is used to measure CO, and/or excess air in the flue gas, records shall be kept of the make and model of the instrument and instrument calibration data. If an ORSAT apparatus or other gas absorption analyzer is used, the permittee shall record all calibration results. Records shall be kept of all raw data used to determine flue gas flow and of all calculations used to determine flow rates and emission rates. The permittee shall maintain records in accordance with Section B109, B110, and B111. Reporting: The permittee shall summarize in tabular form the results of the initial or subsequent periodic emissions tests for CO, specifying the mass emissions rates in pounds per hour. The table shall include the average concentration of all relevant pollutant species. The permittee shall report in accordance with Section B109, B110, and B111. A205 Turbines not required EPA Inspection Report - Page 169 of 1969 A206 Flares A. FL-0400, FL-0403 Requirement: (NSR 0195M35, Condition A206.A) (1) An alarm system in good working order shall be connected to Flare FL-0403 which will signal non-combustion of the gas. (2) The acid gas flow meter for flare FL-0400 or FL-0403 shall be operated and calibrated at a frequency and by the procedure specified by the manufacturer. A chart recorder or data logger (electronic storage) shall continuously record the amount of gas measured by the flow meter. Monitoring: The fuel gas required to provide supplemental heat to either Flare FL-0400 or FL-0403 as required under A105.B shall be monitored during flaring by a flow meter. The flow meter shall be operated continuously 24 hours per day, 365 days per year except for periods of flow meter maintenance or repair. The upper range of the flow meter shall be sufficient to record the highest expected flow rate of fuel gas sent to flare. The reading of this flow meter and the flow meter to measure acid gas flow as required under Condition A105.B shall be used to determine compliance with emission limits at A106.C. Recordkeeping: (1) Records of all periods of operation during which the flare pilot flame is absent as included in the MACT subpart CC semi-annual reports. (2) Records of the quantity of supplemental fuel used during each acid gas flaring incident to provide supplemental heat to flare FL-0400 or flare FL-0403. (3) The permittee shall maintain records from the flow meter of the amount of gas sent to the flare. Reporting: The permittee shall report in accordance with Section B110. B. MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" (Flares listed in Table 103.K) Requirement: The permittee shall comply with all applicable requirements of MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" for all affected sources shown in Tables 103.B. (63.640). Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 63, Subpart CC. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 63.655. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 63.655. EPA Inspection Report - Page 170 of 1969 A207 Sulfur Recovery Plant (SRP), Tail Gas Incinerator (TGI) A. Consent Decree Requirements for SRP and TGI Requirement: In addition to the applicable requirements of NSPS, 40 CFR 60, Subparts J and Ja, the permittee shall accomplish the following: 1. Navajo shall route all Sulfur Recovery Plant (SRP) sulfur pit emissions from the SRP so that sulfur pit emissions to the atmosphere either are eliminated or are included and monitored as part of the applicable Sulfur Recovery Plant's tail gas emissions that meet the NSPS Subpart J or Ja limit for SO2. (CD 18.C.ii) 2. The SRP and TGI (and any supplemental control devices) shall be operated and maintained, to the extent practicable, in accordance with the obligation to minimize SRP emissions through implementation of good air pollution control practices required by 40 CFR 60.11(d), at all times, including periods of start-up, shutdown, and malfunction. (CD 18.C.iii) (NSR 0195M35, Condition A207.A) Monitoring: The permittee shall comply with the applicable monitoring requirements of NSPS Subpart J or Ja. Recordkeeping: The permittee shall maintain records in accordance with the applicable requirements of NSPS Subparts J and Ja. Reporting: The permittee shall report in accordance with the applicable requirements of NSPS Subparts J and Ja. B. The following BACT SO2 work practices and equipment shall apply to the SRP (SRU3/TGTU3/TGI3): (PSD-NM-0195-M25) (1) Maintain at least 98% SRP on-stream operations. This includes curtailing refinery operations as necessary when SRU capacity is limited during planned startup, shutdown, and maintenance events. (2) Maintain adequate SRP excess capacity to reduce the frequency and quantity of refinery excess SO2 emissions. After the refinery expansion project proposed units are constructed, the proposed SRU3 will provide at least 25% excess capacity. (3) Continue to maintain and use a sulfur shedding plan to prevent or reduce acid gas flaring events from refinery upsets. An acid gas flaring event is defined as excess SO2 emissions greater than 500 pounds in a 24-hour period. The plan shall state specific actions that may be taken to reduce or prevent acid gas flaring. The actions taken during any event will be based on the refinery operators' discretion, considering safety and other factors related to prudent operation. This plan is subject to review by NMED or EPA, and shall be amended upon written request by NMED or EPA. EPA Inspection Report - Page 171 of 1969 The sulfur shedding plan may include, but is not limited to the following options: (a) Store sour water to reduce acid gas generation from the sour water strippers (b) Reduce the operating rate of one or more amine strippers to lower the acid gas generation rate (c) Reduce one or more hydrotreating unit throughput rates to lower acid gas generation rate (4) Use hydrogen, when available, as SRU fuel during startup and hot standby to minimize carbon deposits on the SRU catalysts. (5) During startup and shutdown and to the extent practicable, process vessels shall be depressurized into other process equipment rather than venting to a flare. The permittee shall document instances when this is not practicable. C. SRU1, SRU2, and SRU3 Requirement: (NSR 0195M35, Condition A207.C and revised) The permittee shall demonstrate compliance with the H2S, SO2, lb/hr, tpy emission limits by completing the following requirements, monitoring, recordkeeping and reporting: (1) A flow meter shall be installed, operated, calibrated, and maintained on the sour water stripper streams that go to the SRUs. (2) An SO2 CEMS and flow meter shall be installed on the SRU1/SRU2 and SRU3 incinerator stacks. In addition, these units shall be equipped with instruments to measure and record sulfur concentration and flow rates of the gas streams into SRU1, SRU2, and SRU3. The CEMS, flow meters, and data loggers shall be calibrated and maintained. In addition, the calibration of the SO2 CEMS shall follow the quality assurance and quality control procedures in 40 CFR 60 Subpart J or Ja and Appendix F. (3) The minimum acceptable level of data capture for all instruments measuring flow of sulfur streams into the SRU1, SRU2, and SRU3, as well as the CEMS and flow meters on the incinerator stacks, shall be at least 90% for each semi-annual period. The 10% lost data will include all periods when the concentration and corresponding flow are not being measured as a result of calibrations or breakdowns. Monitoring: The gas stream feeding SRU1, SRU2, and SRU3 from the amine regeneration units and the sour water stripper shall be tested at least monthly for H2S concentration. The permittee shall monitor the following: (1) Flow rate of sour water stream to SRUs, (2) SO2 concentration in SRU incinerator stacks and (3) Flow rate of the SRU incinerator stacks. Recordkeeping: The permittee shall maintain records in accordance with the applicable EPA Inspection Report - Page 172 of 1969 requirements of NSPS Subparts J or Ja and MACT Subpart UUU. The permittee shall also keep records of the following: (1) Flow rate of sour water stream to SRUs, (2) SO2 concentration in SRU incinerator stacks and (3) Flow rate of the SRU incinerator stacks. Reporting: The permittee shall report in accordance with the applicable requirements of NSPS Subparts J or Ja, MACT Subpart UUU, and Section B110. D. 40 CFR 60, Subpart J (Unit(s) SRU1 and SRU2) Requirement: The permittee shall comply with the applicable requirements of 40 CFR 60, Subpart J. Monitoring: The permittee shall install a continuous monitoring device to monitor compliance with the H2S limit. (40 CFR 60.105(a)(3-4)) Recordkeeping: The permittee shall maintain the continuous emission records. Reporting: The permittee shall comply with the reporting requirements of 40 CFR 60, Subpart J. E. 40 CFR 60, Subpart Ja (Unit SRU3) Requirement: The permittee shall comply with the applicable requirements of 40 CFR 60, Subpart Ja. Monitoring: The permittee shall install a continuous monitoring device to monitor compliance with the H2S limit. (40 CFR 60.105a(a)(3-4)) Recordkeeping: The permittee shall maintain the continuous emission records. Reporting: The permittee shall comply with the reporting requirements of 40 CFR 60, Subpart Ja. A208 Amine Unit - Not Required A209 Fugitives A. NSPS Subpart GGG, Standards of Performance for Equipment Leaks of VOC in Petroleum Refineries for which construction, reconstruction, or modification commenced after January 4, 1983, and on or before November 7, 2006 (Fugitives subject in Table 103.B) Requirement: The permittee shall comply with all applicable requirements of NSPS Subpart GGG for all sources in Table 103.B (affected units and voluntarily units). This table also includes areas that are voluntarily following the NSPS Subpart GGG monitoring requirements. (See footnote 1 to Table 103.B) Monitoring: The permittee shall comply with all applicable monitoring requirements of 40 CFR 60, Subpart GGG. Recordkeeping: The permittee shall comply with all applicable recordkeeping requirements EPA Inspection Report - Page 173 of 1969 of 40 CFR 60, Subpart GGG. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart GGG. B. NSPS Subpart GGGa, Standards of Performance for Equipment Leaks of VOC in Petroleum Refineries for which Construction, Reconstruction, or Modification Commenced After November 7, 2006 (Fugitives subject in Table 103.B) Requirement: The permittee shall comply with all applicable requirements of NSPS Subpart GGGa for all sources in Table 103.B (affected units and voluntarily units). This table also includes areas that are voluntarily following the NSPS Subpart GGGa monitoring requirements. Monitoring: The permittee shall comply with all applicable monitoring requirements of 40 CFR 60, Subpart GGGa. Recordkeeping: The permittee shall comply with all applicable recordkeeping requirements of 40 CFR 60, Subpart GGGa. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart GGGa. C. MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" (Fugitives subject in Table 103.B) Requirement: The permittee shall comply with all applicable requirements of MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" for all affected sources shown in Tables 103.B. (63.640). For all activities in Table 103.B that are not subject to MACT CC, the permittee voluntarily performs a LDAR program for those units and that program meets the requirements of MACT CC. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 63, Subpart CC. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 63.655. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 63.655. D. NSPS Subpart QQQ, Standards of Performance for VOC Emissions from Petroleum Refinery Wastewater Systems (Fugitives subject in Table 103.B) Requirement The permittee shall comply with all applicable requirements of NSPS, 40 CFR Part 60.690, Subpart QQQ. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart QQQ. (60.695) EPA Inspection Report - Page 174 of 1969 Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60.696. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60.697. E. Minor changes within the facility to piping and components that affect fugitive VOC emission source shall be updated and added during the next available Significant permit revision in accordance with 20.2.72 NMAC. The facility wide fugitive VOC emission limit shown above and in Table 106.A of this permit. A210 Loading Racks A. Truck and Rail Loading (Unit shown in Table 106.G) Requirement: Compliance with the allowable emission limits in Table 106.G shall be demonstrated by not exceeding the monthly rolling 12-month total throughput for each loading rack for each different product in gallons per year (barrels/year). Monitoring: The permittee shall monitor the throughput volumes on a monthly basis. Recordkeeping: The permittee shall record the monthly throughput volume for each loading rack for each different product. Each month during the first 12 months of monitoring the permittee shall record the cumulative condensate loadout volume and after the first 12 months of monitoring, the permittee shall calculate and record a monthly rolling 12-month total loadout volume. Records shall also be maintained in accordance with Section B109. Reporting: The permittee shall report in accordance with Section B110. B. Fuel Truck Loading Rack (Units subject in Table 103.D) (40 CFR 63, Subpart CC) Requirement: The permittee shall comply with all applicable requirements of MACT Subpart CC, National Emission Standards for Hazardous Air Pollutants From Petroleum Refineries. Specially, the truck loading rack shall be equipped with a carbon adsorption system for compliance with the MACT requirements. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 63, Subpart CC. Specifically 63.427(a)(2), where a carbon adsorption system is used, a continuous emission monitoring system (CEMS) capable of measuring organic compound concentration shall be installed in the exhaust air stream. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 63, Subpart CC. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 63, Subpart CC. EPA Inspection Report - Page 175 of 1969 A211 Fluid Catalytic Cracking Unit (FCC) A. Continuous Monitor System (CMS) (Unit FCC REGEN) Requirement: (1) Consent Decree Limits on PM and SO2 emissions from the FCC: By no later than December 31, 2003, the Wet Gas Scrubber (WGS) on the FCC Regenerator shall comply with the following limits: (CD 12.B & 13.B) (a) SO2 concentration not to exceed 25 ppmvd on a daily rolling 365-day average basis and 50 ppmvd on a daily rolling 7-day average basis, each corrected to 0% oxygen. Compliance with this emissions limit shall be demonstrated on an ongoing basis through the use of CMS; and (b) a particulate matter (PM) emission limit of 1.0 pound of PM per 1000 pounds of coke burned on a 3-hour average basis (CD 13.B). To demonstrate compliance with this requirement, the Permittee shall conduct an annual EPA Method 5 Test for PM and weekly EPA Method 9, Opacity Test in accordance with their approved Alternative Monitoring Plan (AMP). (c) As the FCC Regenerator is subject to the provisions of 40 CFR 60.102 (NSPS Subpart J), it shall not discharge to the atmosphere gases exhibiting greater than 30 percent opacity, except for one six-minute average opacity reading in any one-hour period. (2) Consent Decree Limits on NOx and CO emissions from the FCC: The FCC shall comply with NOx and CO emission limits as follows: (a) The concentration-based (ppmvd) NOx emission limit based on daily rolling 7-day and daily rolling 365-day averages, corrected to 0% oxygen as established pursuant to the Consent Decree, unless EPA rejects the proposed limit and establishes a different NOx emission limit, in which case the FCC shall comply with EPA's established limit. Under no circumstances shall this emission limit be greater than a concentration-based limit that would be equivalent to 34.9 lbs/hr. The 7-day FCC NOx emission limits, shall not apply during periods of Hydrotreater Outage provided that the FCC (including associated air pollution control equipment) is maintained and operated in a manner that minimizes emissions in accordance with an EPA-approved good air pollution control practices plan. Navajo shall comply with the plan at all times, including periods of startup, shutdown, and malfunction of the hydrotreater. The daily rolling 365-day average NOx emissions limit shall apply during periods of hydrotreater outages. The NOx limits are: (1) 87.3 ppmvd NOx, corrected to 0% O2 on a daily rolling 7-day average, and (2) 58.1 ppmvd NOx, corrected to 0% O2 on a daily rolling 365-day average (b) The NSPS Subpart J emission limit of 500 ppmvd CO corrected to 0% O2 on a 1-hour average basis and 100 ppmvd CO corrected to 0% O2 on a daily rolling 365-day average basis, by no later than December 31, 2003. EPA Inspection Report - Page 176 of 1969 Monitoring: (1) A continuous monitor system (CMS) for CO, O2, SO2 and NOx shall be installed, calibrated, maintained, and operated on the FCC Catalyst Regenerator vent stack(s) downstream of the scrubber in accordance with 40 CFR Part 60, 60.13, Appendix A, and the applicable performance specifications of Appendices B (Specifications 2 and 3) and F. The CMS shall be used to demonstrate compliance with CO, SO2 and NOx emissions limits and to report compliance with the terms and conditions of the Consent Decree. The CMS and process data shall be made available, by permittee, to applicable Federal and State Agencies (NMED) upon demand as soon as practicable. (CD 11.F, 12 D, and 14.C) (2) The FCC Regenerator Scrubber NOx, SO2, CO and O2 CMS shall be recertified annually. (3) The CMS data shall be monitored to ensure the CO, SO2 and NOx emission limits for the FCC are met. (4) The Permittee shall conduct an annual EPA Method 5 Test for PM and weekly EPA Method 9 Opacity test to demonstrate compliance with the particulate matter (PM) emission limit of 1.0 pound of PM per 1000 pounds of coke burned on a 3-hour average basis and opacity limit of 30%. Permittee shall meet testing requirements of B111. Recordkeeping: The permittee shall maintain the records of: (1) The certification and re-certification of the CMS. (2) Modifications to the FCC's good air pollution control practice plan to minimize NOx emissions shall be summarized on an annual basis if any changes were made. ( CD 11.G) (3) The permittee shall keep records of CMS data monitoring NO2, SO2, PM10 and CO emissions from the FCC. (CD 11.F, CD 12.D & CD 14.C) (4) Records of NOx, CO, SO2 ppmvd, lb/hr, tpy; PM lb/hr, tpy and opacity. TPY shall be based on a monthly rolling 12-month total. (5) The permittee shall keep records of annual PM stack tests and weekly Method 9 observations conducted on the FCC. For any opacity observations conducted in accordance with the requirements of EPA Method 9, record the information on the form referenced in EPA Method 9, Sections 2.2 and 2.4. Reporting: The permittee shall report in accordance with Section B110 and testing requirements of B111. B. Performance Testing (Unit FCC REGEN) Requirements: (1) The permittee shall demonstrate compliance with the NSPS Subpart J particulate matter emission limit at Table 106.A by conducting an initial performance test in accordance with NSPS Subpart A, 60.8 and NSPS Subpart J, 60.106(b). The particulate matter stack test EPA Inspection Report - Page 177 of 1969 shall be repeated on an annual basis. (2) The permittee shall comply with all applicable performance testing requirements in accordance with MACT Subparts A and UUU. Monitoring: Testing shall be conducted in accordance with NSPS Subparts A and J, and in accordance with MACT Subparts A and UUU. Recordkeeping: The permittee shall maintain performance test records in accordance with NSPS Subparts A and J, MACT Subparts A and UUU, and in accordance with Section B109. Reporting: The permittee shall report performance test results in accordance with NSPS Subparts A and J, MACT Subparts A and UUU, and in accordance with Section B110. A212 Cooling Towers A. MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" (Cooling Towers subject in Table 103.F) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 63, Subpart CC for heat exchange systems for all affected sources shown in Table 103.F attached. (63.654(a), 63.640(h)(6)) Monitoring: The permittee shall comply with all applicable monitoring and testing requirements of 40 CFR 63, Subpart CC. (63.654(c), (d), (e), (f)) Recordkeeping: The permittee shall comply with all applicable recordkeeping requirements of 40 CFR 63, Subpart CC. (63.654(g), 63.655(i)(4), (i)(5)) Reporting: The permittee shall comply with all applicable reporting requirements of 40 CFR 63, Subpart CC. (63.655(f), (f)(1)(vi), (g)(9), (h)(1), (7)) B. Cooling Tower Operations (Cooling Towers subject in Table 103.F) Requirement: Compliance with the allowable emission limits in Table 106.H shall be demonstrated by meeting the following requirements: 1) operate a maximum of six (6) recirculating pumps at any one time; 2) ensure that each pump capacity shown in Table 104.A are not exceeded gallons per minute for each cooling tower (65,500 gpm total maximum rate for 6 pumps); 3) limit the Total Dissolved Solids (TDS) content for the cooling tower recirculating water system to 3500 ppmw, based on a monthly rolling 12-month annual average; 4) ensure that the drift eliminator are rated by the manufacturer at 0.001% or 0.003 drift or less as shown in Table 104.A; and 5) ensure that the drift eliminator is present and in good working order. The permittee shall measure the Total Dissolved Solids (TDS) content of the recirculating water through direct laboratory analysis, or may use a conductivity meter on the recirculating water system for the cooling tower. The correlation between conductivity of the water and the EPA Inspection Report - Page 178 of 1969 TDS content shall be taken as 0.9 * conductivity (mhos/cm) = TDS (ppmw) unless a new correlation is determined through laboratory analysis and submitted to the Permit Program Manager for approval. Monitoring: The permittee shall: 1) Monitor the recirculating water TDS content by direct laboratory analysis of the TDS or through use of conductivity meter values and correlated TDS on a monthly basis; and a. Any correlation other than the 0.9 value described above shall be developed by the permittee by independent laboratory measurement of at least 10 water samples with approximately evenly spaced measured TDS values that bracket the minimum and maximum values expected. The highest laboratory TDS sample used for the correlation shall be greater than the maximum allowable TDS of 3500 ppmw. 2) Perform an annual inspection of the drift eliminator and perform any maintenance necessary to ensure the device operates according to the manufacturer's specifications. 3) The permittee shall monitor the cooling water inlet and outlet streams for hydrocarbons on an annual basis using either EPA Method 8015 with a large enough sample to achieve accurate quantification of hydrocarbon content, EPA Method 8260, EPA Method 8270 or a similar method as approved by the Department prior to testing. Recordkeeping: The permittee shall maintain the following records: 1) Manufacturer's specifications demonstrating maximum capacities of the recirculating water pumps and the manufacturer's specification for the drift eliminator specified drift rate; 2) Monthly TDS and monthly rolling 12-month average; 3) If a conductivity meter is installed, a record of the correlation between conductivity and TDS, any laboratory analyses used to determine the correlation, and all related calculations; 4) Annual drift eliminator inspection and any records of maintenance performed. The permittee shall maintain records in accordance with Section B109. Reporting: The permittee shall report in accordance with Section B110. A213 Wastewater Systems A. NSPS Subpart QQQ, Standards of Performance for VOC Emissions from Petroleum Refinery Wastewater Systems (Unit MAIN API) Requirement: Beginning December 31, 2003, all remaining and newly installed individual drain systems, oil-water separators, and aggregate facilities not previously specified shall be affected facilities, as the term is used in the NSPS, 40 CFR Part 60, Subpart QQQ, and shall be subject to and comply with the applicable requirements of 40 CFR Part 60, Subpart QQQ. EPA Inspection Report - Page 179 of 1969 (CD 29) The permittee shall comply with all applicable requirements of NSPS Subpart QQQ for the affected sources in Tables 103.B, C, G. (60.690) Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart QQQ. (60.695 and 60.696) Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60.697. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60.698. B. MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" Requirement: The permittee shall comply with all applicable requirements of MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" for all affected sources shown in Tables 103.B, C, G attached. (63.640). Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 63, Subpart CC. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 63.655. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 63.655. C. Wastewater Treatment System (Units shown in Table 106.I) Requirement: Compliance with the emission limits in Table 106.I shall be demonstrated by properly maintaining and repairing the units, and running the Wastewater Model annually to calculate the maximum VOC emissions generated. Monitoring: (1) Maintenance and repair shall meet the minimum manufacturer's or permittee's recommended maintenance schedule. Activities that involve maintenance, adjustment, replacement, or repair of functional components with the potential to affect the operation of an emission unit shall be documented as they occur for the following events: (a) Routine maintenance that takes a unit out of service for more than two hours during any twenty-four hour period. (b) Unscheduled repairs that require a unit to be taken out of service for more than two hours in any twenty-four hour period. (2) The permittee shall annually run the Waste-Water Model to determine the hourly and annual emission rates, based on Toxchem V4 Input Parameters. Recordkeeping: (1) The permittee shall maintain records in accordance with Section B109, including records of maintenance and repairs activities and a copy of the manufacturer's or permittee's EPA Inspection Report - Page 180 of 1969 recommended maintenance schedule. (2) The permittee shall maintain records of the Toxchem V4 Input Parameters and the emission calculation results compared to permit limits. Reporting: The permittee shall report in accordance with Section B110. EPA Inspection Report - Page 181 of 1969 PART B GENERAL CONDITIONS B100 Introduction A. Not Applicable B101 Legal A. Permit Terms and Conditions (20.2.70 sections 7, 201.B, 300, 301.B, 302, 405 NMAC) (1) The permittee shall abide by all terms and conditions of this permit, except as allowed under Section 502(b)(10) of the Federal Act, and 20.2.70.302.H.1 NMAC. Any permit noncompliance is grounds for enforcement action, and significant or repetitious noncompliance may result in termination of this permit. Additionally, noncompliance with federally enforceable conditions of this permit constitutes a violation of the Federal Act. (20.2.70.302.A.2.a NMAC) (2) Emissions trading within a facility (20.2.70.302.H.2 NMAC) (a) The Department shall, if an applicant requests it, issue permits that contain terms and conditions allowing for the trading of emissions increases and decreases in the permitted facility solely for the purpose of complying with a federally enforceable emissions cap that is established in the permit in addition to any applicable requirements. Such terms and conditions shall include all terms and conditions required under 20.2.70.302 NMAC to determine compliance. If applicable requirements apply to the requested emissions trading, permit conditions shall be issued only to the extent that the applicable requirements provide for trading such increases and decreases without a case-by-case approval. (b) The applicant shall include in the application proposed replicable procedures and permit terms that ensure the emissions trades are quantifiable and enforceable. The Department shall not include in the emissions trading provisions any emissions units for which emissions are not quantifiable or for which there are no replicable procedures to enforce the emissions trades. The permit shall require compliance with all applicable requirements. (3) It shall not be a defense for the permittee in an enforcement action to claim that it would have been necessary to halt or reduce the permitted activity in order to maintain compliance with the conditions of this permit. (20.2.70.302.A.2.b NMAC) (4) If the Department determines that cause exists to modify, reopen and revise, revoke and reissue, or terminate this permit, this shall be done in accordance with 20.2.70.405 NMAC. (20.2.70.302.A.2.c NMAC) EPA Inspection Report - Page 182 of 1969 (5) The permittee shall furnish any information the Department requests in writing to determine if cause exists for reopening and revising, revoking and reissuing, or terminating the permit, or to determine compliance with the permit. This information shall be furnished within the time period specified by the Department. Additionally, the permittee shall furnish, upon request by the Department, copies of records required by the permit to be maintained by the permittee. (20.2.70.302.A.2.f NMAC) (6) A request by the permittee that this permit be modified, revoked and reissued, or terminated, or a notification by the permittee of planned changes or anticipated noncompliance, shall not stay any conditions of this permit. (20.2.70.302.A.2.d NMAC) (7) This permit does not convey property rights of any sort, or any exclusive privilege. (20.2.70.302.A.2.e NMAC) (8) In the case where an applicant or permittee has submitted information to the Department under a claim of confidentiality, the Department may also require the applicant or permittee to submit a copy of such information directly to the Administrator of the EPA. (20.2.70.301.B NMAC) (9) The issuance of this permit, or the filing or approval of a compliance plan, does not relieve the permittee from civil or criminal liability for failure to comply with the state or Federal Acts, or any applicable state or federal regulation or law. (20.2.70.302.A.6 NMAC and the New Mexico Air Quality Control Act NMSA 1978, Chapter 74, Article 2) (10) If any part of this permit is challenged or held invalid, the remainder of the permit terms and conditions are not affected and the permittee shall continue to abide by them. (20.2.70.302.A.1.d NMAC) (11) A responsible official (as defined in 20.2.70.7.AE NMAC) shall certify the accuracy, truth and completeness of every report and compliance certification submitted to the Department as required by this permit. These certifications shall be part of each document. (20.2.70.300.E NMAC) (12) Revocation or termination of this permit by the Department terminates the permittee's right to operate this facility. (20.2.70.201.B NMAC) (13) The permittee shall continue to comply with all applicable requirements. For applicable requirements that will become effective during the term of the permit, the permittee shall meet such requirements on a timely basis. (Sections 300.D.10.c and 302.G.3 of 20.2.70 NMAC) B. Permit Shield (20.2.70.302.J NMAC) (1) Compliance with the conditions of this permit shall be deemed to be compliance with any applicable requirements existing as of the date of permit issuance and EPA Inspection Report - Page 183 of 1969 identified in Table 103.A. The requirements in Table 103.A are applicable to this facility with specific requirements identified for individual emission units. (2) The Department has determined that the requirements in Table 103.B as identified in the permit application are not applicable to this source, or they do not impose any conditions in this permit. (3) This permit shield does not extend to administrative amendments (Subsection A of 20.2.70.404 NMAC), to minor permit modifications (Subsection B of 20.2.70.404 NMAC), to changes made under Section 502(b)(10), changes under Paragraph 1 of subsection H of 20.2.70.302 of the Federal Act, or to permit terms for which notice has been given to reopen or revoke all or part under 20.2.70.405 and 20.2.70.302J(6). (4) This permit shall, for purposes of the permit shield, identify any requirement specifically identified in the permit application or significant permit modification that the department has determined is not applicable to the source, and state the basis for any such determination. (20.2.70.302.A.1.f NMAC) C. The owner or operator of a source having an excess emission shall, to the extent practicable, operate the source, including associated air pollution control equipment, in a manner consistent with good air pollutant control practices for minimizing emissions. (20.2.7.109 NMAC). The establishment of allowable malfunction emission limits does not supersede this requirement. B102 Authority A. This permit is issued pursuant to the federal Clean Air Act ("Federal Act"), the New Mexico Air Quality Control Act ("State Act") and regulations adopted pursuant to the State and Federal Acts, including Title 20, New Mexico Administrative Code, Chapter 2, Part 70 (20.2.70 NMAC) - Operating Permits. B. This permit authorizes the operation of this facility. This permit is valid only for the named permittee, owner, and operator. A permit modification is required to change any of those entities. C. The Department specifies with this permit, terms and conditions upon the operation of this facility to assure compliance with all applicable requirements, as defined in 20.2.70 NMAC at the time this permit is issued. (20.2.70.302.A.1 NMAC) D. Pursuant to the New Mexico Air Quality Control Act NMSA 1978, Chapter 74, Article 2, all terms and conditions in this permit, including any provisions designed to limit this facility's potential to emit, are enforceable by the Department. All terms and conditions are enforceable by the Administrator of the United States Environmental Protection Agency ("EPA") and citizens under the Federal Act, unless the term or condition is specifically EPA Inspection Report - Page 184 of 1969 designated in this permit as not being enforceable under the Federal Act. (20.2.70.302.A.5 NMAC) E. The Department is the Administrator for 40 CFR Parts 60, 61, and 63 pursuant to the Modification and Exceptions of Section 10 of 20.2.77 NMAC (NSPS), 20.2.78 NMAC (NESHAP), and 20.2.82 NMAC (MACT). B103 Annual Fee A. The permittee shall pay Title V fees to the Department consistent with the fee schedule in 20.2.71 NMAC - Operating Permit Emission Fees. The fees will be assessed and invoiced separately from this permit. (20.2.70.302.A.1.e NMAC) B104 Appeal Procedures (20.2.70.403.A NMAC) A. Any person who participated in a permitting action before the Department and who is adversely affected by such permitting action, may file a petition for a hearing before the Environmental Improvement Board ("board"). The petition shall be made in writing to the board within thirty (30) days from the date notice is given of the Department's action and shall specify the portions of the permitting action to which the petitioner objects, certify that a copy of the petition has been mailed or hand-delivered, and attach a copy of the permitting action for which review is sought. Unless a timely request for a hearing is made, the decision of the Department shall be final. The petition shall be copied simultaneously to the Department upon receipt of the appeal notice. If the petitioner is not the applicant or permittee, the petitioner shall mail or hand-deliver a copy of the petition to the applicant or permittee. The Department shall certify the administrative record to the board. Petitions for a hearing shall be sent to: Secretary, New Mexico Environmental Improvement Board 1190 St. Francis Drive, Runnels Bldg. Rm N2153 Santa Fe, New Mexico 87502 B105 Submittal of Reports and Certifications A. Stack Test Protocols and Stack Test Reports shall be submitted electronically to Stacktest.AQB@state.nm.us or as directed by the Department. B. Excess Emission Reports shall be submitted as directed by the Department. (20.2.7.110 NMAC) C. Compliance Certification Reports, Semi-Annual monitoring reports, compliance schedule progress reports, and any other compliance status information required by this permit shall be certified by the responsible official and submitted to the mailing address below, or as directed by the Department: EPA Inspection Report - Page 185 of 1969 Manager, Compliance and Enforcement Section New Mexico Environment Department Air Quality Bureau 525 Camino de los Marquez Suite 1 Santa Fe, NM 87505-1816 D. Compliance Certification Reports shall also be submitted to the Administrator at the address below (20.2.70.302.E.3 NMAC): Chief, Air Enforcement Section US EPA Region-6, 6EN-AA 1445 Ross Avenue, Suite 1200 Dallas, TX 75202-2733 B106 NSPS and/or MACT Startup, Shutdown, and Malfunction Operations A. If a facility is subject to a NSPS standard in 40 CFR 60, each owner or operator that installs and operates a continuous monitoring device required by a NSPS regulation shall comply with the excess emissions reporting requirements in accordance with 40 CFR 60.7(c). B. If a facility is subject to a NSPS standard in 40 CFR 60, then in accordance with 40 CFR 60.8(c), operations during periods of startup, shutdown, and malfunction shall not constitute representative conditions for the purpose of a performance test nor shall emissions in excess of the level of the applicable emission limit during periods of startup, shutdown, and malfunction be considered a violation of the applicable emission limit unless otherwise specified in the applicable standard. C. If a facility is subject to a MACT standard in 40 CFR 63, then the facility is subject to the requirement for a Startup, Shutdown and Malfunction Plan (SSM) under 40 CFR 63.6(e)(3), unless specifically exempted in the applicable subpart. (20.2.70.302.A.1 and A.4 NMAC) B107 Startup, Shutdown, and Maintenance Operations A. The establishment of permitted startup, shutdown, and maintenance (SSM) emission limits does not supersede the requirements of 20.2.7.14.A NMAC. Except for operations or equipment subject to Condition B106, the permittee shall establish and implement a plan to minimize emissions during routine or predictable start up, shut down, and scheduled maintenance (SSM work practice plan) and shall operate in accordance with the procedures set forth in the plan. (20.2.7.14.A NMAC) B108 General Monitoring Requirements (20.2.70. 302.A and C NMAC) EPA Inspection Report - Page 186 of 1969 A. These requirements do not supersede or relax requirements of federal regulations. B. The following monitoring and/or testing requirements shall be used to determine compliance with applicable requirements and emission limits. Any sampling, whether by portable analyzer or EPA reference method, that measures an emission rate over the applicable averaging period greater than an emission limit in this permit constitutes noncompliance with this permit. The Department may require, at its discretion, additional tests pursuant to EPA Reference Methods at any time, including when sampling by portable analyzer measures an emission rate greater than an emission limit in this permit; but such requirement shall not be construed as a determination that the sampling by portable analyzer does not establish noncompliance with this permit and shall not stay enforcement of such noncompliance based on the sampling by portable analyzer. C. If the emission unit is shutdown at the time when periodic monitoring is due to be accomplished, the permittee is not required to restart the unit for the sole purpose of performing the monitoring. Using electronic or written mail, the permittee shall notify the Department's Enforcement Section of a delay in emission tests prior to the deadline for accomplishing the tests. Upon recommencing operation, the permittee shall submit any pertinent pre-test notification requirements set forth in the current version of the Department's Standard Operating Procedures For Use Of Portable Analyzers in Performance Test, and shall accomplish the monitoring. D. The requirement for monitoring during any monitoring period is based on the percentage of time that the unit has operated. However, to invoke monitoring period exemptions at B108.D(2), hours of operation shall be monitored and recorded. (1) If the emission unit has operated for more than 25% of a monitoring period, then the permittee shall conduct monitoring during that period. (2) If the emission unit has operated for 25% or less of a monitoring period then the monitoring is not required. After two successive periods without monitoring, the permittee shall conduct monitoring during the next period regardless of the time operated during that period, except that for any monitoring period in which a unit has operated for less than 10% of the monitoring period, the period will not be considered as one of the two successive periods. (3) If invoking the monitoring period exemption in B108.D(2), the actual operating time of a unit shall not exceed the monitoring period required by this permit before the required monitoring is performed. For example, if the monitoring period is annual, the operating hours of the unit shall not exceed 8760 hours before monitoring is conducted. Regardless of the time that a unit actually operates, a minimum of one of each type of monitoring activity shall be conducted during the five year term of this permit. E. The permittee is not required to report a deviation for any monitoring or testing in a Specific Condition if the deviation was authorized in this General Condition B108. EPA Inspection Report - Page 187 of 1969 F. For all periodic monitoring events, except when a federal or state regulation is more stringent, three test runs shall be conducted at 90% or greater of the unit's capacity as stated in this permit, or in the permit application if not in the permit, and at additional loads when requested by the Department. If the 90% capacity cannot be achieved, the monitoring will be conducted at the maximum achievable load under prevailing operating conditions except when a federal or state regulation requires more restrictive test conditions. The load and the parameters used to calculate it shall be recorded to document operating conditions and shall be included with the monitoring report. G. When requested by the Department, the permittee shall provide schedules of testing and monitoring activities. Compliance tests from previous NSR and Title V permits may be reimposed if it is deemed necessary by the Department to determine whether the source is in compliance with applicable regulations or permit conditions. H. If monitoring is new or is in addition to monitoring imposed by an existing applicable requirement, it shall become effective 120 days after the date of permit issuance. For emission units that have not commenced operation, the associated new or additional monitoring shall not apply until 120 days after the units commence operation. All preexisting monitoring requirements incorporated in this permit shall continue to apply from the date of permit issuance. All monitoring periods, unless stated otherwise in the specific permit condition or federal requirement, shall commence at the beginning of the 12 month reporting period as defined at condition A109.B. B109 General Recordkeeping Requirements (20.2.70.302.D NMAC) A. The permittee shall maintain records to assure and verify compliance with the terms and conditions of this permit and any applicable requirements that become effective during the term of this permit. The minimum information to be included in these records is as follows (20.2.70.302.D.1 NMAC): (1) Records required for testing and sampling: (a) equipment identification (include make, model and serial number for all tested equipment and emission controls) (b) date(s) and time(s) of sampling or measurements (c) date(s) analyses were performed (d) the qualified entity that performed the analyses (e) analytical or test methods used (f) results of analyses or tests (g) operating conditions existing at the time of sampling or measurement EPA Inspection Report - Page 188 of 1969 (2) Records required for equipment inspections and/or maintenance required by this permit: (a) equipment identification number (including make, model and serial number) (b) date(s) and time(s) of inspection, maintenance, and/or repair (c) date(s) any subsequent analyses were performed (if applicable) (d) name of the person or qualified entity conducting the inspection, maintenance, and/or repair (e) copy of the equipment manufacturer's or the owner or operator's maintenance or repair recommendations (if required to demonstrate compliance with a permit condition) (f) description of maintenance or repair activities conducted (g) all results of any required parameter readings (h) a description of the physical condition of the equipment as found during any required inspection (i) results of required equipment inspections including a description of any condition which required adjustment to bring the equipment back into compliance and a description of the required adjustments B. The permittee shall keep records of all monitoring data, equipment calibration, maintenance, and inspections, Data Acquisition and Handling System (DAHS) if used, reports, and other supporting information required by this permit for at least five (5) years from the time the data was gathered or the reports written. Each record shall clearly identify the emissions unit and/or monitoring equipment, and the date the data was gathered. (20.2.70.302.D.2 NMAC) C. If the permittee has applied and received approval for an alternative operating scenario, then the permittee shall maintain a log at the facility, which documents, contemporaneously with any change from one operating scenario to another, the scenario under which the facility is operating. (20.2.70.302.A.3 NMAC) D. The permittee shall keep a record describing off permit changes made at this source that result in emissions of a regulated air pollutant subject to an applicable requirement, but not otherwise regulated under this permit, and the emissions resulting from those changes. (20.2.70.302.I.2 NMAC) E. Unless otherwise indicated by Specific Conditions, the permittee shall keep the following records for malfunction emissions and routine and predictable emissions during startup, shutdown, and scheduled maintenance (SSM): (1) The owner or operator of a source subject to a permit, shall establish and implement a plan to minimize emissions during routine or predictable startup, EPA Inspection Report - Page 189 of 1969 shutdown, and scheduled maintenance through work practice standards and good air pollution control practices. This requirement shall not apply to any affected facility defined in and subject to an emissions standard and an equivalent plan under 40 CFR Part 60 (NSPS), 40 CFR Part 63 (MACT), or an equivalent plan under 20.2.72 NMAC - Construction Permits, 20.2.70 NMAC - Operating Permits, 20.2.74 NMAC - Permits - Prevention of Significant Deterioration (PSD), or 20.2.79 NMAC - Permits - Nonattainment Areas. (20.2.7.14.A NMAC) The permittee shall keep records of all sources subject to the plan to minimize emissions during routine or predictable SSM and shall record if the source is subject to an alternative plan and therefore, not subject to the plan requirements under 20.2.7.14.A NMAC. (2) If the facility has allowable SSM emission limits in this permit, the permittee shall record all SSM events, including the date, the start time, the end time, a description of the event, and a description of the cause of the event. This record also shall include a copy of the manufacturer's, or equivalent, documentation showing that any maintenance qualified as scheduled. Scheduled maintenance is an activity that occurs at an established frequency pursuant to a written protocol published by the manufacturer or other reliable source. The authorization of allowable SSM emissions does not supersede any applicable federal or state standard. The most stringent requirement applies. (3) If the facility has allowable malfunction emission limits in this permit, the permittee shall record all malfunction events to be applied against these limits. The permittee shall also include the date, the start time, the end time, and a description of the event. Malfunction means any sudden and unavoidable failure of air pollution control equipment or process equipment beyond the control of the owner or operator, including malfunction during startup or shutdown. A failure that is caused entirely or in part by poor maintenance, careless operation, or any other preventable equipment breakdown shall not be considered a malfunction. (20.2.7.7.E NMAC) The authorization of allowable malfunction emissions does not supersede any applicable federal or state standard. The most stringent requirement applies. This authorization only allows the permittee to avoid submitting reports under 20.2.7 NMAC for total annual emissions that are below the authorized malfunction emission limit. (4) The owner or operator of a source shall meet the operational plan defining the measures to be taken to mitigate source emissions during malfunction, startup or shutdown. (20.2.72.203.A(5) NMAC) B110 General Reporting Requirements (20.2.70.302.E NMAC) A. Reports of required monitoring activities for this facility shall be submitted to the Department on the schedule in section A109. Monitoring and recordkeeping requirements that are not required by a NSPS or MACT shall be maintained on-site or (for unmanned EPA Inspection Report - Page 190 of 1969 sites) at the nearest company office, and summarized in the semi-annual reports, unless alternative reporting requirements are specified in the equipment specific requirements section of this permit. B. Reports shall clearly identify the subject equipment showing the emission unit ID number according to this operating permit. In addition, all instances of deviations from permit requirements, including those that occur during emergencies, shall be clearly identified in the reports required by section A109. (20.2.70.302.E.1 NMAC) C. The permittee shall submit reports of all deviations from permit requirements, including those attributable to upset conditions as defined in the permit, the probable cause of such deviations, and any corrective actions or preventive measures taken. These reports shall be submitted as follows: (1) Deviations resulting in excess emissions as defined in 20.2.7.7 NMAC (including those classified as emergencies as defined in section B114.A) shall be reported in accordance with the timelines specified by 20.2.7.110 NMAC and in the semiannual reports required in section A109. (20.2.70.302.E.2 NMAC) (2) All other deviations shall be reported in the semi-annual reports required in section A109. (20.2.70.302.E.2 NMAC). D. The permittee shall submit reports of excess emissions in accordance with 20.2.7.110.A NMAC. E. Results of emission tests and monitoring for each pollutant (except opacity) shall be reported in pounds per hour (unless otherwise specified) and tons per year. Opacity shall be reported in percent. The number of significant figures corresponding to the full accuracy inherent in the testing instrument or Method test used to obtain the data shall be used to calculate and report test results in accordance with 20.2.1.116.B and C NMAC. Upon request by the Department, CEMS and other tabular data shall be submitted in editable, MS Excel format. F. At such time as new units are installed as authorized by the applicable NSR Permit, the permittee shall fulfill the notification requirements in the NSR permit. G. Periodic Emissions Test Reporting: The permittee shall report semi-annually a summary of the test results. H. The permittee shall submit an emissions inventory report for this facility in accordance with the schedule in subparagraph (5), provided one or more of the following criteria is met in subparagraphs (1) to (4): (20.2.73 NMAC) (1) The facility emits, or has the potential to emit, 5 tons per year or more of lead or lead compounds, or 100 tons per year or more of PM10, PM2.5, sulfur oxides, nitrogen oxides, carbon monoxide, or volatile organic compounds. EPA Inspection Report - Page 191 of 1969 (2) The facility is defined as a major source of hazardous air pollutants under 20.2.70 NMAC (Operating Permits). (3) The facility is located in an ozone nonattainment area and which emits, or has the potential to emit, 25 tons per year or more of nitrogen oxides or volatile organic compounds. (4) Upon request by the department. (5) The permittee shall submit the emissions inventory report by April 1 of each year, unless a different deadline is specified by the current operating permit. I. Emissions trading within a facility (20.2.70.302.H.2 NMAC) (1) For each such change, the permittee shall provide written notification to the department and the administrator at least seven (7) days in advance of the proposed changes. Such notification shall state when the change will occur and shall describe the changes in emissions that will result and how these increases and decreases in emissions will comply with the terms and conditions of the permit. (2) The permittee and department shall attach each such notice to their copy of the relevant permit. B111 General Testing Requirements A. Compliance Tests (1) Compliance test requirements from previous permits (if any) are still in effect, unless the tests have been satisfactorily completed. Compliance tests may be reimposed if it is deemed necessary by the Department to determine whether the source is in compliance with applicable regulations or permit conditions. (20.2.72 NMAC Sections 210.C and 213) (2) Compliance tests shall be conducted within sixty (60) days after the unit(s) achieve the maximum normal production rate. If the maximum normal production rate does not occur within one hundred twenty (120) days of source startup, then the tests must be conducted no later than one hundred eighty (180) days after initial startup of the source. (3) Unless otherwise indicated by Specific Conditions or regulatory requirements, the default time period for each test run shall be at least 60 minutes and each performance test shall consist of three separate runs using the applicable test method. For the purpose of determining compliance with an applicable emission limit, the arithmetic mean of results of the three runs shall apply. In the event that a sample is accidentally lost or conditions occur in which one of the three runs must be discontinued because of forced shutdown, failure of an irreplaceable portion of the sample train, extreme meteorological conditions, or other circumstances, beyond the owner or operator's control, compliance may, upon the EPA Inspection Report - Page 192 of 1969 Department approval, be determined using the arithmetic mean of the results of the two other runs. (4) Testing of emissions shall be conducted with the emissions unit operating at 90 to 100 percent of the maximum operating rate allowed by the permit. If it is not possible to test at that rate, the source may test at a lower operating rate, subject to the approval of the Department. (5) Testing performed at less than 90 percent of permitted capacity will limit emission unit operation to 110 percent of the tested capacity until a new test is conducted. (6) If conditions change such that unit operation above 110 percent of tested capacity is possible, the source must submit a protocol to the Department within 30 days of such change to conduct a new emissions test. B. EPA Reference Method Tests (1) All compliance tests required by this permit, unless otherwise specified by Specific Conditions of this permit, shall be conducted in accordance with the requirements of 40 CFR 60, Subpart A, General Provisions, and the following EPA Reference Methods as specified by 40 CFR 60, Appendix A: (a) Methods 1 through 4 for stack gas flowrate (b) Method 5 for TSP (c) Method 6C and 19 for SO2 (d) Method 7E for NOX (test results shall be expressed as nitrogen dioxide (NO2) using a molecular weight of 46 lb/lb-mol in all calculations (each ppm of NO/NO2 is equivalent to 1.194 x 10-7 lb/SCF) (e) Method 9 for opacity (f) Method 10 for CO (g) Method 19 may be used in lieu of Methods 1-4 for stack gas flowrate upon approval of the Department. A justification for this proposal must be provided along with a contemporaneous fuel gas analysis (preferably on the day of the test) and a recent fuel flow meter calibration certificate (within the most recent quarter). (h) Method 7E or 20 for Turbines per 60.335 or 60.4400 (i) Method 29 for Metals (j) Method 201A for filterable PM10 and PM2.5 (k) Method 202 for condensable PM (l) Method 320 for organic Hazardous Air Pollutants (HAPs) (m) Method 25A for VOC reduction efficiency EPA Inspection Report - Page 193 of 1969 (n) Method 30B for Mercury (2) Alternative test method(s) may be used if the Department approves the change. C. Periodic Monitoring and Portable Analyzer Requirements (1) Periodic emissions tests (periodic monitoring) may be conducted in accordance with EPA Reference Methods or by utilizing a portable analyzer. Periodic monitoring utilizing a portable analyzer shall be conducted in accordance with the requirements of ASTM D 6522-00. However, if a facility has met a previously approved Department criterion for portable analyzers, the analyzer may be operated in accordance with that criterion until it is replaced. (2) Unless otherwise indicated by Specific Conditions or regulatory requirements, the default time period for each test run shall be at least 20 minutes. Each performance test shall consist of three separate runs. The arithmetic mean of results of the three runs shall be used to determine compliance with the applicable emission limit. (3) Testing of emissions shall be conducted in accordance with the requirements at Section B108.F. (4) During emissions tests, pollutant and diluent concentration shall be monitored and recorded. Fuel flow rate shall be monitored and recorded if stack gas flow rate is determined utilizing Method 19. This information shall be included with the test report furnished to the Department. (5) Stack gas flow rate shall be calculated in accordance with 40 CFR 60, Appendix A, Method 19 utilizing fuel flow rate (scf) determined by a dedicated fuel flow meter and fuel heating value (Btu/scf) determined from a fuel sample obtained preferably during the day of the test, but no earlier than three months prior to the test date. Alternatively, stack gas flow rate may be determined by using EPA Methods 1-4. D. Test Procedures: (1) The permittee shall notify the Department's Program Manager, Compliance and Enforcement Section at least thirty (30) days before the test to afford a representative of the Department an opportunity to be present at the test. (40CFR 60.8(d)) (2) Equipment shall be tested in the "as found" condition. Equipment may not be adjusted or tuned prior to any test for the purpose of lowering emissions, and then returned to previous settings or operating conditions after the test is complete. (3) Contents of test notifications, protocols and test reports shall conform to the format specified by the Department's Universal Test Notification, Protocol and Report Form and Instructions. Current forms and instructions are posted to NMED's Air Quality web site under Compliance and Enforcement Testing. EPA Inspection Report - Page 194 of 1969 (4) The permittee shall provide (a) sampling ports adequate for the test methods applicable to the facility, (b) safe sampling platforms, (c) safe access to sampling platforms and (d) utilities for sampling and testing equipment. (5) The stack shall be of sufficient height and diameter and the sample ports shall be located so that a representative test of the emissions can be performed in accordance with the requirements of EPA Method 1 or ASTM D 6522-00 as applicable. (6) Where necessary to prevent cyclonic flow in the stack, flow straighteners shall be installed (7) Unless otherwise indicated by Specific Conditions or regulatory requirements, test reports shall be submitted to the Department no later than 30 days after completion of the test. B112 Compliance A. The Department shall be given the right to enter the facility at all reasonable times to verify the terms and conditions of this permit. Required records shall be organized by date and subject matter and shall at all times be readily available for inspection. The permittee, upon verbal or written request from an authorized representative of the Department who appears at the facility, shall immediately produce for inspection or copying any records required to be maintained at the facility. Upon written request at other times, the permittee shall deliver to the Department paper or electronic copies of any and all required records maintained on site or at an off-site location. Requested records shall be copied and delivered at the permittee's expense within three business days from receipt of request unless the Department allows additional time. Required records may include records required by permit and other information necessary to demonstrate compliance with terms and conditions of this permit. (NMSA 1978, Section 74-2-13) B. A copy of the most recent permit(s) issued by the Department shall be kept at the permitted facility or (for unmanned sites) at the nearest company office and shall be made available to Department personnel for inspection upon request. (20.2.70.302.G.3 NMAC) C. Emissions limits associated with the energy input of a Unit, i.e. lb/MMBtu, shall apply at all times unless stated otherwise in a Specific Condition of this permit. The averaging time for each emissions limit, including those based on energy input of a Unit (i.e. lb/MMBtu) is one (1) hour unless stated otherwise in a Specific Condition of this permit or in the applicable requirement that establishes the limit. (20.2.70.302.A.1 and G.3 NMAC) D. The permittee shall submit compliance certification reports certifying the compliance status of this facility with respect to all permit terms and conditions, including applicable requirements. These reports shall be made on the pre-populated Compliance Certification Report Form that is provided to the permittee by the Department, and shall be submitted to the Department and to EPA at least every 12 months. For the most current form, please EPA Inspection Report - Page 195 of 1969 contact the Compliance Reports Group at email:reportsgroup.aqb@state.nm.us. For additional reporting guidance see http://www.nmenv.state.nm.us/aqb/enforce_compliance/TitleVReporting.htm. (20.2.70.302.E.3 NMAC) E. The permittee shall allow representatives of the Department, upon presentation of credentials and other documents as may be required by law, to do the following (20.2.70.302.G.1 NMAC): (1) enter the permittee's premises where a source or emission unit is located, or where records that are required by this permit to be maintained are kept; (2) have access to and copy, at reasonable times, any records that are required by this permit to be maintained; (3) inspect any facilities, equipment (including monitoring and air pollution control equipment), work practices or operations regulated or required under this permit; and (4) sample or monitor any substances or parameters for the purpose of assuring compliance with this permit or applicable requirements or as otherwise authorized by the Federal Act. B113 Permit Reopening and Revocation A. This permit will be reopened and revised when any one of the following conditions occurs, and may be revoked and reissued when A(3) or A(4) occurs. (20.2.70.405.A.1 NMAC) (1) Additional applicable requirements under the Federal Act become applicable to a major source three (3) or more years before the expiration date of this permit. If the effective date of the requirement is later than the expiration date of this permit, then the permit is not required to be reopened unless the original permit or any of its terms and conditions has been extended due to the Department's failure to take timely action on a request by the permittee to renew this permit. (2) Additional requirements, including excess emissions requirements, become applicable to this source under Title IV of the Federal Act (the acid rain program). Upon approval by the Administrator, excess emissions offset plans will be incorporated into this permit. (3) The Department or the Administrator determines that the permit contains a material mistake or that inaccurate statements were made in establishing the terms and conditions of the permit. (4) The Department or the Administrator determines that the permit must be revised or revoked and reissued to assure compliance with an applicable requirement. B. Proceedings to reopen or revoke this permit shall affect only those parts of this permit for which cause to reopen or revoke exists. Emissions units for which permit conditions have EPA Inspection Report - Page 196 of 1969 been revoked shall not be operated until new permit conditions have been issued for them. (20.2.70.405.A.2 NMAC) B114 Emergencies (20.2.70.304 NMAC) A. An "emergency" means any situation arising from sudden and reasonably unforeseeable events beyond the control of the permittee, including acts of God, which situation requires immediate corrective action to restore normal operation, and that causes the source to exceed a technology-based emission limitation under the permit due to unavoidable increases in emissions attributable to the emergency. An emergency shall not include noncompliance to the extent caused by improperly designed equipment, lack of preventive maintenance, or careless or improper operation. B. An emergency constitutes an affirmative defense to an action brought for noncompliance with technology-based emission limitations contained in this permit if the permittee has demonstrated through properly signed, contemporaneous operating logs, or other relevant evidence that: (1) An emergency occurred and that the permittee can identify the cause(s) of the emergency; (2) This facility was at the time being properly operated; (3) During the period of the emergency the permittee took all reasonable steps to minimize levels of emissions that exceeded the emission standards or other requirements in this permit; and (4) The permittee submitted notice of the emergency to the Department within 2 working days of the time when emission limitations were exceeded due to the emergency. This notice fulfills the requirement of 20.2.70.302.E.2 NMAC. This notice must contain a description of the emergency, any steps taken to mitigate emissions, and corrective actions taken. C. In any enforcement proceeding, the permittee seeking to establish the occurrence of an emergency has the burden of proof. D. This provision is in addition to any emergency or upset provision contained in any applicable requirement. B115 Stratospheric Ozone (20.2.70.302.A.1 NMAC) A. If this facility is subject to 40 CFR 82, Subpart F, the permittee shall comply with the following standards for recycling and emissions reductions: EPA Inspection Report - Page 197 of 1969 (1) Persons opening appliances for maintenance, service, repair, or disposal must comply with the required practices, except for motor vehicle air conditioners (MVAC) and MVAC-like appliances. (40 CFR 82.156) (2) Equipment used during the maintenance, service, repair, or disposal of appliances must comply with the standards for recycling and recovery equipment. (40 CFR 82.158) (3) Persons performing maintenance, service, repair, or disposal of appliances must be certified by an approved technician certification program. (40 CFR 82.161) B116 Acid Rain Sources (20.2.70.302.A.9 NMAC) A. If this facility is subject to the federal acid rain program under 40 CFR 72, this section applies. B. Where an applicable requirement of the Federal Act is more stringent than an applicable requirement of regulations promulgated under Title IV of the Federal Act, both provisions are incorporated into this permit and are federally enforceable. C. Emissions exceeding any allowances held by the permittee under Title IV of the Federal Act or the regulations promulgated thereunder are prohibited. D. No modification of this permit is required for increases in emissions that are authorized by allowances acquired pursuant to the acid rain program, provided that such increases do not require a permit modification under any other applicable requirement. E. The permittee may not use allowances as a defense to noncompliance with any other applicable requirement. F. No limit is placed on the number of allowances held by the acid rain source. Any such allowance shall be accounted for according to the procedures established in regulations promulgated under Title IV of the Federal Act. G. The acid rain permit is an enclosure of this operating permit. B117 Risk Management Plan (20.2.70.302.A.1 NMAC) A. If this facility is subject to the federal risk management program under 40 CFR 68, this section applies. B. The owner or operator shall certify annually that they have developed and implemented a RMP and are in compliance with 40 CFR 68. EPA Inspection Report - Page 198 of 1969 C. If the owner or operator of the facility has not developed and submitted a risk management plan according to 40 CFR 68.150, the owner or operator shall provide a compliance schedule for the development and implementation of the plan. The plan shall describe, in detail, procedures for assessing the accidental release hazard, preventing accidental releases, and developing an emergency response plan to an accidental release. The plan shall be submitted in a method and format to a central point as specified by EPA prior to the date specified in 40 CFR 68.150.b. PART C MISCELLANEOUS C100 Supporting On-Line Documents A. Copies of the following documents can be downloaded from NMED's web site under Compliance and Enforcement or requested from the Bureau. (1) Excess Emission Form (for reporting deviations and emergencies) (2) Compliance Certification Report Form (3) Universal Stack Test Notification, Protocol and Report Form and Instructions (4) SOP for Use of Portable Analyzers in Performance Tests C101 Definitions A. "Daylight" is defined as the time period between sunrise and sunset, as defined by the Astronomical Applications Department of the U.S. Naval Observatory. (Data for one day or a table of sunrise/sunset for an entire year can be obtained at http://aa.usno.navy.mil/. Alternatively, these times can be obtained from a Farmers Almanac or from http://www.almanac.com/rise/). B. "Exempt Sources" and "Exempt Activities" is defined as those sources or activities that are exempted in accordance with 20.2.72.202 NMAC. Note; exemptions are only valid for most 20.2.72 permitting action. C. "Fugitive emission" means those emissions which could not reasonably pass through a stack, chimney, vent, or other functionally equivalent opening. (20.2.70.7M NMAC) D. "Insignificant Activities" means those activities which have been listed by the department and approved by the administrator as insignificant on the basis of size, emissions or production rate. (20.2.70.7Q NMAC) E. "Malfunction" for the requirements under 20.2.7 NMAC, means any sudden and unavoidable failure of air pollution control equipment or process equipment beyond the control of the owner or operator, including malfunction during startup or shutdown. A EPA Inspection Report - Page 199 of 1969 failure that is caused entirely or in part by poor maintenance, careless operation, or any other preventable equipment breakdown shall not be considered a malfunction. F. "Natural Gas" is defined as a naturally occurring fluid mixture of hydrocarbons that contains 20.0 grains or less of total sulfur per 100 standard cubic feet (SCF) and is either composed of at least 70% methane by volume or has a gross calorific value of between 950 and 1100 Btu per standard cubic foot. (40 CFR 60.331) G. "Natural Gas Liquids" means the hydrocarbons, such as ethane, propane, butane, and pentane, that are extracted from field gas. (40 CFR 60.631) H. "National Ambient Air Quality Standards" means the primary (health-based) and secondary (welfare-related) federal ambient air quality standards promulgated by the US EPA pursuant to Section 109 of the Federal Act. (20.2.72.7Q NMAC) I. "NO2" or "Nitrogen dioxide" means the chemical compound containing one atom of nitrogen and two atoms of oxygen, for the purposes of ambient determinations. The term "nitrogen dioxide," for the purposes of stack emissions monitoring, shall include nitrogen dioxide (the chemical compound containing one atom of nitrogen and two atoms of oxygen), nitric oxide (the chemical compound containing one atom of nitrogen and one atom of oxygen), and other oxides of nitrogen which may test as nitrogen dioxide and is sometimes referred to as NOx or NO2. (20.2.2.7U NMAC) J. "NOx" see NO2 K. "Paved Road" is a road with a permanent solid surface that can be swept essentially free of dust or other material to reduce air re-entrainment of particulate matter. To the extent these surfaces remain solid and contiguous they qualify as paved roads: concrete, asphalt, chip seal, recycled asphalt and other surfaces approved by the Department in writing. L. "Potential Emission Rate" means the emission rate of a source at its maximum capacity to emit a regulated air contaminant under its physical and operational design, provided any physical or operational limitation on the capacity of the source to emit a regulated air contaminant, including air pollution control equipment and restrictions on hours of operation or on the type or amount of material combusted, stored or processed, shall be treated as part of its physical and operational design only if the limitation or the effect it would have on emissions is enforceable by the department pursuant to the Air Quality Control Act or the Federal Act. (20.2.72.7Y NMAC) M. "Restricted Area-Non Military" is an area to which public entry is effectively precluded. Effective barriers include continuous fencing, continuous walls, or other continuous barriers approved by the Department, such as rugged physical terrain with a steep grade that would require special equipment to traverse. If a large property is completely enclosed by fencing, a restricted area within the property may be identified with signage only. Public roads cannot be part of a Restricted Area. N. "Shutdown" for requirements under 20.2.72.7BB NMAC, means the cessation of operation of any air pollution control equipment, process equipment or process for any purpose, except routine phasing out of batch process units. EPA Inspection Report - Page 200 of 1969 O. "SSM" for requirements under 20.2.7 NMAC, means routine or predictable startup, shutdown, or scheduled maintenance. (1) "Shutdown" for requirements under 20.2.7.7H NMAC, means the cessation of operation of any air pollution control equipment or process equipment. (2) "Startup" for requirements under 20.2.7.7I NMAC, means the setting into operation of any air pollution control equipment or process equipment. P. "Startup" for requirements under 20.2.72.7DD NMAC, means the setting into operation of any air pollution control equipment, process equipment or process for any purpose, except routine phasing in of batch process units. C102 Acronyms 2SLB ........................................................................................................ 2-stroke lean burn 4SLB ........................................................................................................ 4-stroke lean burn 4SRB .........................................................................................................4-stroke rich burn acfm........................................................................................... actual cubic feet per minute AFR....................................................................................................................air fuel ratio AP-42 ...........................................................................EPA Air Pollutant Emission Factors AQB ........................................................................................................Air Quality Bureau AQCR ....................................................................................... Air Quality Control Region ASTM ................................................................American Society for Testing & Materials Btu.......................................................................................................... British thermal unit CAA .............................................................Clean Air Act of 1970 and 1990 Amendments CEM ................................................................................. continuous emissions monitoring cfh ........................................................................................................... cubic feet per hour cfm .......................................................................................................cubic feet per minute CFR ........................................................................................... Code of Federal Regulation CI ........................................................................................................compression ignition CO ..............................................................................................................carbon monoxide COMS ...................................................................... continuous opacity monitoring system EIB ............................................................................... Environmental Improvement Board EPA .......................................................... United States Environmental Protection Agency gr/100 cf ........................................................................... grains per one hundred cubic feet gr/dscf ..............................................................................grains per dry standard cubic foot GRI.....................................................................................................Gas Research Institute H2S ..............................................................................................................hydrogen sulfide HAP................................................................................................... hazardous air pollutant hp ....................................................................................................................... horsepower IC .........................................................................................................Internal Combustion KW/hr ...................................................................................................... kilowatts per hour lb/hr ..............................................................................................................pounds per hour lb/MMBtu ............................................................... pounds per million British thermal unit MACT ............................................................. Maximum Achievable Control Technology MMcf/hr ...................................................................................... million cubic feet per hour EPA Inspection Report - Page 201 of 1969 MMscf.........................................................................................million standard cubic feet N/A.................................................................................................................. not applicable NAAQS.................................................................National Ambient Air Quality Standards NESHAP ................................. National Emission Standards for Hazardous Air Pollutants NG ....................................................................................................................... natural gas NGL ........................................................................................................ natural gas liquids NMAAQS ......................................................New Mexico Ambient Air Quality Standards NMAC............................................................................ New Mexico Administrative Code NMED..................................................................... New Mexico Environment Department NMSA .................................................................................New Mexico Statues Annotated NOx...............................................................................................................nitrogen oxides NSCR .............................................................................. non-selective Catalytic Reduction NSPS ............................................................................. New Source Performance Standard NSR.......................................................................................................New Source Review PEM ..................................................................................parametric emissions monitoring PM................................ particulate matter (equivalent to TSP, total suspended particulate) PM10 .......................................................particulate matter 10 microns and less in diameter PM2.5 .....................................................particulate matter 2.5 microns and less in diameter pph................................................................................................................pounds per hour ppmv ......................................................................................... parts per million by volume PSD ......................................................................... Prevention of Significant Deterioration RATA................................................................................ relative accuracy test assessment RICE .................................................................... reciprocating internal combustion engine rpm .................................................................................................... revolutions per minute scfm....................................................................................... standard cubic feet per minute SI ................................................................................................................... spark ignition SO2 .................................................................................................................. sulfur dioxide SSM...................................................Startup Shutdown Maintenance (see SSM definition) TAP ........................................................................................................ Toxic Air Pollutant TBD.............................................................................................................to be determined THC..........................................................................................................total hydrocarbons TSP.......................................................................................... Total Suspended Particulates tpy ..................................................................................................................... tons per year ULSD ................................................................................................. ultra-low sulfur diesel USEPA..................................................... United States Environmental Protection Agency UTM..................................................... Universal Transverse Mercator Coordinate System UTMH................................................................Universal Transverse Mercator Horizontal UTMV....................................................................Universal Transverse Mercator Vertical VHAP...................................................................................volatile hazardous air pollutant VOC .......................................................................................... volatile organic compounds PART D ATTACHMENTS EPA Inspection Report - Page 202 of 1969 Table 103.B, Summary Applicability - Fugitives [return] Title V Permit Unit ID FUG-02-SP CRUDE FUG-05-KERO FUG-06-NHDU FUG-07-N AMINE FUG-07-SWS1 FUG-08-TRUCK RK FUG-09-N ALKY FUG-10-FCC FUG-13-NHDU FUG-18-LSR MEROX TRT FUG-20-ISOM FUG-21-SP VACUUM FUG-25-ROSE-2 FUG-29-BLENDER/TK FARM FUG-31-SRU3/TGTU3/TGI3 FUG-33-DIST HDU FUG-34-HYDROCRACKER FUG-35-SAT GAS FUG-41-PBC FUG-43-S ALKY FUG-44-DIST-HDU FUG-45-DIST-HDU FUG-63-H2 PLANT-1 FUG-64-H2 PLANT-2 FUG-70-CCR FUG-73-SP UTIL Description South Division Crude Unit Kerosene HDS Unit JP8 Hydrodesulfurization Amine Unit-Treating/Regen. Sour Water Stripper Loading Racks North Alkylation Unit (New-Inside battery limits) FCC w/CVS Naphtha HDS Unit Merox/Merichem Treating Units Powerformer/Penex Unit w/CVS Flasher/Vacuum Unit ROSE Unit Light Oil Tankage SRU3 Unit Relocated Diesel HDS Unit w/CVS WX Hydrocracker Saturates Gas Plant PBC Unit South Alky Unit (W-76) Gas Oil Hydrotreater (incl. CVS) Gas Oil Hydrotreater (incl. CVS) Hydrogen Plant Hydrogen Plant CCR Reformer (w/in battery limits) Utilities 20.2.37 YES NO NO YES YES NO YES YES YES NO NO NO YES NO YES YES YES NO NO YES NO NO NO NO YES NO MACT CC YES NO YES NO NO YES YES YES YES YES YES NO YES YES YES YES YES YES NO YES YES YES NO NO YES NO NSPS GGG NO NO NO YES YES NO YES YES YES NO NO NO NO NO NO YES NO NO NO YES NO YES NO NO YES NO NSPS GGGa YES NO NO NO NO YES NO NO NO NO NO YES YES YES YES NO YES NO NO NO NO NO NO NO NO NO NSPS QQQ YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES NESHAP NESHAP NAV-195- J V CC 1 NO NO NO NO NO NO NO NO NO NO NO YES NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO EPA Inspection Report - Page 203 of 1969 Table 103.B, Summary Applicability - Fugitives [return] Title V Permit Unit ID Description FUG-80-WWTP CVS Oil/Water Separator FUG-ASPHALT STG Asphalt/Heavy Oil Storage FUG-FUEL GAS Fuel Gas Distribution System FUG-LPG LPG Storage System FUG-RLO-ASPHALT Asphalt/Pitch Loading Rack FUG-SRU1/SRU2/TGTU SRU1/SRU2/SWS w/CVS FUG-RRTOTRUCK Crude oil unloading system, closed loop system between railcars and trucks. 1 NAV-195-CC represents those units not subject to MACT CC, but Navajo has decided to voluntarily to follow the fugitive LDAR program consistent with MACT CC monitoring requirements. 20.2.37 YES NO NO NO NO YES NO MACT CC YES NO YES NO NO NO NO NSPS GGG YES NO NO NO NO YES NO NSPS GGGa NO NO NO NO NO NO NO NSPS QQQ YES YES YES YES YES YES YES NESHAP NESHAP NAV-195- J V CC 1 NO NO YES NO NO NO NO NO NO NO NO YES NO NO NO NO NO YES NO NO NO EPA Inspection Report - Page 204 of 1969 Table 103.C, Summary Applicability - Tanks MACT NSPS NSPS NSPS CC MACT CC Tank No. K Ka Kb Storage Wastewater RW-4 NO NO NO NO N/A RW-5 NO NO NO NO N/A RW-6 NO NO NO NO N/A T-0001 NO NO NO NO YES T-0002 NO NO NO NO YES T-0003 NO NO NO NO YES T-0004 NO NO NO NO YES T-0011 NO NO NO YES N/A T-0012 NO NO NO YES N/A T-0013 NO NO NO YES N/A T-0026 NO NO NO NO N/A T-0028 NO NO NO NO N/A T-0031 NO NO NO NO N/A T-0040 NO NO NO YES N/A T-0041 NO NO NO YES N/A T-0042 NO NO NO NO N/A T-0045 NO NO NO NO N/A T-0046 NO NO NO NO N/A T-0049 NO NO NO YES N/A T-0055 NO NO NO YES N/A T-0056 NO NO NO YES N/A T-0057 NO YES NO YES N/A T-0059 NO NO NO YES N/A T-0061 NO NO NO YES N/A T-0063 NO NO NO YES N/A T-0064 NO NO NO NO N/A T-0065 NO NO YES YES N/A T-0071 NO NO NO NO N/A T-0072 NO NO NO NO N/A T-0073 NO NO NO NO N/A T-0074 NO NO NO NO N/A T-0075 NO NO YES YES N/A NESHAP FF N/A N/A N/A YES YES YES NO N/A N/A YES N/A N/A N/A N/A N/A N/A N/A N/A YES N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A NSPS QQQ N/A N/A N/A NO NO NO NO N/A N/A YES N/A N/A N/A N/A N/A N/A N/A N/A YES N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 20.2.37.205 NMAC NO NO NO NO NO NO NO YES YES NO NO NO NO NO NO YES YES YES NO YES YES YES NO NO NO NO YES YES YES YES YES YES 20.2.38.109 NMAC NO NO NO NO NO NO NO YES YES NO NO NO NO NO NO YES NO NO NO NO YES YES NO NO NO NO NO NO NO NO NO NO 20.2.38.110 NMAC YES YES YES NO NO NO NO YES YES NO NO NO NO NO NO YES NO NO NO NO YES YES NO NO NO NO NO NO NO NO NO NO 20.2.38.112 NMAC NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES YES YES NO YES NO YES NO NO NO NO YES YES YES YES YES YES 20.2.38.113 NMAC YES NO YES NO NO NO NO NO NO NO NO NO NO NO NO YES NO NO NO NO NO YES NO NO NO NO NO NO NO NO NO NO CAM NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO EPA Inspection Report - Page 205 of 1969 Table 103.C, Summary Applicability - Tanks MACT NSPS NSPS NSPS CC MACT CC Tank No. K Ka Kb Storage Wastewater T-0076 NO NO NO NO N/A T-0078 NO NO YES YES N/A T-0079 NO NO YES YES N/A T-0081 NO NO YES YES N/A T-0082 NO NO YES YES N/A T-0106 NO NO NO YES N/A T-0107 NO NO NO YES N/A T-0108 NO NO NO YES N/A T-0109 NO NO NO YES N/A T-0110 NO NO NO YES N/A T-0111 NO NO NO YES N/A T-0112 NO NO NO YES N/A T-0114 NO NO NO NO N/A T-0115 NO NO NO NO N/A T-0116 NO NO NO NO N/A T-0117 NO NO NO YES N/A T-0119 NO NO NO NO N/A T-0124 NO YES NO YES N/A T-0400 NO NO NO YES N/A T-0401 NO YES NO YES N/A T-0402 NO YES NO YES N/A T-0404 NO NO NO YES N/A T-0405 NO NO NO YES N/A T-0409 NO NO NO YES N/A T-0410 NO NO NO YES N/A T-0411 NO NO NO YES N/A T-0412 NO NO NO YES N/A T-0413 NO NO NO YES N/A T-0415 NO NO NO YES N/A T-0417 NO NO NO YES N/A T-0418 NO NO NO YES N/A T-0419 NO NO NO YES N/A T-0420 NO NO NO YES N/A T-0422 NO NO NO YES N/A NESHAP FF N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A NSPS QQQ N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 20.2.37.205 NMAC YES YES YES YES YES YES YES YES YES NO YES YES YES YES YES YES YES YES YES YES YES NO NO NO NO YES YES YES YES YES NO NO NO NO 20.2.38.109 NMAC NO YES YES NO NO YES YES YES YES NO YES YES NO NO NO YES NO YES NO YES YES NO NO NO NO YES YES YES YES YES NO NO NO NO 20.2.38.110 NMAC NO YES YES NO NO YES YES YES YES NO YES YES NO NO NO YES NO YES NO YES YES NO NO NO NO YES YES YES YES YES NO NO NO NO 20.2.38.112 NMAC YES YES YES YES YES NO NO NO NO NO NO NO YES YES YES NO YES YES YES YES YES NO NO NO NO NO NO NO NO NO NO NO NO NO 20.2.38.113 NMAC NO YES YES NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES NO YES YES NO NO NO NO NO NO NO NO NO NO NO NO NO CAM NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO EPA Inspection Report - Page 206 of 1969 Table 103.C, Summary Applicability - Tanks MACT NSPS NSPS NSPS CC MACT CC Tank No. K Ka Kb Storage Wastewater T-0423 NO NO NO YES N/A T-0431 NO NO NO YES N/A T-0432 NO NO NO YES N/A T-0433 NO NO NO YES N/A T-0434 NO NO NO YES N/A T-0435 NO NO YES YES N/A T-0437 YES NO NO YES N/A T-0438 NO NO NO YES N/A T-0439 NO YES NO YES N/A T-0446 NO NO NO NO N/A T-0447 NO NO NO NO N/A T-0448 NO NO NO NO N/A T-0449 NO NO NO NO N/A T-0450 NO NO YES YES N/A T-0453 NO NO NO NO N/A T-0460 NO NO NO NO N/A T-0465 NO NO NO NO N/A T-0466 NO NO NO NO N/A T-0467 NO NO NO NO N/A T-0468 NO NO NO NO N/A T-0600 NO NO NO NO N/A T-0737 NO NO YES YES N/A T-0802 NO NO YES YES N/A T-0803 NO NO NO NO YES T-0804 NO NO NO NO YES T-0807 NO NO NO NO N/A T-0809 NO NO NO NO YES T-0810 NO NO NO NO N/A T-0814 NO NO YES YES N/A T-0815 NO NO YES YES N/A T-0816 NO NO NO NO N/A T-0830 NO NO YES NO YES T-0834 NO NO NO YES N/A T-0835 NO NO NO YES N/A NESHAP FF N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A YES YES N/A YES YES N/A N/A N/A YES N/A N/A NSPS QQQ N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A NO NO N/A NO YES N/A N/A N/A YES N/A N/A 20.2.37.205 NMAC NO NO NO NO YES YES YES YES YES NO NO NO NO YES NO NO NO NO NO NO NO YES YES NO NO NO NO NO YES YES YES YES NO YES 20.2.38.109 NMAC NO NO NO NO NO YES YES NO YES NO NO NO NO YES NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES 20.2.38.110 NMAC NO NO NO NO NO YES YES NO YES NO NO NO NO YES NO NO NO NO NO NO NO YES YES NO NO NO NO NO NO NO NO NO NO YES 20.2.38.112 NMAC NO NO NO NO YES YES YES YES YES NO NO NO NO YES NO NO NO NO NO NO NO YES YES NO NO NO NO NO YES YES NO YES NO NO 20.2.38.113 NMAC NO NO NO NO NO YES YES NO YES NO NO NO NO YES NO NO NO NO NO NO NO YES YES NO NO NO NO NO NO NO NO NO NO NO CAM NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO EPA Inspection Report - Page 207 of 1969 Table 103.C, Summary Applicability - Tanks MACT NSPS NSPS NSPS CC MACT CC Tank No. K Ka Kb Storage Wastewater T-0838 NO NO NO YES N/A T-0839 NO NO NO NO N/A T-0840 NO NO NO NO N/A T-0841 NO NO NO NO N/A T-0891 NO NO NO NO N/A T-0892 NO NO NO NO N/A T-1221 NO NO NO NO N/A T-1222 NO NO NO NO N/A T-1223 NO NO NO NO N/A T-1224 NO NO NO NO YES T-1225 NO NO YES YES N/A T-1227 NO NO YES YES N/A BioDiesel NO NO NO NO N/A Ethanol NO NO YES NO N/A NESHAP FF N/A N/A N/A N/A N/A N/A N/A N/A N/A YES N/A N/A N/A N/A NSPS QQQ N/A N/A N/A N/A N/A N/A N/A N/A N/A NO N/A N/A N/A N/A 20.2.37.205 NMAC YES NO NO NO NO NO NO NO NO NO YES YES NO NO 20.2.38.109 NMAC NO NO NO NO NO NO NO NO NO NO YES NO NO NO 20.2.38.110 NMAC NO NO NO NO NO NO NO NO NO NO YES NO NO NO 20.2.38.112 NMAC NO NO NO NO NO NO NO NO NO NO YES YES NO NO 20.2.38.113 NMAC NO NO NO NO NO NO NO NO NO NO YES NO NO NO CAM NO NO NO NO NO NO NO NO NO NO NO NO NO NO Table 103.D, Summary Applicability - Loading Unit ID TL-4 TL-7 RLO-8 Description Fuels Truck Loading Rack CBO/LCO Truck Loading Rack Railcar Loading & Off-Loading Rack MACT CC YES NO NO 20.2.37.205.C NO NO NO MACT BBBBBB NO NO NO MACT CCCCCC NO NO NO CAM NO NO NO EPA Inspection Report - Page 208 of 1969 Table 103.E, Summary Applicability - Heaters and Boilers Unit ID B-0007 B-0008 B-0009 H-0009 H-0011 H-0018 H-0019 H-0020 H-0028 H-0030 H-0040 H-0303 H-0312 H-0352 H-0353 H-0354 H-0355 Description Boiler 7 Boiler 8 Boiler 9 Unit 13 Naphtha Splitter Reboiler Unit 21 Vacuum Unit Heater Unit 06 HDS Reboiler South Crude Charge Heater South Crude Charge Heater Unit 21 Heater H-28 Unit 06 Charge Heater Unit 13 Charge Heater Unit 05 Charge Heater Unit 10 FCC Feed Heater Unit 70 CCR Reformer Heater Unit 70 CCR Reformer Heater Unit 70 CCR Reformer Heater Unit 70 Stabilizer Reboiler Heater NSPS D NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NSPS Db YES YES YES NO NO NO NO NO NO NO NO NO NO NO NO NO NO NSPS Dc NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO H-0362 Unit 70 CCR Heater NO NO NO NSPS J YES YES NO YES NSPS Ja NO NO Yes NO YES NO YES NO YES NO YES NO YES NO YES NO YES NO YES NO YES NO YES NO YES NO YES NO YES NO YES NO MACT DDDDD YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES H-0363 Unit 70 CCR Heater NO NO NO YES NO YES 20.2.33.108 NMAC YES YES YES NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO 20.2.36 NMAC YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES 20.2.37 NMAC YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES CAM NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO EPA Inspection Report - Page 209 of 1969 Table 103.E, Summary Applicability - Heaters and Boilers Unit ID Description NSPS D NSPS Db NSPS Dc H-0364 Unit 70 CCR Heater NO NO NO NSPS J NSPS Ja YES NO MACT DDDDD YES H-0421 Unit 44 Charge Heater NO NO NO YES NO YES H-0464 SRU Hot Oil Heater NO NO YES YES NO NO H-0473 H-0600 SRU1 and SRU2 Tail Gas Incinerator NO NO NO YES NO NO Unit 09 Depropanizer Reboiler Heater NO NO NO YES NO YES H-0601 Unit 33 Charge Heater NO NO NO YES NO YES H-2421 Unit 45 Charge Heater NO NO NO YES NO YES H-8801/ Unit 63 Hydrogen Plant H-8802 Reformer NO NO NO YES NO YES H-3402 Unit 34 Hydrocracker Reboiler 1 NO NO NO NO YES YES H-3403 Hydrocracker Reactor Charge Heater NO NO NO NO YES YES H-9851 Unit 64 Hydrogen Plant Reformer NO NO NO NO YES YES H-2501 Unit 25 ROSE Unit NO YES NO NO YES YES No.2 Hot Oil Heater H-3101 (formerly SRU3- SRU3 Hot Oil Heater NO NO NO NO YES NO HOH) SRU3-TGI SRU3 Tail Gas Incinerator NO NO NO NO YES NO 20.2.33.108 NMAC NO NO NO NO NO NO NO YES NO NO YES YES NO NO 20.2.36 NMAC YES YES YES YES YES YES YES YES YES YES YES YES YES YES 20.2.37 NMAC YES YES YES YES YES YES YES YES YES YES YES YES CAM NO NO NO NO NO NO NO NO NO NO NO NO YES NO YES NO EPA Inspection Report - Page 210 of 1969 Table 103.F, Summary Applicability - Cooling Towers Cooling Tower Y-0001 Y-0002 Y-0008 Y-0011 Y-0012 CT TT-0006 Description TCC Cooling Tower S. Alky Cooling Tower (Marley Cooling Tower) North Alky Cooling Tower FCC & NP Cooling Tower Hydrogen Plants Cooling Tower Unit 07 Amine W-0745 Cooling Tower MACT Q YES YES YES NO NO NO Table 103.G, Summary Applicability - Wastewater [return] Equipment ID MAIN API DAF-0896 DAF-0806 T-0801 T-0805 T-0829 T-0836 T-0897 Emission Point ID D-0829/0830 DAF-0896 DAF-0806 MACT CC Wastewater YES YES YES YES YES YES YES YES NESHAP FF YES YES YES YES YES YES YES YES MACT CC YES YES YES YES YES NO NSPS QQQ YES NO NO NO NO NO NO NO CAM NO NO NO NO NO NO CAM NO NO NO NO NO NO NO NO EPA Inspection Report - Page 211 of 1969 Table 103.H, Summary Applicability - FCC-CCR Unit ID FCCREGEN NSPS J YES NSPS Ja NO MACT UUU YES 20.2.37 NMAC YES CCR N/A N/A YES N/A CAM YES Satisfied by MACT UUU NO Table 103.I, Summary Applicability - SRU Source ID SRU1 SRU2 SRU3 Emission Point ID H-0473 H-0473 SRU3-TGI Description SRU1 and SRU2 Tail Gas Incinerator SRU1 and SRU2 Tail Gas Incinerator SRU3 Tail Gas Incinerator NSPS J YES YES NO NSPS Ja NO NO YES MACT UUU YES YES YES 20.2.36.113.A(1)(d) & 20.2.36.113.A(1)(e) YES YES YES 20.2.37.200B YES YES YES 20.2.37.202.A YES YES YES 20.2.39 NO NO NO CAM YES-Satisfied by MACT UUU YES-Satisfied by MACT UUU YES-Satisfied by MACT UUU EPA Inspection Report - Page 212 of 1969 Table 103.J, Summary Applicability - Engines [return] Source ID E-0600W E-0601M E-0602E E-0603 E-0901 G-0100 G-0101 V-0543 V-0545 V-0546 E-8010 Description Fire Water Pump Engine Fire Water Pump Engine Fire Water Pump Engine Fire Water Pump Engine Fire Water Pump Engine UPS backup generator UPS backup generator Portable Air Compressor Portable Air Compressor Portable Air Compressor WWTP Emergency Engine NSPS IIII YES YES YES YES YES NO NO YES YES YES YES MACT ZZZZ YES YES YES YES YES YES YES YES YES YES YES 20.2.61.109 NMAC YES YES YES YES YES YES YES YES YES YES YES 20.2.61.114 NMAC YES YES YES YES YES YES YES YES YES YES YES CAM NO NO NO NO NO NO NO NO NO NO NO Table 103.K, Summary Applicability - FLARES [return] Unit ID FL-400 Description North Plant Flare NSPS A YES NSPS J NO NSPS Ja YES NESHAP A NO FL-401 South Plant Flare YES NO YES NO FL-402 FCCU Flare YES NO YES NO FL-403 Alky Flare YES NO YES NO FL-404 GOHT Flare YES NO YES NO All flares are steam assisted. State of New Mexico requires that an exit gas velocity of 65 ft/sec for modeling. The heating value of the gas for all flares is < 1000 BTU/scf. MACT A YES YES YES YES YES 20.2.36.112 NMAC YES YES YES YES YES 20.2.36.113b NMAC YES YES YES YES YES 20.2.37.201B NMAC YES YES YES YES YES EPA Inspection Report - Page 213 of 1969 Table 104.A: Regulated Sources List [return to A104][return to A201Engines] Unit No. Unit Type Manufacturer Model No. B-0007 B-0008 B-0009 E-8010 E-0600W E-0601M E-0602E E-0603 E-0901 G-0100 G-0101 V-0543 V-0545 V-0546 H-0009 H-0011 H-0018 H-0019 H-0020 H-0028 H-0030 H-0040 H-0303 H-0312 Boiler 7 Boiler 8 Boiler 9 WWTP Diesel Pump Engine Fire Water Pump Engine Fire Water Pump Engine Fire Water Pump Engine Fire Water Pump Engine Fire Water Pump Engine UPS backup generator UPS backup generator Portable Air Compressor Portable Air Compressor Portable Air Compressor Unit 13 Naphtha Splitter Reboiler Unit 21 Vacuum Flasher Heater Naphtha HDS Reboiler South Crude Charge Heater South Crude Charge Heater Unit 21 Heater H-28 (previously H-10) Unit 06 Charge Heater Unit 13 Charge Heater Unit 05 Charge Heater Unit 10 FCC Feed Heater Todd/John Zink burners Unknown Todd/John Zink burners Unknown Babcock & Wilcox TBD 6090HF485/ John Deere RG6090L101484 Clarke Diesel (John Deere) JW6H-UFAD70/ RG6090L113548 Clarke Diesel (John Deere) JW6H-UFAD70/ RG6090L113561 Clarke Diesel (John Deere) JW6H-UFAD70/ RG6090L113574 Clarke Diesel (John Deere) JU6H-UFADX8/ PE6068L228486 Clarke Diesel (John Deere) JX6H-UF30' RG6125A016118 Deutz F4L912GEN/ Engine WDZXL05.7010 Family Deutz F4L 1011 F/ EI97-68CA00-000-0053 Cummings, Inc. QSC, 73104611 Cummings, Inc. QSC, 73142120 Cummings, Inc. QSC, 46917364 Zeeco burners GSFW-12 burners Unknown Unknown Zeeco burners GSFW-8 burners Callidus Technologies, LLC burners CUBL-8W burners Callidus Technologies, LLC burners CUBL-12W burners John Zink burners PSFG-12 burners John Zink burners PSFG-16R burners John Zink burners PSFG-16 burners John Zink burners HEVD-Q-18 burners John Zink burners VYD-18 burners Manufacture Date 10/8/2001 * 2003 * TBD 2/2011 7/2012 7/2012 7/2012 2012 10/2007 1998 1999 8/30/2010 4/8/2011 11/19/2008 Unknown Unknown Unknown New burners in 2005 New burners in 2005 Unknown 2000* 1990* 1982* 1990* H-0352 H-0353 H-0354 H-0355 H-0362 Callidus Technologies, LLC Unit 70 CCR Heater (previously 70-H1) burners CUBL-10W burners Callidus Technologies, LLC Unit 70 CCR Heater (previously 70-H2) burners CUBL-10W burners Callidus Technologies, LLC Unit 70 CCR Heater (previously 70-H3) burners CUBL-10W burners Unit 70 Stabilizer Reboiler Heater H-355 (previously 70H-4) John Zink burners Unknown Callidus Technologies, LLC Unit 70 CCR Heater burners CUBL-8W burners New burners in 2006 New burners in 2006 New burners in 2006 1991* New burners in 2006 Capacity 215 MMBtu/hr (LHV Basis) 215 MMBtu/hr (LHV Basis) 220 MMBtu/hr (LHV Basis) 400 hp 376 hp 376 hp 376 hp 305 hp 430 hp 52 hp 54 hp 260 hp 260 hp 240 hp 44 MMBtu/hr (LHV Basis) 38 MMBtu/hr (LHV Basis) 32 MMBtu/hr (LHV Basis) 54 MMBtu/hr (LHV Basis) 78 MMBtu/hr (LHV Basis) 12.3 MMBtu/hr (LHV Basis) 42 MMBtu/hr (LHV Basis) 42 MMBtu/hr (LHV Basis) 11 MMBtu/hr (LHV Basis) 35 MMBtu/hr (LHV Basis) 63 MMBtu/hr (LHV Basis) 81 MMBtu/hr (LHV Basis) 56 MMBtu/hr (LHV Basis) 24 MMBtu/hr (LHV Basis) 40 MMBtu/hr (LHV Basis) EPA Inspection Report - Page 214 of 1969 Table 104.A: Regulated Sources List [return to A104][return to A201Engines] Unit No. Unit Type Manufacturer Model No. H-0363 H-0364 H-0421 H-0464 H-0600 H-0601 H-2421 H-8801 H-8802 H-2501 H-3403 H-3402 H-9851 H-3101 H-0473 (SRU1/SRU2 TGI) SRU3-TGI FCC Regenerator CCRr FL-0400, North Plant Flare FL-0401, South Plant Flare FL-0402, FCC Flare FL-0403, Alky Flare FL-0404, GOHT Flare Y-0001 Y-0002 Y-0008 Y-0011 Y-0012 Callidus Technologies, LLC Unit 70 CCR Heater burners CUBL-8W burners Callidus Technologies, LLC Unit 70 CCR Heater burners CUBL-6W burners Unit 44 Charge Heater (previously H-21) John Zink burners LNC-PC-18 burners Callidus Technologies, LLC SRU Hot Oil Heater burners LE-CSG-4W burners Depropanizer Reboiler Heater (previously Callidus Technologies, LLC 3F-1) burners CUBL-12W burners Callidus Technologies, LLC Unit 33 Charge Heater burners CUB-8P-CW burners GLSF-14 Round Flame Unit 45 Charge Heater Zeeco, Inc. burners "Free Jet" burners Callidus Technologies, LLC LE-CSG-12W-PSA Unit 63 Hydrogen Plant Reformer Furnace burners burners Callidus Technologies, LLC LE-CSG-12W-PSA Unit 63 Hydrogen Plant Reformer Furnace burners burners John Zink Company, LLC ROSE2 Hot Oil Heater burners COOLstar-18 burners Callidus Technologies, LLC Hydrocracker Reactor Charge Heater burners CUBL-10W burners Callidus Technologies, LLC Hydrocracker Fractionator Reboiler 1 burners LE-CSG-12W burners Callidus Technologies, LLC Unit 64 Hydrogen Plant Reformer burners CUBL-3WDF burners Callidus Technologies, LLC SRU3 Hot Oil Heater burner Unknown SRU1 and SRU2 Tail Gas Incinerator Unknown Unknown Callidus Technologies, LLC SRU3 Tail Gas Incinerator burners Unknown FCC Regenerator Scrubber Unknown Unknown CCR Reformer Unknown Unknown North Plant Flare Unknown Unknown South Plant Flare Unknown Unknown FCC Flare Unknown Unknown Alky Flare GOHT Flare TCC Cooling Tower S. Alky Cooling Tower (Marley Tower) North Alky Cooling Tower FCC & NP Cooling Tower Hydrogen Plants Cooling Tower Cooling Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Manufacture Date New burners in 2006 New burners in 2006 1981* 2003* 1991*, New burners in 2009 New burners in 2003 2006* 2006* 2006* 2009* TBD 2009* 2009* 05/11/2009 * Unknown 05/11/2009 * Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Capacity 50 MMBtu/hr (LHV Basis) 35 MMBtu/hr (LHV Basis) 27 MMBtu/hr (LHV Basis) 9.6 MMBtu/hr (LHV Basis) 84 MMBtu/hr (LHV Basis) 78 MMBtu/hr (LHV Basis) 27 MMBtu/hr (LHV Basis) 60 MMBtu/hr (LHV Basis) 60 MMBtu/hr (LHV Basis) 120 MMBtu/hr (LHV Basis) 32.0 MMBtu/hr (LHV Basis) 52 MMBtu/hr (LHV Basis) 337 MMBtu/hr (LHV Basis) 9.6 MMBtu/hr (LHV Basis) NA NA NA NA NA NA NA NA NA 5,000 gpm, 0.003% drift 5,000 gpm, 0.003% drift 12,500 gpm, 0.003% drift 30,000 gpm, 0.001% drift 10,000 gpm, 0.001% drift EPA Inspection Report - Page 215 of 1969 Table 104.A: Regulated Sources List [return to A104][return to A201Engines] Unit No. Unit Type Manufacturer Model No. Manufacture Date Capacity CT TT-0006 Unit 07 Amine W-0745 Cooling Tower Unknown Unknown Unknown 3,000 gpm, 0.003% drift MAIN API Above Ground API Oil-Water Separator Unknown Unknown Unknown 1,200 gpm T-0896 DAF Unit T-0896 Unknown Unknown Unknown 1,200 gpm T-0801 Enhanced Biodegradation Tank T-0801 Unknown Unknown Unknown 1,200 gpm T-0836 Enhanced Biodegradation Tank T-0836 Unknown Unknown Unknown 1,200 gpm T-0829 Equalization Tank T-0829 Not yet installed Not yet installed Not yet installed 1,200 gpm T-0806 DAF Unit T-0806 Not yet installed Not yet installed Not yet installed Not yet installed Equipment component leaks (pump seals, Fugitives (see Table 103.B) valves, flanges, etc.) NA NA Varies NA Loading (see Table 103.D) Bulk Loading/Unloading Racks NA NA Varies Varies Fixed Roof, External Floating Roof & Tanks (see Table 103.C) Internal Floating Roof Tanks NA NA Varies Varies * Installation date Note: Serial numbers are not used since most equipment consists of field erected parts that are assembled on site and may have several "serial numbers" for various components. Heaters are the best example because each of the burners has a serial number but the heater as a whole does not have a single serial number. The heater as a whole is typically identified by our equipment number. There may also be a "project number" or "job number" from the manufacturer, but that can change if a heater is revamped at a later date such as when they modify the convection section to improve energy efficiency. EPA Inspection Report - Page 216 of 1969 Table 106.A Allowable Emission Limits [return A106] Source ID B-0007 B-0008 B-0009 H-0009 H-0011 H-0018 H-0019 H-0020 H-0028 H-0030 H-0040 H0352/0353/0354 H-0355 H-0303 H-0312 H0362/0363/0364 H-0421 H-0464 H-0600 H-0601 H-2421 H-8801/8802 H-2501 H-3402 H-3403 3,5MM Btu/hr 215 215 220 44 38 32 54 78 12.3 42 42 63/81/56 24 11 35 40/50/35 27 9.6 84 78 27 60/60 120 52 32.0 SO2 5 (lb/hr) 7.8 7.8 2.6 1.6 1.4 1.2 2.0 2.8 0.4 1.5 1.5 (ton/yr) 12.7 12.7 11.4 2.6 2.3 1.9 3.2 4.6 0.7 2.5 2.5 7.3 11.8 0.9 1.4 0.4 0.7 1.3 2.1 4.6 7.4 1.0 1.6 0.4 0.6 3.1 5.0 2.8 4.6 1.0 1.6 0.2 0.8 4.4 7.1 1.9 3.1 1.2 1.9 5(lb/hr) 12.9 12.9 4.4 4.0 9.5 3.5 2.9 4.2 2.2 3.2 3.8 9.0 2.2 1.2 4.6 6.9 2.4 0.5 4.7 3.5 1.2 4.2 3.6 1.6 1.0 2NOx (ton/yr) 56.5 56.5 19.3 17.3 31.6 15.2 12.5 18.3 9.5 14.0 16.6 39.4 9.5 5.2 20.2 30.1 10.6 2.3 20.3 15.4 5.3 18.4 15.8 6.8 4.2 H-9851 337 0.5 2.2 4.2 18.5 H-3101 9.6 0.4 0.6 0.3 1.3 H-0473 NA (SRU1/SRU2 30.0 81.8 6.5 28.5 TGI) SRU3-TGI NA 30.0 81.8 6.5 28.5 5(lb/MM Btu) 0.06 0.06 0.02 BACT 0.09 0.0527 0.0535 - 0.045 - 0.055 0.09 - 0.05 0.045 0.045 0.035 0.03 0.03 0.03 0.0125 BACT 0.03 N/A N/A 5(lb/hr) 19.6 19.6 8.1 4.0 3.5 2.9 4.9 7.1 1.1 3.8 3.8 18.2 2.2 1.0 3.2 11.4 2.5 0.9 7.6 7.1 2.5 10.9 7.2 4.7 2.9 20.2 0.9 27.7 15.0 CO (ton/yr) 85.7 85.7 35.7 17.5 15.2 12.8 21.5 31.1 4.9 16.8 16.8 79.7 9.6 4.4 14.0 49.8 10.8 3.8 33.5 31.1 10.8 47.8 31.5 20.7 12.8 88.6 3.8 5(lb/MM Btu LHV) 0.09 BACT 0.09 BACT 0.06 BACT 0.09 BACT 121.2 65.7 4PM (lb/hr) 1.8 1.8 1.6 0.4 0.3 0.3 0.4 0.6 0.1 0.4 0.4 1.7 0.2 0.1 0.3 1.0 0.2 0.1 0.7 0.6 0.2 1.0 1.0 0.4 0.3 2.8 0.1 (ton/yr) 7.8 7.8 7.2 1.6 1.4 1.2 2.0 2.8 0.4 1.5 1.5 7.2 0.9 0.4 1.3 4.5 1.0 0.4 3.03 2.8 1.0 4.3 4.3 1.9 1.2 12.2 0.4 0.5 2.2 0.5 2.2 VOC 5(lb/hr) 1.3 1.3 0.9 0.3 0.2 0.2 0.3 0.5 0.1 0.3 0.3 1.2 0.1 0.1 0.2 0.7 0.2 0.1 0.5 0.5 0.2 0.7 0.7 0.3 0.2 2.0 0.1 (ton/yr) 5.6 5.6 3.9 1.2 1.0 0.8 1.4 2.0 0.3 1.1 1.1 5.2 0.6 0.3 0.9 3.3 0.7 0.3 2.2 2.0 0.7 3.1 3.1 1.4 0.8 8.8 0.3 0.1 0.6 0.1 0.6 EPA Inspection Report - Page 217 of 1969 Table 106.A Allowable Emission Limits [return A106] Source ID 3,5MM Btu/hr SO2 5 (lb/hr) (ton/yr) 5(lb/hr) 2NOx (ton/yr) 5(lb/MM Btu) 5(lb/hr) CO (ton/yr) 5(lb/MM Btu LHV) 4PM (lb/hr) (ton/yr) VOC 5(lb/hr) (ton/yr) FCC Regenerator NA 27.9 61.0 35.0 101.9 N/A 121.9 106.8 25.0 109.5 - - FL-0400, North NA Plant Flare 0.2 0.5 0.2 0.8 N/A 1.0 4.3 0.0 0.0 0.2 0.7 FL-0401, South NA Plant Flare 0.1 0.1 <0.1 0.2 N/A 0.2 1.1 0.0 0.0 <0.1 0.2 FL-0402, FCC NA Flare 0.1 0.1 <0.1 0.2 N/A 0.2 1.1 0.0 0.0 <0.1 0.2 FL-0403, Alky NA Flare <0.1 <0.1 <0.1 <0.1 N/A <0.1 0.2 0.0 0.0 <0.1 <0.1 FL-0404, GOHT NA Flare 2.4 10.5 4.1 18.1 N/A 13.6 59.6 0.0 0.0 2.3 10.2 Subtotal 345.4 668.8 1156.2 196.0 70.2 Tanks, Table 106.E 322.4 Fugitives, Table 106.F 994.6 Misc Sources, Table 106.G 16.6 Cooling Towers, Table 106.H 2.5 9.0 56.2 Oil/Water Separators, Table 5.3 9.5 106.I 6SSM, Table 107 27.4 31.6 97.6 0.4 46.2 TOTAL 1 NA 372.8 700.4 N/A 1256.3 205.3 1 Totals are for information and are not enforceable conditions. 2 Nitrogen dioxide emissions include all oxides of nitrogen expressed as NO2 3 lbs-NOX/MMBtu of heat input, calculated as a 3-hour average, when firing natural gas at 3% stack oxygen at full design load without air preheat. 4 All Particulate Matter emitted is assumed to be of aerodynamic diameter 10 microns or less. 5 Hourly emission limits and lb/MM Btu limits are based on a hourly rolling 3-hour average. 6 Maximum allowable emissions during maintenance, startup, or shutdown (SSM) and malfunction activities. 1515.7 "-" indicates that in accordance with the application, emissions of this pollutant are not expected. "- -" indicates that the emissions are less than 1.0 pph or 1.0 tpy and emission limits are not required for this permit, unless it's for a control device. Unit 9851, the SCR exhaust has Ammonia Slip limit of 7 ppmv on a wet basis and 6.1 tpy (BACT). EPA Inspection Report - Page 218 of 1969 INTERNAL FLOATING ROOF STORAGE TANKS TABLE 106.B(1) VAPOR PRESSURE LIMITATIONS FOR REFINERY NONCOMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS (VOC) Tank No. T-0056 T-0106 T-0107 T-0108 T-0109 T-0111 T-0112 T-0011 T-0124 T-0012 T-0413 T-0415 T-0417 T-0439 Typical Liquid Stored Naphthas Distillates Gasolines Gasolines Gasolines Naphthas Naphthas Gasolines Gasolines Gasolines Distillates Gasolines Gasolines Crude Oil Most Volatile Category of Allowable Liquids to be Stored1 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 Max Vapor Pressure (psia) of Most Volatile Liquid at Max Temp. 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 1 Liquids in lower volatility categories may also be stored (i.e., tanks allowed to store high vapor pressure category liquids can also store moderate and low vapor pressure category liquids; tanks allowed to store moderate vapor pressure category liquids can also store low vapor pressure category liquids). 2 High Vapor Pressure Liquids include: Crude, Naphtha (raw or treated), Unleaded Gasolines (sub-grade, regular, premium, and other blends), Alkylate, Reformate, FCC Gasoline, Ethanol, Isomerate, Straight Run Gasoline, and other refinery feedstocks, intermediates, products, byproducts, and wastes having a max vapor pressure of 11 psia or less under actual storage conditions. EPA Inspection Report - Page 219 of 1969 EXTERNAL FLOATING ROOF STORAGE TANKS TABLE 106.B(2) VAPOR PRESSURE LIMITATIONS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS (VOC) - Tank No. Typical Stored Liquid Most Volatile Category of Allowable Liquids to be Stored1 Max Vapor Pressure (psia) of Most Volatile Liquid at Max Temp. T-0057 Naphthas High Vapor Pressure2 11.0 T-0078 Isomerates High Vapor Pressure2 11.0 T-0079 Isomerates High Vapor Pressure2 11.0 T-0117 Gasolines High Vapor Pressure2 11.0 T-0401 Gasolines High Vapor Pressure2 11.0 T-0402 Gasolines High Vapor Pressure2 11.0 T-0411 Gasolines High Vapor Pressure2 11.0 T-0412 Gasolines High Vapor Pressure2 11.0 T-0435 Crude Oil High Vapor Pressure2 11.0 T-0437 Crude Oil High Vapor Pressure2 11.0 T-0450 Naphthas High Vapor Pressure2 11.0 T-0802 Sour Water High Vapor Pressure2 11.0 T-0830 Slop High Vapor Pressure2 11.0 T-0834 Distillates Moderate Vapor Pressure3 1.5 T-0835 Distillates High Vapor Pressure2 11.0 T-1225 Naphthas High Vapor Pressure2 11.0 T-0737 Sour Water High Vapor Pressure2 11.0 TK-NEWETHANOL Ethanol High Vapor Pressure2 2.32 1 Liquids in lower volatility categories may also be stored (i.e., tanks allowed to store high vapor pressure category liquids can also store moderate and low vapor pressure category liquids; tanks allowed to store moderate vapor pressure category liquids can also store low vapor pressure category liquids). 2 High Vapor Pressure Liquids include: Crude, Naphtha (raw or treated), Unleaded Gasolines (sub-grade, regular, premium, and other blends), Alkylate, Reformate, FCC Gasoline, Ethanol, Isomerate, Straight Run Gasoline, and other refinery feedstocks, intermediates, products, byproducts, and wastes having a max vapor pressure of 11 psia or less under actual storage conditions. 3 Moderate Vapor Pressure Liquids include: Desulfurized Naphtha (Splitter Bottoms), Light Slop, and other refinery feedstocks, intermediates, products, byproducts, and wastes having a max vapor pressure of 1.5 psia or less under actual storage conditions. EPA Inspection Report - Page 220 of 1969 FIXED ROOF STORAGE TANKS TABLE 106.C VAPOR PRESSURE LIMITATIONS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS (VOCs) Tank No. T-0013 Typical Liquid Stored Slop Most Volatile Category of Allowable Liquids to be Stored1 Moderate Vapor Pressure3 Max Vapor Pressure (psia) of Most Volatile Liquid at Max Temp. 1.5 T-0040 Distillates Low Vapor Pressure4 0.5 T-0041 Distillates Low Vapor Pressure4 0.5 T-0110 Asphalt/Pitch Low Vapor Pressure4 0.5 T-0400 Gas Oils Low Vapor Pressure4 0.5 T-0404 Carbon Black Low Vapor Pressure4 0.5 Oil (CBO) T-0405 CBO Low Vapor Pressure4 0.5 T-0409 Gas Oils Low Vapor Pressure4 0.5 T-0410 Asphalt/Pitch Low Vapor Pressure4 0.5 T-0418 Distillates Low Vapor Pressure4 0.5 T-0419 Distillates Low Vapor Pressure4 0.5 T-0420 CBO Low Vapor Pressure4 0.5 T-0422 Distillates Low Vapor Pressure4 0.5 T-0423 Distillates Low Vapor Pressure4 0.5 T-0431 Distillates Low Vapor Pressure4 0.5 T-0432 Distillates Low Vapor Pressure4 0.5 T-0049 Slop Moderate Vapor Pressure3 1.5 T-0055 Distillates Low Vapor Pressure4 0.5 T-0058 Distillates Low Vapor Pressure4 0.5 T-0059 CBO Low Vapor Pressure4 0.5 T-0061 Distillates Low Vapor Pressure4 0.5 T-0063 CBO Low Vapor Pressure4 0.5 T-0065 CBO Low Vapor Pressure4 0.5 T-0075 CBO Low Vapor Pressure4 0.5 T-0433 Gas Oils Low Vapor Pressure4 0.5 T-0434 Distillates Low Vapor Pressure4 0.5 T-0438 Gas Oils Low Vapor Pressure4 0.5 T-0810 Slop Moderate Vapor Pressure3 1.5 T-0814 Asphalt/Pitch Low Vapor Pressure4 0.5 T-0815 Distillates Low Vapor Pressure4 0.5 T-0838 Distillates Low Vapor Pressure4 0.5 T-1227 Asphalt/Pitch Low Vapor Pressure4 0.5 T-0081 Asphalt/Pitch Low Vapor Pressure4 0.5 EPA Inspection Report - Page 221 of 1969 FIXED ROOF STORAGE TANKS TABLE 106.C VAPOR PRESSURE LIMITATIONS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS (VOCs) Tank No. Typical Liquid Stored Most Volatile Category of Allowable Liquids to be Stored1 Max Vapor Pressure (psia) of Most Volatile Liquid at Max Temp. T-0082 Asphalt/Pitch Low Vapor Pressure4 0.5 RW-4 Recovery Well High Vapor Pressure2 11.0 Hydrocarbons RW-5 Recovery Well High Vapor Pressure2 11.0 Hydrocarbons RW-6 Recovery Well High Vapor Pressure2 11.0 Hydrocarbons TK- Biodiesel Low Vapor Pressure4 0.022 NEWBIODIES EL 1 Liquids in lower volatility categories may also be stored (i.e., tanks allowed to store high vapor pressure category liquids can also store moderate and low vapor pressure category liquids; tanks allowed to store moderate vapor pressure category liquids can also store low vapor pressure category liquids). 2 High Vapor Pressure Liquids include: Crude, Naphtha (raw or treated), Unleaded Gasolines (sub-grade, regular, premium, and other blends), Alkylate, Reformate, FCC Gasoline, Ethanol, Isomerate, Straight Run Gasoline, and other refinery feedstocks, intermediates, products, byproducts, and wastes having a max vapor pressure of 11 psia or less under actual storage conditions. 3 Moderate Vapor Pressure Liquids include: Desulfurized Naphtha (Splitter Bottoms), Light Slop, and other refinery feedstocks, intermediates, products, byproducts, and wastes having a max vapor pressure of 1.5 psia or less under actual storage conditions. 4 Low Vapor Pressure Liquids include: Diesel (raw or finished), Kerosene (raw or finished), JP-8, CBO, LCO, Slurry, Heavy Slop, Cutback Asphalt, Cutter, VGO, AGO, and other refinery feedstocks, intermediates, products, byproducts, and wastes having a max vapor pressure less than 0.5 psia under actual storage conditions. EPA Inspection Report - Page 222 of 1969 TABLE 106.D - STORAGE TANK THROUGHPUT AND TEMPERATURE LIMITS Material Throughput (bbl/yr) Maximum Storage Temperature (F) Asphalt/Pitch 30,872,000 510 Carbon Black Oil (CBO) 1,291,610 250 Crude Oil 76,212,000 Ambient Distillate 55,076,590 310 Gas Oil 25,059,500 310 Gasoline (includes isomerates) 57,910,908 Ambient Naphtha 39,028,084 Ambient Slop 1,330,000 Ambient Sour Water 45,051 Ambient BioDiesel 949,000 Ambient Methanol 142,350 Ambient TABLE 106.E- STORAGE TANK VOC AND H2S EMISSION LIMITS1 (return to A203) Tank Type VOC Emission Rate (tpy) H2S Emission Rate (tpy) Fixed-Roof 238.6 0.0 Floating-Roof 83.8 1.47 Total Tanks 322.4 1.47 1 The permittee shall demonstrate compliance with the above throughputs and emission limits through the annual emissions inventory process. Specific tank data (e.g. temperature & throughputs) shall be monitored and recorded weekly by the permittee. EPA Inspection Report - Page 223 of 1969 Table 106.F, 1EMISSIONS LIMITS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS (VOC) FUGITIVE EMISSIONS FROM EQUIPMENT LEAKS Process Unit ID Number FUG-02-SP CRUDE FUG-10-FCC Description South Division Crude Unit FCC w/CVS Maximum Hourly VOC Emission Rate (lb/hr) 10.2 10.8 Average Annual VOC Emission Rate (tons/yr) 44.6 47.2 FUG-20-ISOM Powerformer/Penex Unit w/CVS 5.9 25.7 FUG-21-SP VACUUM Flasher/Vacuum Unit 3.2 13.9 FUG-05-KERO Kerosene HDS Unit 5.2 22.7 FUG-06-NHDU JP8 Hydrodesulfurization 7.1 30.9 FUG-18-LSR MEROX TRT Merox/Merichem Treating Units 3.5 15.3 FUG-35-SAT GAS Saturates Gas Plant 18.3 80.0 FUG-29-BLENDER/TK FARM Light Oil Tankage 6.8 29.6 FUG-ASPHALT STG Asphalt/Heavy Oil Storage 3.5 15.3 FUG-FUEL GAS Fuel Gas Distribution System 4.2 18.2 FUG-LPG LPG Storage System 21.6 94.4 FUG-41-PBC PBC Unit 3.4 14.7 FUG-70-CCR CCR Reformer (w/in battery limits) 23.4 102.3 FUG-13-NHDU Naphtha HDS Unit 10.2 44.6 FUG-43-S ALKY FUG-09-N ALKY South Alky Unit (W-76) North Alkylation Unit (New-Inside battery limits) 1.7 7.5 12.0 52.5 FUG-44-DIST-HDU FUG-45-DIST-HDU FUG-07-N AMINE FUG-SRU1/SRU2/TGTU FUG-07-SWS1 FUG-80-WWTP CVS FUG-33-DIST HDU FUG-08-TRUCK RK FUG-RLO-ASPHALT FUG-73-SP UTIL FUG-63-H2 PLANT-1 FUG-31-SRU3/TGTU3/TGI3 FUG-34-HYDROCRACKER FUG-25-ROSE-2 Gas Oil Hydrotreater (incl. CVS) Gas Oil Hydrotreater (incl. CVS) Amine Unit-Treating/Regen. SRU1/SRU2/SWS w/CVS Sour Water Stripper Oil/Water Separator Relocated Diesel HDS Unit w/CVS Loading Racks Asphalt/Pitch Loading Rack Utilities Hydrogen Plant SRU3 Unit WX Hydrocracker ROSE Unit 9.3 40.6 2.6 11.2 6.3 27.5 2.4 10.4 1.6 7.0 1.3 5.5 12.9 56.4 2.8 12.1 0.7 2.9 16.7 73.3 2.6 11.2 0.7 3.1 6.2 27.2 8.0 35.1 FUG-64-H2 PLANT-2 Hydrogen Plant 2.6 11.2 FUG-RRTOTRUCK Crude oil unloading system, closed loop system between railcars and trucks 0.1 0.5 Subtotal Facility VOC CAP 227.8 994.6 1 Minor changes within the facility to piping and components that affect fugitive VOC emission source shall be updated and added during the next available Significant permit revision in accordance with 20.2.72 NMAC. The facility wide fugitive VOC emission limit shown above and in Table 106.A of this permit. EPA Inspection Report - Page 224 of 1969 MISCELLANEOUS SOURCES Table 106.G EMISSION LIMITS FOR REFINERY NON-COMBUSTION SOURCES Of VOLATILE ORGANIC COMPOUNDS (VOCs) Loading Rack Loading Rack Description Material Loaded Hourly Annual Throughput Throughput VOC Emissions bbl/hr bbl/yr lb/hr ton/yr Gasoline 1214 1,600,696 4.25 2.80 TL-4a Fuels Truck Loading Rack Diesel 107100 3,650,000 1.72 1.72 Jet Fuel 35700 1,021,718 0.75 0.34 TOTAL VOC 6.73 4.86 Carbon Black Oil 30000 500,808 6.30 1.57 TL-7 CBO/LCO Truck Loading Rack Light Cycle Oil 38100 20,119 3.55 0.06 TOTAL VOC 6.30 1.63 Carbon Black Oil 30000 365,000 6.30 1.15 RLO-8 Railcar Loading & Off-Loading Rack Diesel Jet Fuel Asphalt 20000 1,144,000 0.32 0.54 20000 1,144,000 0.42 0.38 30000 2,628,000 0.01 0.03 TOTAL VOC 6.30 2.09 FUGODOR Odor Controlling Atomizer 1250 ml/hr 10950 liters 0.46 2.0 Note:1. Calculation method and factors per AP-42, Section 5.2, dated June 2008. a Controlled emission rate. The previous controlled rate was set by the terms of the consent agreement between Navajo Refining Co. and the Department executed January 28, 1994. The agreement required that the incinerator have a minimum 90% destruction efficiency for gasoline loading and a minimum 80% destruction efficiency for diesel fuel loading or Jet A fuel loading. This was achieved by a vapor combustor. This device has since been replaced with a carbon adsorption system compliant with MACT Subpart R, as subject per MACT Subpart CC. Emission limits changed in 195-M-17 to correspond to Title V permit values. EPA Inspection Report - Page 225 of 1969 COOLING TOWERS Table 106.H EMISSION LIMITS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUMDS and PM Source ID VOC VOC PM PM CO CO lb/hr tons/yr (lb/hr) (tons/yr) (lb/hr) (tons/yr) Y-0001 1.8 7.9 0.3 1.2 Y-0002 Y-0008a 1.8 7.9 6.5 28.3 0.3 1.2 0.7 2.9 0.58 2.54 Y-0011 1.3 5.5 0.5 2.3 Y-0012 0.4 1.8 0.2 0.8 CT TT-0006 1.1 4.7 0.2 0.7 Subtotal informational (for 12.8 purposes 56.1 2.1 9.1 only) a Y-0008 cooling tower provides 100% control of any NH3 emissions from V-H2 and V-H2-2. Unit 64, Hydrogen Plant has de-aerator line that has dissolved CO that is connected to the cooling tower. API OIL/WATER SEPARATORS Table 106.I EMISSION LIMITS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS (VOCs) Maximum Average Hourly VOC Annual VOC Equipment Emission Emission Emission ID Point ID Description Rate (lb/hr) Rate (tons/yr) Above Ground API Oil-Water Separators MAIN API D-0829/0830 and enclosed drain system. <0.1 <0.1 T-0896 DAF-0896 DAF Unit T-0896 <0.1 <0.1 T-0801 T-0801 Enhanced Biodegradation Tank T-0801 <0.1 <0.1 T-0836 T-0836 Enhanced Biodegradation Tank T-0836 0.1 0.5 T-0829 T-0829 Equalization Tank T-0829 5.1 8.9 T-0806 DAF-0806 DAF Unit T-0806 <0.1 <0.1 Subtotal (for informational purposes only) 5.3 9.4 EPA Inspection Report - Page 226 of 1969 Table 107.A MAINTENANCE STARTUP AND SHUTDOWN EMISSION LIMITS [return to A107] NOx CO VOC Unit Description of Emissions pph tpy pph tpy pph tpy SSM H-9851 Emissions during SCR downtime1 10.1 1.2 20.2 2.4 2.0 0.2 SSM T-0737 Emissions from roof landing -- -- -- -- 33.0 0.5 SSM Misc 1 Emissions from catalyst handling -- -- -- -- -- -- SSM SRU3-TGI Emissions from SRU3 startup and shutdown 6.5 <0.1 15.0 0.1 0.1 <0.1 Emissions from roof landing and tank SSM T-0078 refilling -- -- -- -- 177.0 2.7 Emissions from roof landing and tank SSM T-0079 refilling -- -- -- -- 306.0 4.6 SSM T-1225 Emissions from roof landing 187.0 2.8 SSM FL-HEPPORT Temporary, portable flare for natural gas pipeline maintenance 173.4 0.1 943.5 0.5 160.7 0.1 SSM SRU2-TGI Emissions from SRU2 startup and (H-0473) shutdown 6.5 0.1 27.7 0.2 0.2 0.1 Emissions from venting SSM activity gases to FL-400, FL-401,FL-402, FL- SSM Flare Cap 403, or FL-404. 162.9 18.3 1243.0 77.0 211.6 13.2 Flares Malf Cap Upset and Malfunction Emissions -- 10.0 -- 10.0 -- 10.0 Low-Emitting Maintenance Activities such as de-inventorying small equipment, clearing piping associated with emission units, and routine maintenance activities SSM Misc 2 such as heat exchanger repair. 17.0 1.9 127.1 7.8 21.2 1.4 SSM Tanks Misc Storage Tanks -- -- -- -- 112.0 10.6 TSP/PM10/PM2.5 pph tpy 2.8 0.3 -- -- 1.5 <0.1 -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- SO2 pph tpy 0.5 0.1 -- -- -- -- 159.0 0.4 -- -- -- -- 1.7 <0.1 159.0 0.4 1133. 4 14.9 -- 10.0 129.3 1.6 -- -- H2S pph tpy -- -- -- -- -- -- 6.5 <0.1 0.02 <0.1 6.6 0.1 0.4 0.1 -- -- 0.7 0.1-- 0.1 0.1 Subtotal SSM/M1 31.6 98.0 46.2 0.4 27.4 0.4 1 During startup, shutdown, schedule maintenance or malfunction of the SCR control system, BACT for H-9851 shall be ultra-low NOx burners emitting no more than 0.03 lb per MMBtu (LHV) on a hourly rolling 3-hour average basis at 3% excess oxygen. 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Mail/Return. ReceipJ 7018 0360 0001 7923 5958 Re: HollyFrontier Navajo Refining LLC Artesia, NM Refinery Title V Operating Permits P051-R2Ml Annua] Compliance Certification Agency Interest No. 198 Reporting Period September 1, 2018 through August 31, 2019 On behalf of HollyFrontier Navajo Refining LLC (Navajo), I am submitting Navajo's annual compliance certification (ACC) for the Artesia, NM Refinery. Title V Operating Permit P051-R2Ml Reporting Period: September 1, 2018 through August 31, 2019 Consistent with the initial compliance certification, items identified during work practices, such as fugitive component monitoring inspections, that are corrected or repaired within the regulatory timeframe and that are properly documented, do not comprise exceptions or deviations. Please feel free to contact me at (575) 746-5487 or Ray Smalts at (575) 746-5490 if you have any questions or should require any further information. Sincerely, Scott M. Denton Environmental Manager Enclosure cc: US EPA (w/enc): Chief, Air Permits, U.S. EPA Region 6 (6PD-R), 1201 Elm Street, Suite 500, Dallas, TX 75270-2102 Navajo: P. Miller, W. Romine, R Smalts, S. Hammond Environmental File: 2.10 Annual Compliance Certifications (Title V)\Artesia Certification\2019 Artesia Certification\2019-09- 30 Artesia. Title .v..Annual..Compliance. Certification..ndf .HollyFmntier Navajo Refining LLC 501 East Ma.in Artesia, NM 88210 (575) 748-331 l ht1r.iiwww.Jwlt;fr:2ntfa~I&9m HFNA-000005178 EPA Inspection Report - Page 718 of 1969 New l\1exico Environment Department Air Quality Bureau Compliance and Enforcement Section 525 Camino de los Marquez, Suite 1 Santa Fe, NJV[ 87505 Version 05.02.13 Phone (505) 476-4300 Fax (505) 476-4375 i NMED USE ONLY t TEMPO l'llilSE !\IOU: - Indicates required field REPORTING SUBMITTAL FORM ,.-....................N.MED.USE.ONLY............ ] Staff I ccccc-} ________!\f!mir:i. ,.......................................................... SECTION I - GENERAL COMPANY ANO FACILITY INFORMATION A. Company Name: D. Facility Name: HollyFrontier Navajo Refining LLC HollyFrontier Navajo Refining LLC B. 1 Company Address: PO Box 159 E. 1 Facility Address: 501 E.Main St. -------------------! .....................................- - - - - - 1 B.2 City: Artesia ssss"""""""""""' B.3 State: i B.4 Zip: : NM - 8 8 2 1 '1 - 0 '1 5 9 C.1 Company Environmental Contact: C.2 Title: Scott Denton Environmental Manager 1~C---.3""~P""h_o_n_e-"ON"'""u_m_b~e-r_:_ _ _ _ _-,--.,c"".~4 Fax Number:" !~e:~ity: .............. ~:~@sfute:1~~~~-z1i,: .. F.1 Facility Cont-ac_t_:- - - - - + . =Fcc.2~@"'""R-="Titie: ........................._............_. - Scott Denton F.3 Phone Number: Environmental Manager F.4 Fax Number: .........................._ 575-746-5487 c.5 Email Address: 575-746-5451 575-746-5487 F.5 Email Address: 575-746-5451 ----------------------- Scott.Denton@hollyfrontier.com Scott.Denton@hollyfrontier.com G. Resoonsible Official: /Title Vonlvl: H. Title: Vice President & Refinery L Phone Number: 0 , J. Fax Number: I Parrish R. Miller Manager, HollyFrontier Navajo 575-748-3311 1 575-746-5451 ._!~-"""'-------............................................... Refininq LLC 1 K. Al Number: [ L Title VP M. Title V Permit Issue Date: IN. NSR Permit Number: 198 P051-R2M1 01/22/2016 PSD-NM-0195-M37 :; ~~po~~~~1~;~;~d:-~- To: ...0...8.../..31/2019',11,..............................................,...........................................,[_................ I 0. NSR Permit Issue Date: 08/12/2016 0 A. [g1 s. D C. D D. D E. D F.0 G.0 NII -TYPE OF SUBMITIAl (check one that applies) ------r------ - ..- .................................-............. -----------------------------------~~~~~~~~~~~~~~ Title V Annual Compliance Permit Condition{s}: Description: Certification A109 Annual Compliance Certification Title V Semi-annual Monitoring Report IPermit Conditionls}: j i Descriotion: NSPS Requirement (40CFR60) MACT Requirement (40CFR63) NMAC Requirement {20.2.xx} or NESHAP Requirement (40CFR61} Permit or Notice of Intent (NO!) Requirement Requirement of an Enforcement Action Reaulation: I I I Reaulation: Sectionisl: Sectionlsl: i IReau!ation: !Section!sl: IIPermit No.O: or NOi No.D: Condition{s): I NOV No. D: ~r SFO Ni,,~~:]_ Section(s): orCONo.O.orOtherD. i Descriotion: Descriotion: Descriotion: Description: jDescription: SECTION IV- CERTIFICATION ------------------------------------------------------..------- After reasoabfuinquiry, I Parrish R. Miller ............................ certify that the information in this submittal is true, accurate and complete. /,,_/ / ................ (name of reporting official) ---- er-~""-"" n= =nnnn~ ..,.. ............. .. ~Jwiature of~p9-rtj,ig ~c\~;>_t' Title: Date 1 Responsible Official for Title V? ,, /._,,"''' / / ,.. ;-- / Vice President & Refinery ----,,, ;> /.,,___,./ ' ., >~ Manager, HollyFrontier 09/30/2019 [g1 Yes 0No _ _ _ _..,.__ _ _ _ _ _ ___._ _ __,,,_ __....__ _ _ _ _ _ _ _ _ _ _,...,__ _ _ _ _ _ _ _.......l! / ~--r ,. ,. .. ,.. ' ,,, Navao Refinin LLC Reviewed By: =------------ Date Reviewed: HFNA-000005179 EPA Inspection Report - Page 719 of 1969 Title V Report Certification Form 1111 Annual Compliance Certification o Semi-Annual l\1onitoring Report Facility Name: Artesia Refinery Facility Address: PO Box 159, Artesia State: NM ----------------------------------------~ Zip: 88211-0159 Responsible Official (RO): Parrish R. Miller RO Title: Vice President & Refinery Phone; 575-748-331 l Fax: 575-746-5421 ------------------------------- Manager, HollyFrontier Navajo Refining RO e-mail: _________ ________________ LLC ----------~----------------------------------------------------! ,,__P_ermit No.: P051-R2M1 ,__,, Date Permit Issued: 01/22/2016 Report Due Date (as required by the Permit Al number: 0198 permit):09/30/201_8_ _ _ _ _ _ _ _ _,____ _ _~ --------------------------------' Time period covered by this Report: From: I am the Responsible Official indicated above. I, :Parrish R. Miller, certify that I meet the requirements of 20.2.70.7.AD NMAC. I certify that, based on information and belief formed after reasonable inquiry, the statements and information contained in the attached Title V report are true, accurate, and complete. Signatur~e-- _L~"~ '---------------------------------------------------------------- HFNA-000005180 EPA Inspection Report - Page 720 of 1969 Title V Annual Compliance Certification for Permit P051-R2 & R2J\11 Title (TV) Permit Administration Amendment On January 22, 2016 NMED AQB issued an Administrative Amendment to Operating Permit PG52-R2. The Administrative Amendment PG51-R2Ml corrected the following: 'lhe Department ackrnrnvledges the 0'%TWr/PennHke rrnme change from Navajo Refh:dng Compan;\ LLC to EfoUyFnmtfor Navajo Rdmmg LLC For this is an Administrative Amendment (P0Sl-R2I\U}, the facility can use one Annual Compliance Certification (ACC) Form which will cover both TV Permits. Although the facility is only required to submit one ACC Form, the facility sha1I submit two (2) separate TV Report Certification Forms. Each form shall list the corresponding TV Permit number, TV Permit Issue Date and Reporting Period. Please note that this is a one-time authorization. Submittal forms for future Administrative Revisions win be evaluated on a case by case basis. This form can also be used for future submittal that cover only the PG51-R2l\U permit HFNA-000005181 EPA Inspection Report - Page 721 of 1969 Part 1 - Permit Requirements Certification Table 2. Method(s) or other int:i'mnation or other facts used to dctcnninc the compliance status: FACILITY REQUIREMENTS SPECIFIC AHH Permit Duration (expiration) :frequency of data coHectk,n used to dc-tc-nninc crnnpfomce? D Continuous 0 Intermittent 4. Was this fadity in compliance with this requirement during the reporting period? [Sl Yes 0No 5. Were there any deviations associated with this requirement during the rnporting rwriod? []Yes [Sl No A. The term of this pen11it is five (5) years. It -.,,vill expire five years from the date of issuance. Application for renewal of this permit is due twelve (l 2) months prior to the date of expiration, 202,70300.R2 and 302.B NMAC A101 Permit Duration (expiration) Navajo submitted the application for renewal on May 06, 2019. D Continuous [Sl Yes 0Yes B. If a renewal pen11it is not issued prior tZI Intermittent 0No to the expiration date, the pen11ittee may continue to operate beyond the expiration date, provided that a timely and complete Navajo submitted the application frir renewal on May 06, 2019. rene\val application is submitted no later than twelve (12) months prior to the , exniration date, (202. 70AOO.D NMAC) Al02 .Facility: Description D Couthmom, [gjycs E. This facility is located in the dtv limits I This is the location of Navajo refinery. \Xl Intermittent 0No of Artesia, NM, I A103 .Facility: Applicable Regulations This permit condition pro-v:ides a 1ist of the applicable requirements that arc addressed in detail in other permit conditions but does not impose any D Continuom, [Sl Intermittent 0Yes [gj No I "Tl A. The permittee shall comply with all specific standa.rds, monitoring, recordkceping, or z reporting requirements. Therefore, no further :r- applicable sections of the requirements 0 response is required. As :instructed by the AQB, 0 listed in Table 103.A 0 Navajo is completing the check box :responses in I 0 0 01 columns 3, 4, and 5 of this form. Navajo continues I ...... OJ N [ZI No 0Yes rgj No rgj Yes 0No EPA Inspection Report - Page 722 of 1969 Version 02.25.15 ! i. Pennit Condition # and Pem1it Condition: I ' 2. Method(s} or other infonnatio11 or other facts used to determine the compliMce status: to comply with all applicable requirements except for specific deviations as :noted elsewhere in this document. (See the specific responses to the permit conditions that contain standards, monitoring, recordkeeping, or reporting requirements for more information). 3. W11at is the frequency of data collection used to determine comnlianee? 4. Was this facility in 5. Werethereany complianc.e with this requirement during the deviations associated with this requirement reporting period? during the reporting u--........................ .. Q~od? ____ ,,,,, I Uu.-.-.-.-.-.-.-.- .-.-.-.-.-.- I "Tl z :r- 0 0 0 0 ACC Form Part l Permit# P051-R2 & R2Ml 0 01 Ver4.1 02/25/2015 ..... OJ (,) Page 3 of 144 EPA Inspection Report - Page 723 of 1969 Version 02.25.15 Table 103.A: Applicable Requirements I A i: 1,.i O Federally . U tN ippncau.1.e=.equ1--ren1ents-------------------------------------------------,---~nof rceat:>.~e m o. NSR Permit No: PSD 0195-M35 X ___________.......... '. ..EntireFacility_ 20.2. 1 NMAC General Provisions X Entire Facility 20.2.7 BM1!gEx~(;:S8EtEis~ions__ X ..JJii:i.Jjr~I~ntr Affected 20.2.33 NMAC Gas Burning Equipment -- Nitrogen Dioxide X sources in -- Table 103.E CCC 20.2.36 NMAC Petroleum Refinerv - Sulfur ~:~:!!=~=- L 20.2.71 NMAC Operating Permit Emission Fees [w.2:1:fNMAc:--construction:--rermiT------------- : X Entire Facility i~ X Entire Fadlitl'. x t~!!!i!~Y~<?i!~~Y.... ---, ) 20.2.73 NMAC Notice oflntent and Emissions Inventory : . : I Re.qmrements , . ~9-?:11~~J::fE~Y.~!!!}ggg{J~Q~~!Q~~~rt~~~~~?~ .............................................].... 20.2.77 NMAC New Source Perfonnance --- cuuuucu c -,u. ----------------------------------------------- ----------- c------------------------------ cc-------------------------------------------------- 20.2.78 NMAC Emission Standards for Hazardous Afr Pollutants X ,E . F .. : ntrre ac111ty i X ........ J~1~!t!~..!:~~-~~!Y-... . I Units subject to X I 40 CFR 60 X Units subject to 40 CFR 61 20.2.82 NMAC MACT Standards for Source Categories of HAPS 40 CFR 50 National. Ambient Air Standards J){ HnitR <mhiP-1"'.t to 4U Cl'K oJ 40 CFR 60, Subprut A, General Provisions X 40 CFR 60, Subpart Db "Standards of Pe1fonnance for [ndustrial- Commercial-Institutional Steam Units" 40 CFR 60, Subpart De "Standards of Performance for Small Industlial-Commercial-Institutional Steam Generating Units, \Vhich or Modification Commenced After June !989" 40 CFR 60, Subpart J, "Standards of Performance for Petroleum Refineries" 40 CFR 60, Subpart Ja, "Standards of Perfonnance for Petroleum I "Tl Refineries for which Construction, Reconstruction, or Modification z :r- Conunencecl.AfterJ\1ay..1A,..2007'' 0 0 0 0 ACC Form Part l Pennit # P051-R2 & R2Ml 0 .0..1.. Ver4.1 02/25/2015 OJ .i:,,. X X H-0464; H-310 l x................... LJfil.J1 to 103.J.........; See Tables I See Tables X 103.B to 103.J Page 4 of 144 EPA Inspection Report - Page 724 of 1969 Version 02.25.15 40 CFR 60, Subpart K, "Standards ofPerformance for Storage See Tables Vessels for Petroleum Liquids for Which Construction, Reconstruction, or Modification Commenced After June 11, 1973, X 103,B to 103,J and Prior to 1 1978" 40 CFR 60, Subpart Ka, "Standards of Performance for Storage See Tab!es Vessels for Petroleum Liquids for Which Construction, Reconstruction, or Modification Commenced After May 18, 1978, X 103.B to 103.k and Prior to Julv 23, 1984" . ....................................................................................... t 40 CFR 60, Subpart Kb, "Standards of Peiformance for Volatile + -----------t Sec Tables Organic Liquid Storage Vessels (Including Petroleum Liquid Storage X 103 .B to 103 .K Vessels) for \Vb.ich Construction, Reconstruction, or Modification Commenced After January 23, 1984" .... ~ ............ . 40 CFR 60, Subpart GGG, Standards of Perfom1ance for Equipment See Tables Leaks of VOC in Petroleum Refineries for which construction, X 103 .B to 103X reconslrnction, or modification commenced after January 4, 1983, and on or befr,re November 7, 2006. 40 CFR 60, Subpart GGGa, Standards of Perfonnance for Equipment See Tables Leaks of VOC in Petroleum Refineries for which construction, X 103,B to 103.K reconstruction, or modification.comn~~!1S:4 after }\J9ycmbcr 7,. 2006..... 40 CFR 60, Subpart QQQ, Standards of Performance for VOC . Emissions from Petroleum Refinerv \Vastewater Svstems X 1'4ociR..60;s~hp~~:r1ri;.s1~d;d/~r p;;fo.~-a-n-ce~e,_:'o-r-_S-t-at_fo_1_1a_r_y_ __;._i---~..--. See Tables _____ Lgi?.1?:.Press1g_1:1J_gQ1tton Internal Corn~:t.t-~.t.;2.i::i...;E.:.1.1.w.1:1:{;)~ ! 40 C.FR 61, Subp.art A General Provisions :'"""""""''"""'''''""""""""""""""" ................................ ------~------- _ _ _ _ _ _ _ __,_ X 103.B to 1 4~ CFR 61,. S?bp~rt FF, National Emission Standards for Benzene i :,:r~~:~:u::=~~mal~owers I VvasteOpe1at1on;:,; 1 -4b..CFR63, SubpaitA,General..Provisions J... 4~ CFR 63, Su~part Q, N~tionaI Emissirn: St~~dards for Hazardous T ........ f..... X 'I Benze1:e Waste Operations ; XX ___ ......J.E-;:tire..l<~ility-----1 X See Table I tf~~~ , to .. ..; 40 CFR 63 Subpart DDDDD . Sec Tables ' ......................- X .1;03-.B- ..t..o......1....0...3.......K.. 40 CFR 63 Subpart UUU, Petroleum Refrnerics: Catalytic Cracking I Units, Catalytic Reforming Units, and Sulfur Recovery Units "Tl z :r- 0 0 0 0 ACC Fonn Part 1 Permit# P05 l-R2 & R2M1 0 01 Ver4.l 02125/2015 ..... See Tables X 103,B to 103.KJ OJ 01 Page 5 of 144 EPA Inspection Report - Page 725 of 1969 Version 02.25.15 40 CFR 63, Subpart ZZZZ, National Emission Standards for I See Tables Hazardous Air Pollutants for Stationary Reciprocating Internal X 103.B to C o m b u s t i o n En0111es .-.-.-.-.-.-c.ssssssssssssssssssssssssssssssssss~ssss,,-.,Q:'.'..._._._._._._._._.__.._._._._._._._._,_,,,,,,,.,._,,,,, --- . - " " " " " " " " " " " " ' " i 103.KJ I .. 40_CFR_68,JRMl'),__Section__l_12(r)_AccidentalRelease____ ....... 1 X -1 Entire Facility ccci Consent Decree CIV-01 :!422LH Lodged 12/20/2001, Entered 3/5/2002 X.. Entire Facility cc=ccccccccccc.,ccc. ,-,-,-,-,-,-,-,-.-.-.-.-.-.-.-.-.-.-.-.-c.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.- 1 -.-.-.-.-c.ssss=--____________j ~------------------------------------------------""""'""--'"""' Table 103.R Smn:mary AppUcabiJ:ity-Fugitives Title V Permit Unit ID Dci::riptim, :W.231 MACT cc NSPS GGG NSPS GGGa NSPS i NESHAP NES1IAP NAV-195- QQ!.) J iv cc 1 FUG-02-SP CRUDE South Division Cmdc,J.Jnit ~i[S YES NO YES YES NO NO NO FUG-05-KERO Kerosene HDS Unit NO NO NO NO FUG-06-NHDU JP8 Hy<lrotle!iulfurization NO YES NO NO flJG-07-N AMINE A.mine Unit-Treating/Regen. Yf:S NO YES NO FUG-07-SWSl Sour Waler Stripper YES NO YES NO FUG-08-TRUCK RK Loading Racks NO YES NO YES FUG-09-N ALKY North Alkylation Ulli1 {Ne,v \made hmuy limits} YFS YES YES NO YES NO NO NO FUG-10-FCC FUG-13-NHDlJ FCCwiCVS Naphtha HDS l!nit -.;tt~s YES YES NO YES NO NO NO wu..n=-' ----- YES YES YES NO YES NO NO NO FUG-l 8-LSR l\1EROX TRT FUG-20-lSOM Merox/},,forichem Treating Units Powerfonner/Pmcx Unit w!CVS NO YES NO NO YES NO NO NO ------.---- ~-------- .\>,J(J YES NO NO YES NO NO NO FUG-21-SF VACUUM FUG 0 25-ROSE-2 FARM FUG-31-SRU3/TGTU3/TGI3 fUG-33-DIST HDU FlJG-34-HYDROCRACKER Flasher/Vacuum Unit ROSE Unit Light Oil Tanbge SRV3 Unit Relocated Die!iel HOS Unit w/CVS WX Hydmcrn.cb::-r NO NO NO '(ES YES NO NO ................ ...... YES YES NO YES YES NO NO --------=- ---------~ ........... ________ NO YES NO YES YES NO NO ,._ - .......... _______ -- YES YES NO YES YES NO NO -------n......w}ssss-' YES YES YES NO YES NO cccc=u-- \TS YES NO YES YES NO FUG-35-SAT GAS Saturates Gas Plant NO YES NO NO NO I I Fl!G-41-PBC l'BC t!nit NO "Tl FUG-43-S ALKY South Alky Unit (W-76; z :r- I HJG-44-D!ST-HDU Gm, Oil Hydrotri;ater (incL CVS) 0 0 Ln~-l~------ 0 0 ACC Form Part 1 Permit# P051-R2 & R2Jv11 0 01 Ver 4.1 02125/2015 ...... OJ 0) NO NO NO NO NO NO YES NO NO NO Page 6 of 144 EPA Inspection Report - Page 726 of 1969 Version 02.25.15 FUG,45-DIST0 HDU Gas Oil Hydminwter (ind CVS) FUG-63-H2 PLANT-! Hydrogen Plant NO NO YES YES NO NO NO NO YES YES ,,..-,~uu,-- 1-.JO NNNuu.-.-.~-.-.-.- NO NO NO NO NO FUG-64-H2 PL"'1"JT-2 FUG-70-CCR FUG-73SP UTIL Hydmgen Plant CCR Reformer (wiin battery lin:lits) Utilities NO NO NO NO YES NO NO NO YES : ''"""""" \TS YES NO YES NO NO NO NO : NO NO NO YES NO NO NO FUG-80-WWTP CVS OiliWater Separntor \'ES YES YES NO YES NO NO YES PUG-ASPHALT STG Asphalt/Heavy Oil Storage NO NO NO NO YES NO NO NO ! FUG-FUEL GAS Fuel Gas Distribution Sysiem NO YES NO NO YES NO NO NO I FUG-LPG LPG Stornge System NO NO NO NO YES NO NO YES FUG-RLO-ASPHALT AsphaltiPitch Loading Rack NO NO NO NO YES NO NO NO FUG-SRUliSRU2!TGTU SRU!/SRU2iSWS w/CVS YES NO YES NO YES NO NO YES FUG-RRTOTRUCK Crude oil "-~-~'-;:: system, dosed loop system NO NO NO NO YES NO NO NO I "Tl z :r- 0 0 0 0 ACC Form Part 1 Permit# P051-R2 & R2M1 0 01 Ver 4. 1 02/25/2015 ...... OJ -..,J Page 7 of144 EPA Inspection Report - Page 727 of 1969 Version 02.25,15 Table 103.C, Summary Applicability-Tmks . ' ' . MACT ,.~,----------- ------ NSPS NS.PS NSPS CC MACT CC NESHAP NSPS 2(t2,37,205 W.23lt1G9 20-:U&JW 20238-112 20,23U13 .. - ...... ,,. K Ka Kb RWA NO NO NO RW-5 RW-6 NO NO NO NO NO NO T-0001 NO NO NO T-000? NO NO NO fJt.,,all.<: NO NO NO NO NO Warmcrnm:, NIA N/A NIA YES \'ES FF NIA N/A NIA YES YES QQQ NIA NIA NIA NO NO NMAC" NO NO NO NO NO NMAC ,., .......,,N....O NO --- NO .NMA.C .....Y.....E....S................,..... YES I - ., - NO fiTh"f~C N~Ji\~ JG/\fyfj NO YES NO . 1 .,7--< NO NO NO NO )'ES NO 1---- -------~-: NO - No..........L No~ NO . NO . T-0003 NO NO NO NO YES YES NO NO NO NO i NO i T-0004 NO NO NO NO YES NO NO NO NO NO NO NO . NO . T-OOU NO NO NO \'ES N/A NIA NIA YES YES YES NO NO NO T-0012 NO NO NO !-- T-0013 NO NO NO YES YES NIA NI A NIA rLS YES YES NO NIA YES YES NO NO NO NO NO NO NO NO T-0026 NO NO NO NO NIA N/A NIA NO NO NO NO NO NO } T-0023 NO NO NO NO N/A NIA NIA NO NO NO NO NO NO N0 NO NO NO NIA N/iAi\ N/A NO NO NO NO NO NO NO NO ------:-- NO -""" _........Y.....E.._S,, N/A. NIA NIA NO NO NO NO NO NO NO NO NO YES N/IA N/A NIA NO NO NO NO NO NO NO NO NO NO -- N/A NI A NI A YES YES YES YES YES NO NO . NO i NO I NO i NIA I NIA N/A YES NO NO YES NO NO T-0046 NO NO NO NO NIA N I A .. nun~ NIA YES NO NO YES NO NO N-O- :i NO NO YES NIA YES YES NO NO NO NO NO NO NO NO NO YES NIA N/A NIA YES NO NO YES NO NO NO NO NO YES NI A NI A NIA YES YES YES NO NO NO T-0057 NO YES NO YES NIA NIA NIA YES \'ES YES YES YES NO T-0059 NO NO NO YES N/A N/A NIA NO NO NO NO NO NO T-0061 NO NO NO YES NIA NIA NIA NO NO NO NO NO NO NO NO YES NIA NIA N/A NO NO NO NO NO NO T-0064 NO NO NO NO NIA NIA NIA NO NO NO NO NO NO T-0065 NO NO YES YES NIA NIA NIA YES NO NO YES NO NO T-0071 NO NO NO NO NiA , NIA NIA YES NO NO YES NO NO T-0072 NO NO NO NO NIA NIA NiA YES NO NO YES NO NO T-0073 NO NO NO NO NIA NIA N/A YES NO NO YES NO NO T-0074 NO NO NO NO NIA NIA NiA YES NO NO YES NO NO I T-0075 NO NO YES vEs NIA NIA NIA YES NO NO YES NO NO T-0076 NO NO NO NO NIA N/A NIA \'ES NO NO YES NO NO T-0078 NO NO YES \13S NIA NIA NIA YES YES YES YES YES NO T-0079 NO NO YES YES NII, NIA NIA r13S YES YES YES YES NO I T-0081 NO NO YES rTS "Tl NO YES YES z :r- T-0106 NO i NO NO YES 0 0 0 0 ACC Form Part 1 Permit# P051-R2 & R2.\iil 0 01 Ver4.l 02125/2015 ..... OJ OJ NIA NIA NIA YES NO NO YES NO NO NI A NIA NIA. YES NO NO YES NO NO NIA NIA NIA YES YES YES NO NO NO Page 8 of 144 EPA Inspection Report - Page 728 of 1969 Version 02.25J5 11 T-0107 I NO NO [ NO i YES NIA ! NiA It.....IJJit=J ~g :g ~l ~~ ......1................~;t... 1~;t ,L...~f.:tHi~ I ~g ~g ~ l YES NIA ::r~~ . NiA YES 1~;xi {~ + ;;_~ L :~~~ J~Q+ ~~ L,,,,, __X.1:l___-rs?.............L NO I ~g +t]~..i ~~.. r~~~ -----~g--- . ~- ! NO i ~.~....l 1" :g : N + .N.....I..A................ NIA N; NIA T-0405 T-0409 T-0410 T-0411 NIA NIA 'A NIA .N.....O. c.........f....NOc...... + NO NO NO NO I NO ................,...,. +-- NIA NIA N/A NO NO ~~ ~~ i! ~~ t~. .::.....t.~+i~ _ijg NIA NI A J NIA l NiA NIA N/A l NIA I I NIA NIA ! NIA I NNIIAA NiA l NIA YES YES YES YES N, NQ....... NO NO YES ! \'ES -~~or NO 1 l NO l .t'./Q .L..........~E2 YES 1.....<~.~.:.I.~..:.. , ..... NQ NO NO YES ! YES . YES NO I j )7??.... J NO [j~.Q:::J 1 l ~9..........._?Jo .........::t::::~B.] 1 NO NO . NO l . NO NO i NO NO NO NO T-0412 NO NO NO YES T-0413 NO NO NO YES T-0415 NO NO NO YES I l 'f..0417 NO NO NO YES T-0418.....J NQ YES T-0419 . NO YES T-0420 NO NO YES . NO NO YES N/A NiA NIA N/A N/A N/A NiA NIA N/A NIA NiA YES N/A YES NO NIA NO N/A N/A NO N/A NIA YES 1'ES YES NO NO NO YES ......................... YES NO .......................... YES NO YES I NO NO I NO NO n~"""-'""'" NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO T-0423 NO NO \'ES T-0431 NO . NO l NO YES T-0432 NO , NO l NO YES NO NO NO NO NO T-0433 NO NO ' NO YES NO -T------0---4---3..-4---- NO T-0435 NO NO NO YES YES T-0437 YES NO NO YES T-0438 NO NO NO YES NIA T-0439 NO YES i NO J... L T-0446 I NO NO j NO T-0447 .....i...... No .. NO ,,No I , T-0448 I NO i NO j '' NQ N/A NIA N/A NIA NIA NO NIA NIA NO NO NO NO NO NO NO NO NO NO NO NO NIA NIA NIA NO NO NO NO NO NO i t51~6 +~b I :g l ~ 11 I YES NIA N/A N/A YES YES YES YES YES NO 0 0 8 ACC Fonn Part 1 Permit# P051-R2 & R.2M l ~ Ver 4.1 02/25/2015 ...... Page 9 of 144 OJ (!) EPA Inspection Report - Page 729 of 1969 Version 0225.15 J r=::::r~_iE~21N'.9J=J~oJ:No1 ~ . ~;~ t ~~~ -BlA_____..J....... ~~ ~------- i T-0465 i NO NO I NO NO !i N/A j NIA NIA . NO I NO I 8:fflil~ , ~~ filg=~~ 1 ::'.! ::'.! L ~g C11~; i T-0468 i NO NO I NO NO . N/A NIA NIA ' NO i NO i l I~Q(SQQ j t!Q ;tiQ LNO NO t!!A-.........,.~---- N(~--- . NIA -----,--~ NQ L. NO I T-0737 i NO NO I YES YES NIA i NIA NIA . YES ! NO til~r:::F::~. -~g--]::::Wlr :::::::::Fi:::~::=_:;___ --fit-----------4~1--- ----~t-------1 YE~____::::::l NO ------~g---------...::-::.~:::::::~~~-~g--------l..............~g..............l......~~::::::1-l NO NO ! NO NO .. ~ -~ i ~ NO NO NO NO NO NO___ + _NO NO YES YES YES NO t~ t~-----=:::i11}--==-te: I i T-0835 NO r NO NO 1 '{ES NIA -t-- NIA t NIA YES YES YES : No NO L..:LQ.ill..J~C:illi:+.-2'.]]l;._l_:J'li.A LNiA NLA ........... Yll.~ NO -;--No a - NQ_ L N() . T-0839 ! NO i NO i NO I NO i N/A I N/A N/A . NO . NO NO i NO ! NO , NO !'<OJ NO i ~i1;gJ ;gt.-E~=r~~it+_j_~=1f-~i[i~f1 ~gJ NO i N/A ------------------------------- 1 NI A NIA NO ' NO NO i NO I NO . NO NIA ., NO. NO=~ INO : N<) ...T>10 : NO NO NO \ NO NO ! NO -----~e:::::::r::::-------~r---- -----tg. r ~g n-~-~@ ::j YES YES YES I YES YES NO i N/A YES _____________ .::::f.{.o. ... -- NO---;- YES NO NQj NIA NO NO NO NO NO NO ! NIA NIA NO NO NO . .. NO ---- NO r NOi . I "Tl z :r- 0 0 0 0 ACC Form Part l Penn.it# P051-R2 & R2Ml 0 01 Ver4.1 02/25/2015 ..... (!) 0 Page 10 of 144 EPA Inspection Report - Page 730 of 1969 Version 02.25.15 T a b l e 103.D S u m m a r v ArmUcabmtv -'--~---r..r. ............................~::... u~~ Loading~ Rack - TL-4 i Fuels Tmck ii>i [ CBO/Lc6i\11ckL~~dhiiRack RL0-8 Railcar Loading &cQff-1,oadin_g Rack .......................................................... J cc~ MACT I YES -" I NO NO ------------------------............... - - -........................... . NO L NO 20.2.37,~~?~t:; MACT BBBBBB f """ NO NO NO L NO i crg::i~ctc"" NO NO - "" NQ-- :::: . )~'.<:?.... NO NO Table 103.E, Summary Applicability - li~_aters and Boilers Unitm Description B-0007 B-0008 B-0009 H-0009 H-0011 H-0018 H-0019 H-0020 Boiler 7 Boiler 8 Boiler 9 Unit 13 Naphtha Splitter Reboiler Unit 21 Vacuum Unit Heater Unit 06 HDS Reboiler South Crude Charge Heater South Crude Charge Heater H-0028 I Unit 21 Heater H-28 H-0030 Unit 06 Charge Heater H-0040 Unit 13 Charge He ,--~ ---- H-0303 Unit 05 Charge Heater H-0312 I Unit 10 FCC Feed Heater H-0352 Unit 70 CCR Refonner Heater H-0353 Unit 70 CCR Reformer Heater H-0354 Unit 70 CCR Reformer Heater H-0355 Unit 70 Stabilizer Reboiler Heater NSPS D NO NO NO NO NO NO NO NO NO NO NO NO NO NO NSPS Db YES YES YES NO NO NO NO NSPS De NO NO NO NO NO NO NO NSPS J I NSPS Ja YES I NO YES I NO NO I Yes YES I NO YES NO YES NO YES NO MACT DDDDD 'Y 1.x, YES YES YES YES YES YES 20.2.33.108 NMAC YES YES YES NO NO NO NO 20.2.36 NMAC YES YES YES YES 20.2.37 NMAC YES YES YES YES YES YES YES YES YES YES CAM NO NO NO NO NO NO NO NO NO 'f"ES NO YES NO YES YH:S NO ~6 +~6 :6 :6 NO I NO YES I NO YES I NO YES YES I NO ,._X!l~t:g+~~ ........j.............. ..,........ I ~1 :.............................._J_ -~-~- NO NO YES NO I YES YES NO NO I No : YES............ No +- YES ; NO 1 YES I YES I NO NO I NO YES NO YES NO YES YES I NO NO I NO YES NO YES NO YES YES I NO NO NO YES NO YES NO ! NO NO YES NO YES NO YES YES NO YES YES NO H-0362 Unit 70 CCR Heater NO NO NO YES NO YES I "Tl ........................f..... ;-l- ............,... .. ..........,....-t,... z H-0363 Unit 70 CCR Heater NO NO NO I YES I NO :r- 0 0 0 0 ACC Forni Part 1 Perm.it# P051-R2 & R2Ml 0 01 Ver 4J 02/25/2015 ...... (!) ...... NO ...................+.. NO YES YES YES YES NO .-,,,,,. ..... , NO Page 11 of 144 EPA Inspection Report - Page 731 of 1969 Version 02.25.15 H-0364 Unit 70 CCR Heater NO NO NO YES H-0421 Unit 44 Charge Heater NO NO NO YES H-0464 H-0473 .H-0600 H~060! SRU Hot Oil Heater NO NO SRUl and SRU2 Tail Gas Incinerator NO NO Unii 09 Deprnpanizer NO Reboikr Heater Unit 33 Charge Heater NO NO YES NO YES "i:'ES NO YES H-2421 Unit 45 Charge Heater NO NO NO "'[ES H-8801/ H-8802 Unit 63 Hydrogen Plant NO NO NO YES Reformer H-3402 Unit 34 Hydrocrn.cker Reboiler 1 NO NO NO NO H-3403 Hydrocracker Reactor NO NO NO NO Charge Heater H-9851 Unit 64 Hydrogen Plant NO NO NO NO Reformer H-2501 Unii 25 ROSE@ Unit No.2 Hot Oil Heater NO YES NO NO H-3101 (formerly SRU3- SRU3 Hot Oil Heater NO NO NO NO HOH) I SRU3-TGI SRU3 Tail Gas Incinerator NO NO NO NO NO NO NO NO NO NO NO NO YES YES YES YES YES YES YES YES NO NO YES YES YES YES YES ' YES YES NO NO NO NO NO NO NO NO YES NO NO YES YES NO NO YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES '1 NO NO I NO NO NO NO NO NO NO NO NO YES NO YES NO I "Tl z :r- 0 0 0 0 ACC Fonn Part 1 Permit# P05 l-R2 & R2Ml 0 01 Ver4.l 02/25/2015 ...... (!) N Page 12 of 144 EPA Inspection Report - Page 732 of 1969 Version 02.25,15 .......... ~................ , ................................. - - - - - - - - - - - - - - - - - - - - ,..--------------------------------- Table~~3.F, Su:ry Appli:::lin~T:~rs M~CTQ ~A_q~L_~CA~L.. ! 1 TCC Cooling Tower : YES YES NO . i Y-0002 j S. Alky Cooling Tower (Marley 1 YES """ - ygft NO l(,.__._._._.._ ~-- i Cooline Tower) "" f - ---~----~ Y-0008 i North Alky Cooling Tower f...... YES Y-0012 l H;~!:an~:~~;:wer -+=~ I CT TT-0006 Unit 07 Amine W-0745 Cooling Tower NO cccccccc.-.-.j.-.-,.-.-.-.-.-.-.- YES NO -~~ l:---1 ccccccccc.-.-.-.-.-.-.-.-.-.-.-.- i- -~ L i '"""""''~"""'-"'"- NO .. NO ..................... ..---------------------------------------------! l Table 103.G, Smnm~t..Y...~.!!~.?~ill!I=~~~!~~?ter i Emission Point MACT CC 1.....Efr;~e~~---o~(i"g~;ci"g30.................W.~~ri~t.~~ ------ DAF-0896 . DAJ,'-0896 YES + N,~~ F'F . YES ............, ...... .----------- NSP~E~~------ ..... NO C~i NO DAF-0806 DAF-0806 YES YES NO NO T-0801 YES YES NO NO T-0805 YES YES NO NO T-0829 T-0836 T-0897 l YES YES NO NO YES YES NO NO \ YES YES NO NO ............................................ -,-------------------------------,- l~~T Table 103.H, Summaryv Applicability - FCC-CCR ' . Unit ID ! FCCREGEN N SPS J YES NS~Ja I ccR NIA \-NIA 1 YEs .......... . I CAM ' ' .YES--, Satisfied by MACTUUU NIA NO I "Tl z :r- 0 0 0 0 ACC Fom1 Part l Permit # P051-R2 & R2M l 0 01 Ver4.1 02/25/2015 ..... (!) (,) Page 13 ofl 44 EPA Inspection Report - Page 733 of 1969 Version 02,25, 15 Table Sou:rcc ID SR!Jl SRU2 SRU3 -SRU Enlission Point ID H~0473 H-0473 SRU3-TGI NP NSPS MACT Gas lndncrator SRUl and SRU2 Tail YES NO Gas Incinerator SRU3 Tail Gas Incinerator NO YES YES YES ccccccccccccccc 20.2.36.113.A(l){d) & YES YES YES CA.'vl YES~Satisfied byMACTUUU YES NO YES-Satisfied byMACTUUU YES NO byMACTUUU Tabfo 103.J, Summary A UcaMlity - Engines. 20.2.61.109 20.2JH.114 L ~~11rce ID _J E-0600W DesctIPJi.~I.!-...........................! ......~.?.~UH NJMAC NMAC CATV[ Fire Wat~t?:i:11:1:?P?!::gine ! YES YES ..............-.........................- ..-,...------c.c.c....c.;,......._ _----i NO E-0601TVI Fire Water Pump Engine + E-0602E Fire \Vater Pump Engine Y~ I YES TIS YES YES YES E~0603 Fire \Vater Pump Engine YES YES E~0901 Fire \Vater Pump Engine YES YES YES YES I YES YES ' NO G-0100 UPS backup generator NO YES YES '{ES NO G-0101 E-8010 UPS back-up generator Portable Air Portable Air -r :-;;nr r- -1,r Portable Air Compressor \%/WT? Emergency Engine ( NO YES YES YES YES YES YES YES YES YES YES YES NO YES YES NO YES YES NO YES YES NO YES YES NO I "Tl z :r- 0 0 0 0 ACC form Part 1 Permit# P051-R2 & R2M1 0 01 Ver4,1 02/25/2015 ...... (!) .i:,,. Page 14 of 144 EPA Inspection Report - Page 734 of 1969 Version 02.25.15 -------------------------------------------- . Tabl2 !9~~~ ~0111rnary Applicahility.-FLARES, ---------------- . , ! l N.ESHAP I 1 ......................,,................--................________ --------~ . 20,236,113b 1{L2,J7,201B . Ni:~~1rfa;e ~iti lI!~I1J,,,,+---~~fl N~~~c N~~~c FIA02 1 6 I FCCU flare YES 11""''''''''''''''N1r-~---~!v~I A NO i YES .. : YES NO YES NO YES YES YES i -! i \ES -YES j 7 : T i I j ....................... ~................................................ I I YES YES . i I I FIA03 A1ky Flare YES NO YES NO YES YES ; YES YES j FL-404 GOHT Flare YES NO \'ES NO "l'FS YES YES YES : ~ - - ~ - - - - - - - ~ - - - ~ - - - - - - < - - - - - - - - - " - " ' " " "_ _,C_ _ _ _~ - - - - - ' - - - - c c ~ c c c c c c c c c c c c c . ~ - - - - - All fiares are steam assisted. . State ofNew Mexico requires that an exit gas velocity of65 ft/sec for modeling._ --=---------- ....................... . ........... The heatinz value o f the gas for all flares i s < 1000 B T U ! s c f : ....._._................._._._...... '7.: .. ___ .........................................................................................................................................................................................................................................................................................................~---------------~------- ------------------------------ -----------"""""""""""""'~"""-""""'"" .... --------------------; ---------- .--------- ----------' .-----------------' .- ----------------------7: _-----~ --~- -- -,.---------_, ---------------------------------- --1"""""-""""""""""""'" 1 This perrmt cond1t10n prov Ide:-; a 11::,t ot the D Continuous 1 . , ,, , , I applicable requirements that are addressed in detail i A103 Facility: Applicable Regulatmm I in other permit conditions but does not impose any ! ~ Intermittent I , _. I specific standards, monitoring, record.keeping, or 1 M. Complrnnce w1th the tenns and I reporting requirements, Therefore, no further conditions ofthis permit regarding source I response is required_ As instructed by the AQB, 1\7! ~,,,,, ~ x~~ [JNo 0Yes ~No emissions and operation demonstrate Navajo is completing the check box responses in compliance with national ambient air columns 3, 4, an<l 5 of this form, Navajo continues quality standards specified at 40 CFR 50, to comply with all applicable requirements except which were applicable at the time air for specific deviations as noted elsewhere in this dispersion modeling was perfonned for docm:nent ~~ee the specific_ responses to the the fadlitv's NSR Permit 0195-M35. pernut cond1t10ns that con.tam standards, monitoring, recordkeeping, or reporting A104 Facility: Regulated Sources re uirements fi:ir more information). This permit condition provides a list but does not impose any standards, monitoring, recordkeeping, or reporting requirements, Therefore, no further D Cou;hl~o~~ ---r-r;gj-Yes --------------------- ' ~ fote:rmittent I [J No l"o Yes I [8J No response is required_ As instructed by the AQB, A. Table 104,A lists the emission units Navajo is completing the check box responses in authorized for this facility, Emission units columns 3, 4, and 5 ofthis fom1. Navajo continues identified as insignificant or trivial to comply with aH applicable requirements except activities (as defined in 202,70,7 NMAC) for specific deviations as noted elsewhere in this and/or equipment not regulated pursuant document. (See the specific responses to the I to the Act are not included, "Tl z :r- 0 0 0 0 ACC Fonn Part l Permit# P05 J-R2 & R2M! 0 01 Ver4.1 02/25i2015 ..... (!) 01 permit conditions that contain standards, monitoring, rccordkeeping, or reporting reqt1ir~J:J:1~11t;:;fcit more information), Page 15 of 144 EPA Inspection Report - Page 735 of 1969 Version 02.25.15 I "Tl z :r- 0 0 0 0 ACC form Part 1 Permit# P05 l-R2 & R2Ml 0 .0...1.. Ver4.l 02/25/2015 (!) 0) Page 16 of 144 EPA Inspection Report - Page 736 of 1969 Version 02.25.15 Table 104,A: Regulated Sources List -; Unit No, 8-0007 8-0008 s=oooe Unit 'fype t Boiler 7 tfoiier ii Boiler 8 ccccccccccccccccccccccccccccccccccccc E-8010 E-0600W E-060iM E-0602E VW!TP Diesel.Pump _Engine-- " ~' . hrn \,ater Pump Engmc Fin: Water Pump Engine .............................! hre_w:1:=::~~~~~:i~~ i~i:c~i~i~it!J l~i~_:;~ f~ -------------.~------=~------ ....,...... lvfanufacturer 1\:fodei No. 1\1.anufacture Capacity ....................... + .....................Date ---- ------~- 0:~:........ --------- 001 -------------i:::if --------1!l~~ii!~ifHt~ti::i --------------------------------------- ~~~t:Of~~1~_;_;--::::::=::J~--- -------- John Deere . ., Clarke Dwsd {John Deere} Clarke Diesel (John Decrc) J J Clarke Diesel (John Deere) JW6H-UFAD70! RG6090Lll354!l ~6!~;~~1;~J~; J~~~~?~rl~~~---------- _________ I 7i2012 ii2oii 7/~~:-~. J.299.DP__..................... :::::::.....:::.::: 1 ' 376 11 l -------------- 375 hg---------- -, ---------------------T 376 llp 11=-oso3 E-090'1 ~'=V-0546 H-0009 H-OOi 1 H-0018 Fire Water Pump Engine Fire Water Pump Engine ~~~~:-~ Unit 13 Naphtha Splitter Reboiler Unit 2i Vacuum Flasher Heater ...N~rFiE/iE2~tBfa2Hr. :::::::::::::::........ ~1~==&f~k~n1t~~-- -~ ClarkeDiesel(JohnDeere) JlT6H-lffADX8/ ,,,,,,,,,,..,,,---------+-_PE6068Ll23486.-------- Clarke Diesel (John Deere) JX6H-U.F3()' RG6t25A016l Hl . 2012 i0/2007 305 hp 1 ,,......J -..... -----! 430 ho ! . ! Zeeco burners GSFW-12 burners I Unknown ""'""""""'""'''"''''''"''' ) Unknown ! 2'.Q<:o<;;i:J_Qll_rr1ers -------------------------- ....C9.F.0Tssurners Callidus Technologies, LLC i Unknown 44 MMStufhr ilHV Basisl rGnknown----------------------r:fa ivii;;istuihr (LHV Basis) Unknown ,,...,,..______ }?}'!1~~\~)FiibtiYJ?~~ !H-0019__ .................................................! .South Crude _Chale Heater burners i CUBL-8\/v burners Callidus Technologies, LLC) New burners in 2005 54 MMBtu/hr ilHV Basis\ i ,, ,,,,,,,,,,...--------------:----------------------.. ' - - - - - - ~ H-0020 . So_y_!h..9L\!.9.tt..:.D.!.?J:!.?ittr. . ... . .. burners L9YPk1~1{;/~l!E1Ii....---- __Jj'J_lW burri_e._r;s.__i1~)991,'L,,,,....JJ8 iv1MBtu/hr {LHV Ba.ti}} 1 1 Callidus Technologies, LLC ! (IJ.:.Q2.____ : r!H--0-36"2----------------------- t Unit 70 Stabilizer Reboiler Heater H-355 ______J._ill~"'viouslv 70H:L___________-------------..--.. ..../ ..)9.hn...Pnk burners .. i Unit 70 CCR Heater --r----------------------------------""""" ' Callidus burners .. i Callidus Technoiogias, Technologies, Unkno~Y[L.. LLC . u):"T! 'Q''''U''''B'''LBVV burners 1'1~............................ ....._-_1_1__MMB!ll{lr.J~r.-1Y.__8asis} rI New burn,,,e,,.r..s.....i.n....2...0...06 ---4-0---M---M-""B"'tu/hr iLHV Basis) glf;~;~: ____ I IH-0363 "Tl ' Unit 70 CCR Heater I burners CUBL-8W burners ! New burners in 2006 50 MMStu/hr ilHV Basisl z ld:9364 .Unit.70.CCR.H::~:;---------- ........................ .] Technologies, LLC _l .~~~-~~~-:,,:~rners ................. ..... . , .......................,.... :r- ~HVBasisJ 0 H-042'1 0 Unit 44 Charge Heater (previouslyl-l-21) ; John Zink burners : LNC-PC-18 burners 1981' LHV Basis) 0 0 ACC Form Part l Permit# P051-R2 & R2Ml Page J7 of 144 0 01 Ver4,l 02/25/2015 ...... (!) -..,J EPA Inspection Report - Page 737 of 1969 Version 0225-15 H-0464 H-0600 H-0601 r~=== 1 H-2501 -1~:::::::::::_~~o~:~:;=~~~~ ::=~ [:::::~:~= SRUHotOilHeater Unit 33 Charge Heater R0SE2 Hot Oil Heater Callidus burners Callidus i burners : CallidtlS Technologies, Technologies, Technologies, I I LLC LE-CSG-41,N burners LLC CUBL-i2W burners LLC I , '.o:QQ1~------ .......................J $..J~i_lY,1!3tu/hr (LHV Basis) o1. 11991 *, New burners in I , '.f9.9-\L.... ................1:31.}v1r,,.i.!u,/hr (LHV Basis)_1 CsLUsBi<-18<Pi-CRWoubruitrinerFs'iari1e; N...e...w..-.b.u..rn. ers in 2003.............,....7...8.....M....M.. Btu/hr (LHV Basis} ]9hri?)1~Qgrr12flnz,hhQg~1E0.2.@...Lcooh1i1r:1e..1:mmers.............L?.P.Q?~ : Callidus Technoiogies, LLC j 120 MMBtul!}LLhdYBs:1;;.i;;;L __H-3491._ ................................................tl:t.1r.?ff.B.:S:~.t;_r_J_il:ls:1;:;t9._r_.Qb.lr.\lfJJ_t;.?_t13.r..... .....L._bumers i Callidus Technoiogies, . CUBL-iO'N burners ... .LJBD LLC : J?:QMMI:l.!u,ibLtbl:N Qs:1;;.is) Jj 1 H-3402 r. --- . rhdrocracker Fractionator Reboiler i Unit 64 Hydrogen Plant Reformer 1 H-3101 : .,. SRU3 Hot Oi! Heater l .. H-0473 (SRU11SRU2 TGll SRIJ1 and SRU2 Tail Gas Incinerator i bUffif:ft:................................................. LE-CSG-12W burners I Callidus ....... burners Callidi;s Technologies, Technologies, U . . l Q\)!3-l,dl(vD[Jiumers LLC i 2009' ------------------- l..29.9.?~. ! CCc1 ... ,.........---- -- caTikius burner i Unknown ,t....--------------------- nn,~-----------,. --................:!,.. 05/1ii20 09 * Unknown ! Unknown Unknown Technologies, ...52. MMBtu/hrJLHV Basis\ 337 IV1MBtuihLLU::1YB.:?i?.J i 9,(:1 MMBt..u...f.h...r...(.,.L...H....V.....B....a...s...i.s..);. 1! NA J : 'l ~t~:~;:~~~i~:\fur~ ~~~i~~;\fu~ ........-... --1,:8~~:::::......=~:r:t~~~~:~ - -;"~ = ri SRU3-TGi FCC Reoenerator I 1. . . . . . . - ~ - - - - I t CCRr SRU3 Tall Gas Incinerator FCC Re,;enerator Scrubber burners Unknown CCR Reformer ~~~~~:~,,~:: -- Unknown -- "1!" ! Unknown runknown , j Unknown i ,,,,......... 05/i i/2009 ! NA Unkno;;,;; .....----+ NA ........ ,,,,,,,,,,,,, +' .........................................._ Unknown : NA i i - - - - i ' +..................- - F,L:Qqg3, A_lliy__EI@[ FL-0404, GOHT Flare j :,l~YE.i@L ! GOHT Flare Unknown ........1..lJr1h1gy111...... ,, ...............................,...Y.G.~.G.own................ MA +l Unknown Unknown : Unknown ! MA 1~ 1!= ii~~~~~~I:~~I~:: t~~~1::::: _j~~ ~~~:::: ==ifit~~ .-0001 i T.9..9...9.??lir1g.J.:9.\i\!<'l'. ........ - - Unknown S. Alky Cooling Tower (Marley Cooling Unis:i}.2ii1.G IIQnknown..~r:/:i"OQgpm:o:003% d I ! ~~~~r~lk, Coolin Tower i ~~~~;~,, ,, \ G~t~~~~~ G~~g;~~--... t~2:~86"~f!l~:o~g;~~/:J~~ift ! : TFccKNfcooiin~to;;;;;;; r~~~~~~~--- I~~~~~:~ .......... ...8~t~t:~ ,~~~~~,,~E..- ..~=;;~t' ~~l~i:g16 i ~~~v~ii-~~~~'Zi:6i~-'~~~!.r.~.;~;.:.:.o.r...........L..~.~.~.~~~;.~ ::::::::::=::_ ..... i G~~~~:~ Q~~~~~~~ ....................................... J,?9QB!!!,_....__ . T.~Q~? .1 OAF Uriit):~Qfl$i_> Ll,l,:i~[191:"'t:i .................-...... j Unknown ....................................... Unknown 1,?29.SJP.[l =1 ' f I Equipment component leaks (pump seals, i -+ seriaf~~1mbern assembied severa1 , etc,, i MA NA Varies NA ........~............... .... , ..............................~ ;~121:'l~i,r,uRacks 1 N;;;:~~~~~~~~::: . ::::::::FA::: ............................... .r .Vifa~i........... -- ..Y.<>:r.iS....... 1 ! I Fixed Root External Floating Roof & I I -!T-a--n-~kfsfff{ffsffeffe--T--able103,C.-.-). I ........~ ..I.n...t..e...r..n...a..~l...F...l.o..a..t..i.n...<....J: ...R....o...o...f...T....a...n...k..s...... Ii MA I NA Varies -----=-------- - - ; _.................. . Varies I "Tl !' lnstallaiion date , I ..... ... .... : i . r z tNote; are not used since most equipment consists of field e;;;t;<l parts that ~re i;~ site ;;z ;;;;;:y1;:;;:;e... "se;IaCiiii:mbers" for various :0r- components. Heaters arc the ~.0.~!..~.~.!nLI...~.0.9.";~~";,:;l1..gt:.~1~~..~.!:1E'.!:~?g~? a serial number but the heater as a whole does not have a single serial number. :D.!S...hgatcras 0 0 0 ACC Form Part 1 Permit# P05l~R2 & R2M1 Page 18 of 144 0 01 Ver4,l 02/25/2015 ..... (!) OJ EPA Inspection Report - Page 738 of 1969 Version 02.25.15 ~----------------------------------------------------------------------- a whole is typically identified by our equipment number. There may also be a "project number" or ''job number" from the manufacturer, but that can change if a heater is revamped at a later date such as when they modify the convection section to improve energy efficiency. A105 Facility: Control Methods A. Table 105.A lists all the pollution I control equipment required for this i facility. Each emission point is identified by the same number that was assigned to it in the permit application. I Table 105.A: Control Methods: This pe1mit condition provides a list but does not impose any standards, monitoring, record.keeping, or reporting requirements. Therefore, no further response is required. As instructed by the AQB, Navajo is completing the check box responses in columns 3, 4, and 5 of this form. Navajo continues to comply with all applicable requirements except for specific deviations as noted elsewhere in this document. (See the specific responses to the permit conditions that contain standards, monitoring, record.keeping, or reporting requirements for more information}. D Continuous r2J Intermittent f2J Yes 0.No 0Yes [2J No I Control Equipment Unit No. Control Description BACT Pollutant being Yes or No controlled Control for Unit Number(s)1 FCC Regenerator Scrubber Fluid Catalytic Cracking Unit Regenerator Cyclones + Wet Gas Scrubber NO PM&S02 FCC Regenerator CHLORSORB@ CCR Regenerator Vent NO Chloride CCR Regenerator Control Vent '' FL-0400 North Plant Flare I "Tl z FL-0401 South Plant Flare :0r- l 0 0 0 ACC Form Part 1 Permit# P051-R2 & R2Ml 0 01 Ver 4.1 02/25/2015 ...... (!) (!) NO VOC&H2S NO VOC&IhS Refinery process units Refinery process units ""'""~- Page 19 of 144 """"""""""-~~~UN EPA Inspection Report - Page 739 of 1969 Version 0225,15 FL-0402 FCC Flare NO VOC&H2S FL-0403 Alky Flare NO voe FL-0404 FL-HEP-PORT H-0473 SCR GOH Flare NO ,,,,,,,~--------------------- Portable Flare for Holly I Energy Partners (HEP) NO Pipeline Pigging Operations -------~..--................---........................................ Sulfur Recovery Units No. 1 & 2 TaH Gas NO Incinerator Selective Catalytic Reduction + ultra-low YES NOx burners VOC&H2S voe Sulfur I NOx SRU3-TG1 Sulfur Recovery Unit No. 3 Tail Gas Incinerator YES Sulfur SRU3/TGTU3/TG13 Best \Vork Practices, A207.B (BAGI') YES S02 D-0829/0830 Main API Carbon Canisters NO voe Y-0011, Y-0012 Drift Eliminators on Cooling Towers YES PM ' i I External Floating Roofs "Tl T-0737, T-1225 YES voe z (BACT) :r- 0 0 0 0 ACC form Part l Pcrmit#P051-R2 & R2M1 0 01 Ver4,l 02/25/2015 N 0 0 Refinery process units Refinery process units Refinery process units i i Pipeline Pig0ring Operations SRUl and SRU2 H-9851 SRU3 SRU3 MAINAPI Y-0011, Y0012 T-0737, T-1225 --~~~-.-... l I Page 20 of 144 EPA Inspection Report - Page 740 of 1969 Version 0225. 15 See Tab1es 106,B(i) and (2) External and Internal floating Roofs (NoneBACT) B-0009 Energy Efficiency, A204.N (BACT) H-2501, H-3402, H- ultra-low NOx bumcrs 3101 (BACT) SRU-TGI, H-2501, H-3402, H-3101 1 Comhust gaseous fuels only to a unit number NO voe See Tables 106,BO) and (2) Yes Greenhouse Gases B-0009 Yes NOx Yes VOC,PM the Regulated Eqoipment List H-2501, H3402, H-3101 SRU-TGI, H2501, H-3402, H-3101 R In accordance with the requirement that Navajo Refining prevent exceedances of the 24-hour and 3-hour National Ambient Air Quality Standards (NAAQS) for S02 during major refinery malfunctions, Navajo Refining shall only flare acid gas from existing Flare FL-0403 according to Navajo Re:fini11g1s !!Phase Two" plan dated January 5, 1996 and received by the Department 011 January 8, 1996, or from flare FL-0400, Navajo shall undertake the following measures for acid gas flaring from FL-0400 and FL-0403. CHART NO. 1 SUPP FUEL FOR 302 NAAQS COMPUANCE, fl.-400 6M '',..-'"' ~-10.0 ~ 60.0 ~ 50.0 ;;:'. 40.0 ,....................,..................,.,,. ................................;. ..................,....................;. ............... . ;" 30.0 ,,,.,_ ........................ , ................, ............,................ ,.......... . 1'; 20.0 <( 10.0 f IO 20 30 40 60 60 10 S;.:pp ~ul'3: Gasf!ow {Msdh} (1) Existing Flare FL-0400 shall be equipped with a flare tip or burners to supply supplemental fuel gas to provide enough heal to supp1eme11t I the heat released by combustion of the acid gas itself and the heat provided by smoke-suppressing steam. The minimum flow rate ot "Tl z supplemental fuet gas to he supplied during acid gas flaring such that compliance with the NAAQS fiJr S02 is assured shall be determined :0r- using Chart No. 1. The fuel gas used for this purpose shall be natural gas (sec definition at Cl 01,1::2:<<<<<< 0 0 0 /\CC Form Part 1 Pennit # P051-R2 & R2M1 Page 21 of 144 0 01 Ver 4J 02/25/2015 N .0.... EPA Inspection Report - Page 741 of 1969 Version 02.25.15 (2) Existing Flare FL-0403 shall be equipped with a flare tip or burners to supply supplemental fuel gas to provide enough supplementa1 heat The volume of supplemental fuel gas to be provided to generate enough supplemental heat to ensure compliance with NAAQS for S02 shall be determined using Chart No. 2. The supplemental heat to be provided when flaring the maximum quantity of acid gas has been determined to be 52.9 million BTU per hour which is generated by buming 96,200 SCFH of supplemental fuel gas. This assumption has been made to ensure compliance with the NAAQS for S02. The fue] gas used for this purpose shall be natural gas (see definition at ClOLF). CHART NO. 2 SUPP. FUEL FOR S02 NAAQS COMPLIANCE, FL-403 4(J . f35 Mso i;!25 , ................ , ................ . [20 !1s II ~10 I s 0 :20 40 50 80 100 Supp. Fuel Gas (Thousand SCfH) C. Beginning December 20, 2001 no fuel oil shall be burned in combustion units except as frlllows: (CD ,17.C) (1) Torch Oil may be burned in the FCC Regenerator during FCC start-ups; and. (2) Fue1 Oil may be burned in combustion units after the establishment of FCC NOx emissions limits pursuant to permit condition Al 10.A, provided that emissions from any such combustion units are routed through the FCC Wet Gas Scmbber and Navajo demonstrates, with the approval of EPA, that the NOx emissions limits contained therein and the S0:2 emissions limits stated in A106.A and A107,A will continue to be met. D. The Artesia Refinery FCC was initially limited to less than 20,000 BPD capacity. FoHowing the December 2003 expansion of the Artesia refinery's FCC as authorized by permit 195-M:15, the catalyst regenerator for the FCC is subject to the minimum requirements for continuous emission monitoring and recording set forth in Appendix P to 40 CFR Part 51, Consent Decree Paragraph 15 required the FCC to be subject to NSPS Subpart J for opacity as of December 31, 2003. A wet gas scrubber was installed in 2003. An Alternative Monitoring Plan (AMP) request was submitted to EPA 011 December 31, 2003 because a continuous opacity monitoring system (COMS) will not v,mrk on a wet gas scrubber exhaust because of the interference from the water vapor. The AMP satisfies the requirements for both NSPS Subpart J and 40 CFR Part 51 Appendix P I "Tl z :0r- i A.106 Facility: Allowable Emissions 0 0 0 ACC Form I'art 1 I'ennit # P051-R2 & R2Ml 0 01 Ver 4J 02/25/20 t5 N 0 N Navajo continues to comply with all applicable D Couu:num:rn 0Yes rgj Yes Page 22 of 144 EPA Inspection Report - Page 742 of 1969 Version 02.25,15 r emission limits except for specific deviations as A, The following Sec tion Wits me emrnsmn noted elsewhere in this document and events k8:J !ntennithmt ~ No D No units, and their allov,rable emission limits. reported per 20.2.7 NMAC. (See Table 1030_A_ for all applicable regulz ' J:;a~;~:;::~owa~1.~!;,;i~~i~~ --- Ir ,,,,,,,,,,,,,----------------,---------- --------------~~~----------------------, ....... 'N-'O_x_.-----~------- co +~~t' ":~,, :~'o~~;" !~..:,":'"' _c_~ ~. _(T'fPL~r;i '. '';~';1 !'i!~l!,Ll~1~ ~, voe I '';Td '"l'!1r1 1tr,r1- ~,~!-J~-~tlb-f.~~+:~Tie!J~~1:-~=~S!!-l~;i.~t-~1;~J1f1!W! . i1 H- 6.)18 1!56 i 7"' ' HR 01) t!BITl?)~?.~?~:::r:.: ?~:::::::J~:--o~~,,:~,,,T:; ;:; t~::;363LO~j~;~m j !! j :H-0303 \ 11 l 0.4 \ h..-..-"""""'"---.-.-.-.-.-.-.-.-'f,~---.-.-.- -.-.-.-.-.-.-.-.--1----.-.. 0.7 L2 ~~-,~ . 9 394 i r~ :9i[ :~~ ,--~~;; ;~:;--1 140 5.2 004" 182 "97 i -.- " L ,9,~ __ 1 LO \ 4.4 ------------------------------,--- I ]'1 72 1? -,-, l.U. , - '0.,L6 0.1 03 03 0.9 LO 4-5 0.7 33 IH-0421 27 i LO i L6 . 2A 10.6 0J)9 2.5 :rf-0464 -=--:::::-:J --------:::: :~:..../lI:: r: o:?..... --- o.5 ....J 2,3 ...... - ::,:::_:~:~----e---- ---~-:?... t iM~6~6T 1; 1....}},~,,j -~:-~,,,,, ~ -~{~---- i ~~:!------- ff{j1j i ~:~ ~~-~ I=~~=~!~-! II; 1T~i~-;)~L,~$iitt ...... 1 I "Tl z !-~:~::~~ :0r~ 0 ~~~18} l :~~ i ~:: i ''''''"~~: I ::~ . L 1~; ~to11 !-~:~~-------~ ....;\6...... 0 0 ACC Form Part 1 Permit# P051-R2 & R2M1 0 01 Ver4J 02/25/2015 N 0 (,) 02 LO 0.4 . 2.8 3,03 I ~:~ 1-------~: 0.7 0.7 3.1 ~0.3 L +1.4~ 02 0.8 2.0 8,8 0.1 03 Page 23 of 144 EPA Inspection Report - Page 743 of 1969 Version 02.25,15 H-0473 NA (SRUl/SRU2 TGl) isri.uj>fdi NA !>F-C---CR-e-u"'cneratm NA iFL-0400, North NA :Plant Flare NA l~i~~~l;~.~o~::h 'FL-0402, FCC NA Flare FL-0403, Alley NA Flare FL-0404, GOHT ! NA . 1 Flare 30J) 81,8 6.5 3CUJ 8L8 6.5 27.9 6LO 35.0 0.2 0.5 0.2 (U 0.1 <OJ 0.1 <CU <Cd <0.1 2.4 10.5 4J 28.5 28.5 101.9 0.8 0.2 <0.1 18.l 1Suhtotai Tanks, .'able 106.E Fugitives, Table 106,F 345,4 668.8 Misc Somces, Table 106.G Cooling Towers, Table 106.H Oi1W s"':~'"''tr,rn 'able 106.I 0SSM, Table 107 27,4 31.6 TOTAL 1 NA 372.8 700.4 NIA 27.7 121-2 NIA 15.0 65.7 NIA 121.9 106.8 Nii\ LO 4.3 NIA 0.2 Ll NIA 0.2 u NIA <0.1 0,2 NIA 13.6 59.6 U56.2 2,; 97.6 N/A 1256.3 0.5 0.5 25.0 OJl OJ) 0.0 OJ) 0.0 2.2 0.1 2.2 109.5 0.0 ............... 0.0 0.1 0.2 <0.1 OJ) <0.1 0.0 <0.1 OJ) 196,(} 2.3 .................... 9.0 0.6 (),6 0.7 cu 0.2 <CU 10.2 70.21 :")"L",I..4 !i __J 994.6 I ...............~l lo.6 i 56.2 0.4 205.3 5.3 9,5 46.2 1515.7 "--"indicates that the emissions are less than 1.0 pph or 1.0 tpy and emission Hmhs are not required for this permit, unless it's for a control device. Unit 9851, the SCR exhaust has Ammonia Slip limit of 7 ppmv on a wet basis and 6, 1 tpy (BACT). I "Tl "'-----------------------------------------------'"""''' z :r- 0 0 0 0 ACC Form Part l Permit# P051-R2 & R2M! 0 01 Ver 4, l 02125/2015 N 0 .i:,,. Page 24 of 144 EPA Inspection Report - Page 744 of 1969 Version 02.25, 15 A106 Facility: AUowable Emfaskms I_:n, The permitted emission sources at the refinery shall consist only of the sources !' listed in Table 106,A and T,,,..a....b....l.,e,...s.....,,,1,,,,0,,,,6,,,,..,B,,,, Navajo continues to comply with all applicable emission limits except for specific deviations as noted elsewhere in this document and events reported per 202.7 NMAC D Continuoui lxJ Intermittent \_throu~ 106J of this permit 'i ! l.NTER'\JAL FLOATING ROOF STORAGE TANKS I I TABLE 106J3(1) VAPOR PRESSURE LIMITATIONS FOR REFINERY NON~ I i COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS {VOC) ,, . ; I auk No. ! < O O Typical Liqmd . Stmed r 1Vlost Vofati.!e Category M~X Vapor Pressure (psia) , . , . ""' -..1 , t'' I, 'd I of AUo-wable faqmdiii to o, ,nost "o,a tte . Aqm at i be Stored1 Max Temp, T-0056 i Nw;hthas """rrngh-Vapor.Pressure2 1--11-.-0 """"""""""""","-"""""""".t.,.nnn..nnnnnn..nn,-" ......u. . . . . . . . . . . . . . . . .____________________________ -------- ' - - - - - _,,-,,,,,,,,,,_ _ T-0106 ! Distillates ! High Vapor Pressure2 1 LO T-0107 \ Gasolines i High Vaporf'ressure2 ccccc.ii,O T-0108 Gasolines High Vapor Fressure2 11.0 es High Vapor 11 J) T-0111 Naphthas T-0112 Naphthas T-0011 Gasolines T-0124 Gasolines T-0012 GasoHnes .-....,..,,............................, T~0413 DistiHates T~0415 } T~0417 GasoHnes GasoHnes T-0439 Crude Oil High Vapor High Vapor 1-'rP-"""'"'"'" High Vapor v""''""'-'"'"'" High Vapor v""''""'-'"'"'" High Vapor !-'>'P'""''"p.k High Vapor !-lrPS:,S:,'1irP" High Vapor,."'."""'""'" High Vapor High Vapor 1 LOJ 11.01 11.0 , l LO 1 LO 0Yes f2:] No lxJ Ye 0No l 1 Liquids in lower volatility categories may also be stored (i.e., tanks allo,vcd to store high vapor pressure category liquids can also store moderate and low vapor pressure I category liquids; tanks allmved to store moderate vapor pressure category liquids can also store low vapor pressure category liquids). I 2 High Vapor Pressure Liquids indude: Crude, Naphtha (raw or treated), Unleaded Gasolines (sob-grade, regular, premium, and other blends), Alkylate, Refonnate, FCC Gasoline, Ethanol, Isomerate, Straight Run Gasoline, and other refinery foedstocks, intermediates products byproducts, and wastes having a max vapor pressure of 11 1 I psia or less under actual storage conditions. "Tl z :r- ~----------------------------------------<< 0 0 0 0 ACC Form Part 1 Permit# P051-R2 & R2M1 0 01 Ver 4.1 02/25/2015 N 0 01 1 i -----------------------~J Page 25 of 144 EPA Inspection Report - Page 745 of 1969 Version 0225J5 EXTERT'1AL FLOATING ROOF STORAGE TA.t""iKS TABLE 106.3{2} VAPOR PRESSURE LIMITATIONS FOR REFINERYNON-COJ\,IBUSTION SOURCES or VOLATILE ORGA.t'\JIC COMPOUNDS (VOC) - Tank No, , Typical : Stored Liquid Most Vohl.tile Category of Allowable Liquids to be Sto.red1 Max (psia) ........ nn.ss,~-.-.-.________ Vapor .Presim.re of lVfost Vo!atik Liquid at Max Tempo I:i il'.",<.i,:p..t1;:.1.t.1H,,.l,.,.:.:, faomerates :: .H.. -,;,,.,~h. ""VrUy.,orPressur~"2 i High Vapor Prcssure2 11.0 11.0 : T-0079 i T-0117 ~ T-0401 : faomerates : GasoHnes ............ Gasolines.. i...T-0402 ! T-0411 (iasoHnes Gasolines T-0412 T-0435 gasolines Crude Oil 1~t~:~:cr I T~0830 r-;r;=og':34 'T-os3s _____________ Slop DistiHates Distillates T-1225 Naphthas ~-~~ T-0737 Sour Water TK-NE___W____E___1__T___I__A___N___O____L__________,_____E____t__h____a___n____o___l_____________ ! Hfah Vapor Prcssure2 11.0 r High V~po,:P;;~~;;e2 1LO ... ... i High Vapor Prcssunl 1 TT!igh\ a12or Pressui:e~i . --- i High Vapor Pressure~ 11.0 ----1-L-O- l LO J!!izh.YEE?!.J~!~~i~ii~ I High Vapor Pressure2 . . r~!~:~::~..~ ~~~ High Vapor Pressun/ . __ r Moderate--V-ap~~;-p~:;;;;;iire3 ...........] ..Higii".var;orPrc;surc2 .. High Vapor Pressure2 I High Vapor Pressure2 High Vapor Pressurc2 ...... 1 LO L5 ILO lL._j l LO j cc-.. ~:~~J Liquids in lo,ver volatility categories may also be stored (i.e,, tanks allowed to store high vapor pressure category liquids can also store moderate and low vapor pressure category liquids: tanks allowed to store moderate vapor pressure category liqllids can also store 1ow vapor pressure category liquids), ?. High Vapor Pressure Liquids include: Crude, Naphtha (raw or treated), Unleaded Gasolines (sub-grade, regular, premium, and other blends), Alkylate, Reformate, FCC Gasoline, Ethanol, lsomcrate, Straight Run Gasoline, and oilier refinery feedstock&, intermediates prodllcts byproducts, and wastes having a max vapor pressure of 11 psia or less under actual storage conditions. 3 Moderate Vapor Pressure Liquids include: Desu!furized Naphtha (Splitter Bottoms), Light Slop, and other refinery feedstocks, intermediates, products, byproducts, and wastes having a max vapor pressure of 15 psia or less under actual storage conditions, --------------------------------------------------"~""""""""'" I "Tl z :r- 0 0 0 0 ACC Form Part l Permit# P051-R2 & R2Ml 0 01 Ver4.l 02/25/2015 N 0 0) Page 26 of t44 EPA Inspection Report - Page 746 of 1969 Version 02.25 .15 ..FL'XED ROOF STORAGE TANKS TABLE 106.C VAPOR PRESSURE LThUTATIONS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS (VOCs) Tank No. ~w~ Most Volatile Category of Allowable Liquids to be Stored1 Max Vapor Pressure (psia) of Most Volatile Li.quid at Max Temp. T-0013 Slop Moderate Vapor 1.5 T-0040 Distillates Low Vapor 0.5 T-0041 Distillates Low Vapor 0.5 T-0110 Asphalt/Pitch Low Vapor 0.5 T-0400 Gas Oils Low Vapor 0.5 i T-0404 T-0405 Carbon Black Oil (CBO) Low Vapor 0.5 ------------------------~-uuu.-.-.- Low Vapor Pressure4 0.5 T-0409 T-0410 Gas Oils Asphalt/Pitch re4 Low Vapor Pressure4 0.5 _ _ _ _................... 0.5 T-0418 Distillates Low Vapor Pressure4 0.5 -T-0419 Distillates Low Vapor Pressure4 0.5 i T-0420 CBO [ Low Vapor Pressure4 0.5 Distillates Low Vapor Pressure4 I 0.5 Distillates Low Vapor 1-'rP"<m,rP~ 0.5 T-0431 !]~:_ ;~~-J~:!;E:;;;J ~ T-0432 L.................... I T-0049 Distillates i Low Vapor Pr~;;me4 Slop .................. ! ............................................................. . Moderate Vapor Pressure3 I "Tl z T-0061 Low Vapor Pressure4 :r- rf~ooi5:,--- .......... rt:o;v~i;o~"ii~~~~fil~4 ~, 0 0 0 0 ACC Form Part 1 Permit# P051-R2 & R2Ml 0 01 Ver 4.1 02/25/2015 N 0 -..,J 0.5 1.5 1~~1 0.5 I o.5 i - - - - - - - - - - - - - - - - - - - - . ,l Page 27 of 144 EPA Inspection Report - Page 747 of 1969 Version 0225. l5 .T....-...0...0....6...5....................................C.....B....O....................,,,,=---- Low Va,,por Pressure4 ccc.-.-cccc 0 5 -.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-. . . . . . . . . . . . . . . . ~ T ~0075 CBO LOW' Vpp0f.Pre??9!~: 0-5 , T~94?} . Gas OUs ),?""Y y~f!?tP~~~~l;l~~ ~--- 0.5 I~.~~~.;.............................l...~~~sti~;~:~........................1...t~;..;;:.ri~~..~;:::~~~: ,0 ~:; T-0810 -L~l?:E i. Moderate Vapor Pressure T-0814 \ As1:halt/Pitch Low Vapor Pressure'' T-0815 i Distillates L o w V a n o r Pressure'' ,TMcccccccccccccccccc+--------------------------------- ------------------0 ----- -K .................................... . T-0838 : Distillates Low Va1Jor Pressure4 ,-ccc--.co------------------------------+------------------------------- --------------- ........ ........................ - T-1227 r i:=oos 1 : Asnhalt/Pitch : Low Va11or Pressure4 TAs~ha1tiPitc1; Tio~~ vavo~ P~~;;:;;:~1 I T~0082 ]Asphalt/Pitch ,,,,[ Lo~v Vapoi: Pressurc . 4 I R\V-4 : Recovery Wdl : High Vapor Pressure1 ....... ' 0,5 CU 1LO r I i Hvdrocarbons : ._.._,............................t.-.....,....i:::......,........- ..- -..=-i..- 1 Recovery Well i High Vapor Pressun} I Hvdrocarbons l R\V-6 R~covery Well High Vapor Pressnre2 ~;;;J~;~I?.2!1~ 1-TK= I i NE\VBIODIES 1 ~Lo;-\iapor Pressure4 Li...E... l~ [ .................. ' ! 1 LO lLO 0,022 Liquids in lower volatility categories may also he stored (i.e., tanks allowed to store high vapor pressure category liquids can also store moderate and low vapor pressure category liquids; tanks allowed to store moderate vapor pressure category liquids can also store low vapor pressure category liquids). 2 High Vapor Pressure Liquids include: Crude, Naphtha (rnw or treated), Unleaded Gasolines (sub~grade, regular, premium, and other blends), Alkylate, Refommte, FCC Gasoline, Ethanol, foomerate, Straight Run Gasoline, and other refinery feedstocks, intermediates, products, byproducts, and. ,vastes having a max vapor pressure of 11 psia or less under actual storage conditions. 3 Moderate Vapor Pressure Liquids include: Desulfurized Naphtha (Splitter Bottoms), Light Slop, and other refinery feedstocks, intermediates, products, byproducts, and wastes having a max vapor pressure of L5 psia or less under actual storage conditions. 4 Low Vapor Pressure Liquids include: Diesel (raw or finished), Kerosene (raw or finished), JP-8, CBO, LCO, Slurry, Heavy Slop, Cutback Asphalt, Cutter, VGO, AGO, and other refinery feedstocks, intermediates, products, byproducts, and. wastes having a max vapor pressure less than (U psia under actual storage conditions, ..........................................................................................................--- I TABLE 106J)- STORAGE TANK THROUGHPUT A.,.r.m TEMPERATURE LINlITS J . .......,~!!lJ~_i:f~~ ..~ ...............:..................................I~:r.?.lJ.ggp:i!Ui,,,A,l,i_Ir} ! Maximum St~f!l;g_!Y.ll'~!:!f:l1.tt: C) Asp~ajy:f.'itc;4. 30,872,000 ,,,,........L 510 I f~A~~?!1: ?}ll:?~Q~~J~~QL L??J~JQ "Tl z Crude Oil 76.212,000 :r- 0 0 0 0 ACC Fom1 Part l Permit# P051-R2 & R2Ml 0 01 Ver 4.1 02/25/2015 N 0 OJ !- 250 Ambient Page 28 of 144 EPA Inspection Report - Page 748 of 1969 Version 02.25.15 ,..... Distillate f .................................... ~.5-1QZ.?1?2Q.................................. ----~ ______________________________________}_!_Q__ .... . ; Gas Oil 25,059,500 ! 310 !: : ~ ~~;:::::: == ; \f........................................S...l..o...,p-...... ...................... ., ..,,,,, ...,,,,,,1 , 3 3 0 , 0 0 0 . :::__ Ambient ,................................ Sour Water BioDiesel l 949,000 Ambient --------- Ambient Methanol ........--,.................... 142,350............................ -----~------ ......A.....m.....b..,i..ent ....-................................--.................................... ............. ------------- - - - - - T.,,, : TABLE 106.E- STORAGE TANK voe AND U:2S EMISSION LIMITS1 (return to A203) r Tank Type, .. ,,,,,,,,,,L,,,,,,,,.....voc.Emission_Rate{tpy} .. ;~:;;:;::~_Rate.(tpy)__j I , Fixed-Roof I 238.6 L........... 0.0 8 t=~:f =t- J = I!; J~~ 32:: The permittee shall demonstrate compliance with the above throughputs and emission limits through the annual emissions inventory process. temperature & throughputs) shall be monitored and recorded weekly by the permittee. Specific tank data (e.g. Table 106.F, 1EMISSI0NS LIMITS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS (VOC) FUGITIVE EMISSIONS I<'ROM EQUIPMENT LEAKS . Process Unit TD Number Description l l FUG-02-SP CRUDE South Division Crude Uni! _Fua-_10-Fcc ..................... Fcc..wicvs,,,,... ,,,,,,,, .. FlJG-20-ISOM Powerfomier/Penex Unit w/CVS Maximum _Ht:ur1y Average Annual VOC VOC Eimsswn E.. R ; Rate (lb/lu) mission ate 1 (lons/vr) ,,, --r---- l 0.2 --------'44.6 T...................................1~-~ .. ------------------ 41.2 l FUG-21-SPVACUUM nit 3. FUG-05-KERO FUG-06-NHDU FUG-18-LSR MEROX TIU ! JP8 Hydrodesulfurization -----+ ------....-----~ccccccc-c~--c--- Mcrox/Mesichem Treating Units 3.5 ' 153 , ""NNNNh "C -"TM"'"" L[. FUG-35-SAT GAS i Saturates Gas Plant HU 80.0' i.,,, ' ,,,,,,,,,,,,..... I : FUG-29-BLENDER/TK FARM i Light Oil Tankagc 29.6 "Tl z . j I<i:i'o..'ASPHALT sni j Asphalt/Heavy Oil Storage . 3.5 . 15.3 :0r- fiucffiTEL.GAsrFuel Gas Distribution System ~ ,,,,,,,, ------ 4:Z' isj< ,,,,, 0 0 0 ACC fom1Part l Permit# P051-R2 & R2Ml 0 01 Ver 4.1 02/25/2015 N 0 (!) ..............,,,, 1 Page 29 of 144 EPA Inspection Report - Page 749 of 1969 Version 02.25.15 ~~ ! f'lJG-LPG ! FUG-13-NHDU !~l!~.~!~~.~~Y... FUG-09-N ALKY FUG-44-DIST-HDU FUG-45-DIST-HDU =1tL ,;~ I LPG Storage System i 21.6 j 94.4 ,ccRRrlo-(w/filbatrecyJ;m,,c=i== I Naphtha HDS Unit 10.2 , 44.6 ! 7.5! ! ~?~1~1.~r.Y~it.CV!.~??!.... ..................::::::::::::::::::::::::::=::: ..... ::~:::::::::::::}}:::]::::: ....... I North Alkylation Unit (New-Inside battery limits) 12.0 52.5 i ---~--- ---~---------- ---------4---- ........... ; i Gas Oil Hydrotreater (incl. CVS) 9 .3 40.6 .....; ...........................-.................... .......... ................................................- i - - - - - - - 1 . Gas Oil Hydmlreater (incl. CVS) 2.6 l l.2 i FUG-07-N AMINE ---rAiiilii'e"u~it~Ti~~tfug/R~g;;: - {j''+ 27.5 FUG-SRU1/SRU2/TGTU ................ ' SR1Jl/SR1J2/SWS w/CVS .. FlJG-07-SWSl ~-- . FlJG-80-WWTP CVS ' FUG-33-DIST HDU Sour Water Stripper Oil/Water Separator Relocated bie.~eUfus t.i11ii wicvs FVG-08-TRIJCK RK i!JG-RL()-ASPHAU' Loading Racks Asphalt/Pitch Loading Rack 1 0.7 ----~:ti FUG-73-SP UTJL Utilities 1---~~~~=i-~=1;:i~~~;~~3/TGI3 ----tt:ttltJ~~~t . 16.7 . 73.3 ! :~rr:.:: ...........1.~21 . RJd:}4:j::fyiiilocRACK:i?il" wx Hydrocracker FlJG-25-ROSE-2 T .................. ROSE Unit ............................ ------- FUG-64-H2 PLANT-2 j Hydrogen Plant ................................................_ .....i.... TL2-] FUG-RRTOTRUCK /"subtotal Facility VOC CAP : Crude oil U11loading system, closed loop system between railcars and trucks ............................................................, .......... .............. i O.l j 0.5 ! ! ! 122i:s1994.6.] 1 Minor changes within the facility to piping and components that affect fugitive voe emission source shall be updated and added during the next available Significant permit revision in accordance with 20.2.72 NMAC. The facility wide fugitive voe emission limit shown above and in Table ]06.A of this permit. MISCELLANEOUS SOURCES Table 106.G EMISSION LIMITS FOR REFINERY NON-COMBUSTION SOURCES Of VOLATILE ORGANIC COMPOUNDS (VOCs) Loading Rack Loading Rack Description Material Loaded Hourly Annual Throughput Throughput VOC Emissions bbl/br bbl/yr lb/hr ton/vr Gasoline 1214 4.25 LSO TL-4a Fuels Truck Loading Rack Diesel Jet Fuel ---- 107100 35700 I TOTALVOC "Tl z CBO/LCO Truck / Carbon Black :r- TL-7 0 0 ... Loading Rack I Light Cycle ( ~. 0 0 ACe Form Part 1 Penn.it# P05 l-R2 & R2Ml 0 01 Ver4.1 02/25/2015 .N..... 0 l.72 0.75 6.73 6.30 355 J..72 (L34 4.86 1.57 (L06 rnwwoo~................... Page 30 of 144 EPA Inspection Report - Page 750 of 1969 Version 02.25. 15 I ] 1 RL0-8 Railcar Loading & Off-Loading Rack Diese1 6.30 1,63 6.30 1J5 (U2 CL54 OA2 038 OJll 0.03 ~~~~~l I~~~:~~;trolling TOTALVOC j 1250m1/hr I - - - ~ -"-.-.-.-.-.- -.-.-.-.-.-.-.-.-.-.-.-.-.-.-..; .-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-Nuu~...-wuuuu~;-;.;......... {- iit~;; 630 2.09 ii I OA6 2.0 .;.;.;.;.;.;.;.;.;..................................... ! .........->...J Note:i. Calculation method and factors per AP-42, Section 5-2, dated June 2008- a Controlled emission rate. The previous controlled rale ,vas set by the terms of the consent agreement between Navajo Refining Co. and the DepartJ.nent executed January 28, 1994. The agreement required that the incinerator have a minimum 90% destruction efficiency for gasoline loading and a minimum 80% destruction efficiency for diesel fuel loading or fo! A fuel loading. This was achieved by a vapor combustor. This device has since: been replaced with a carbon adsorption system compliant with MACT Subpart R, as subject per .\1IACT Subpart CC Emission limits changed i.n 195-l\11-17 to correspond to Titk V pcm1it values. .... COOLL.'\/G TOWERS Table 106,H EMISSION LIM]TS FOR REFINERY NON-COMBliSTION SOT.TR.CE OF VOLATILE PM Source lD VOC VOC PM PM CO CO lb/hr Y-0001 L8 7.9 0.3 L2 Y-0002 --------------------------- ----- Y-0008a 1.8 6.5 7.9 0.3 12 1------------------------------------------------i-------------------------------,-----------------------------------------------s------------+-.......................___ ..____,__, 28.3 0.7 2.9 0.58 2.54 1,3 5,5 0.5 23 OA 1.8 02 0.8 Ll 4.7 02 fl7 i Subtotal (for informational 123 56J !_ ..PX1T'?J~~..9?b:.l, ___ _ 2J 9J a Y-0008 cooling tmver provides 100%1 control of any NH3 emissions from V-H2 and V-H2-2. Unit 64, Hydrogen Plant has de-aerator Ene that has dissolved CO that is connected to the cooling tower, ,------------------------- ----------------------- ............................~u1ori1,vAT"i:1i"s-irARAT0Rs 1 IGT~"s'y~~L H~~~~~~::~s~~ . i Table 106.l EMISSION LIMITS FOR .RE!'INERY NON-COMBUSTION SOURCES OF VOLATILE ! I ; Equipment : Em1ss1on Pomt ! Emission , Em1ss1on I IJQ !D De~gciE!i2EL 3!~f1~brt....,.._R.]QJt?_Q_(Y..r.L "'Tl i : Above Ground AP! Oil-Water Separators z :r- - MA!N AP! D-0829/0830 and enclosed drain system. <O.i <0.1 0 0 0 0 ACC Fom1 Part t Permit# P051-R2 & R2Ml 0 01 Ver 4. l 02/2512015 .N..... ...... Page 31 of 144 EPA Inspection Report - Page 751 of 1969 Vcrsion 02.25. 15 T-0396 H;~=~~~Tii~~~:::~~ ..... + ~~ if~~ ~~:~ J ~~ ==F~~:~ f ~~:~~ : ~~:oo =111~E~~o~~~lQ!!:i~= Subtotal (for informational purposes only} 5.3 I ~~5~ ~ 10==1 SA A106 Facility: AHowablc Emissions 1:8'.l Continuous C. Compliance with Allowable Emission Limits 1:8'.l Intermittent 0Yes l l'8J No I i 1:8'.l Yes 0No Requirement: The allowable mmBtu/hr, lb/mm.Btu, lb/hr, and tpy emission limits for equipment listed in Table ] 06.A construction of which predates the effective date of 202.72 NMAC (August ' 31, 1972), and have not been modified since August 31, 1972, shall be the "potential emission raten of that unit as defined in 20.2<72. l 07 NMAC and the potential to ernit ofthat unit defined under 20.2.74 NMAC, The mmBtu;br, lb/hr and lb/mmBtu limits are based on an hourly rolling 3-hour average, (NSR 0195M35, Condition Al06,C and revised) Nava.10 continues to comply with all appUcab!e emission limits except for specific deviations as noted elsewhere in this document and events reported per 20.2.7 NMAC. M~ni!orin~: -Fo~ units with lb/mmBtu Navaio continues to comply with all applicable mmss1on hm1ts m Table 1,06,A, the emis;ion limits except for specific deviations as Pcrmittec shall monitor the 1b;mmBtu to noted elsewhere in this document and events demonstrate comp1iance with the reported per 20,2,7 Ntv1AC mmBtu/hr, lb/hr, and lpy emission li~i!::!_:___J---------------..--------.....---........__________ ,.... ,,,,,,,, __ .Recordkeeping: To demonstrate II Navajo continues to comply with aH applicable l'8J Continuo.rn: k?J Intermittent 0Ycs I [g] No 1 r8J Continuom~ i O Yes 1 l'8J Yes 0No rgJ Yes ~~;11~~tt~1~~~,:~~T~~;:~tt~~~ I schoomwpilniagnce,therecocrodsrrelast~maln] bbeetwkeeepnt Ij nemoteisdsidosnevli,mrhietrseeixncethpitsfdoorcsupmeceinfitcadnedveiavteionntss as kSl Intermittent J__ [g____]____N____'___o []No "Tl z 1:~:tl~b~~~.Jreported per 20,2,7 NMAC. ! ___ J :r- 0 --=--J 0 0 0 ACC Form Part 1 Permit# P051-R2 & R2M1 Page 32 of 144 0 01 Ver4.I 02/25/2015 .N.... N EPA Inspection Report - Page 752 of 1969 Version 02.25.15 tota1s. TI1e records shall also document any noncompliance with emission limits. For each unit, a summary of the method ' used to detem1ine compliance shall be recorded. The pennittee shall maintain records in accordance with Section Bl 09. Navajo continues to comply with all applicable Reporting: ]11e pennittee shall report in emission limits except for specific deviations as accordance with Section Bl 10. noted elsewhere in this document and events reported per 20.2.7 NMAC. A106 Facility: Allowable Emissions ! D Continuous I 0Yes 1:8:1 Intermittent II 1:8:1 No l................ 1:8:1 Continuous D Yes l1:8:1 Yes 0No 1:8:1 Yes D. BACT S02 Limit - Fuel sulfur limit jl Refinery-Wide for all units burning refinery fuel gas (excluding units H-8801, ' H-8802 and H-9851 which burn only Navajo continues to comply with all applicable natural gas) shall not exceed 60 ppmv H2S emfasion limits except for specific deviations as on a daily rolling 365-day average. The noted elsewhere in this document and events ton/yr emission rates for S02 in Table reported per 20.2.7 NMAC. 106.A of this permit are based on this daily rolling 365-day average 60 ppmv H2S limit. Compliance with this limit shall be demonstrated per the methods described in Condition Al 10.A. A.l06 Facility: Allowable Emissions 1:8:1 Intermittent , 1:8:1 No t8'.I Continuous 0Yes D No t8'.I Yes E. BACT NOx Limit - In addition to the emission limits shown in Table 106.A Boiler Unit B-0009 has a BACT NO~ Navajo continues to comply with all applicable emission limits except for specific deviations as noted elsewhere in this document and events t8'.I Intermittent I t8'.I No 0.No limit of0.02 lb/MM Btu, and CO2 hmit of, reported per 20.2.7 NMAC. s-1,1-2-.1--l-b-/M--M---B-t-u-. -------------'-------l'------~.uuuuuuuu. nnnn .............. )..,,,, I "Tl z :r- 0 0 0 0 ACC Form Part l Permit 1-t P051-R2 & R2M l 0 01 Ver4.l 02/25/2015 .N.... (,) Page 33 of 144 EPA Inspection Report - Page 753 of 1969 Version 02.25.15 rAiti6""F;;iiiiy;-Aii~;ahl~ Emissions I F. BACT S02 Limit - TI1e Sulfur Recovery Unit No. 3 Tail Gas Incinerator (SRU3-TGI) is limited to 192 ppmvd S02 at zero percent oxygen on a hourly roHing 12-hour average basis. In addition, SRU3-TGI is limited to 192 ppmvd S02 at zero percent oxygen on a daily rolling 365-day average ... basis. A106 Facility: Allowable Emissions cccccc cccccccccccccc " " " l'8J Continuous Navajo continues to comply with all applicable emission limits except for specific deviations as noted elsewhere in this document and events reported per 20.2.7 NMAC. r8J Intermittent I D Yes i r8J No l'8J Yes 0No """+ - - - - ! - - - - - - - - . - . . . . - - - _ _ ___, r8J Continuous r8J Yes 0Yes G. BACT VOC Limit - The naphtha storage tank T-1225 and sour water storage tank T-0737 shall be equipped with an external floating roof using double seals to reduce VOC emissions to the atmosphere. "I11e maximum b.ue vapor pressure of any volatile organic liquid stored in either tank shall not exceed 11.0 psia. Demonstration of compliance is through the NSPS Kb and MACT emission limits. A106 Facility: Allowable Emissions Navajo continues to comply with all applicable emission limits except for specific deviations as noted elsewhere in this document and events reported per 20.2.7 NMAC. l'8J Intermittent 0No l'8J Continuous ~Yes l'8J No 0Yes H. VOC - All fugitive piping components in voe service associated with the process units proposed in Permit 195M25 (Units FUG-25-ROSE-2, FUG-31SRU3/TGI3/TGI3, and FUG-34Hydorcracker) shall be monitored under Navajo continues to comply with all applicable emission limits except for specific deviations as noted elsewhere in this document and events reported per 20.2.7 NMAC. r8J Intermittent 0No l'8J No the MACT subpart CC leak detection and repair program, or an approved equivalent ..progra1!~, to reduce voe emissions. I "Tl z :r- 0 0 0 0 ACC Fom1Part l Penn.it# P051-R2 & R2Ml 0 01 Ver4.1 02/25/2015 .N..... .i:,,. Page 34 of 144 EPA Inspection Report - Page 754 of 1969 Version OL25J 5 AJ 06 Facility: AUowablc En1fasions I. VOC - Consistent with MACT Subpart Navajo continues to comply with all applicable emission limits except for specific deviations as [8'.] Conthmom, [8'.] Inte:r:mittent rsJ Yes D No 0Yes [8'.] No l CC, the gasoline truck loading rack (TLO- noted else,vhere in this document and events 14) shall be limited to 10 mg of VOC reported per 20.2,7 NMAC ~n:t~-~i2E-~J~~tJit~r5!fgl:~?!.1.;~t;J~.~~:~.: -----------+.--------------------l-----------------t - . _____________, A.106 Facility: Allowable Emissions ~ ContinuoD:;>;, I ~ Yes 0Yes J. PM10 ---- Cooling towers, Units Y-0011 11 Navajo continues to comply with aH applicable ~ Intermittent D No !6J No and Y-0012, sha11 be equipped with high- emission limits except for specific deviations as efficiency drif1 eliminators to reduce l noted elsewh~Te in thls document and events PM10 emissions. Demonstration of I reported per 202.7 NlVIAC, compliance is through annual inspection in accordance with in Condition A212,R AJ 07 Facility: Allowable Startup, Shutdmvn, & l\!lai:nte:nance (SSM) and M_aifunctio:n Emissions D Continuous [8'.] Intermittent D Yes [8'.] No rsJ Yes 0No A. The maximum allowable SSM and Malfunction emissions limits for this facility are listed in Table 107.A and were relied upon by the Department to determine compfo:mce with applicable regulations. Navajo continues to comply with all applicable emission limits except for specific deviations as noted elsewhere i.n this document and events reported per 20.2.7 NMAC ------------ ---------------------'- -----~ Table 107,A: Allowable SSM and l\!falfundion Units, Activities, and Emission Limits1 i ~--- -------------------------------------------,- ---------------.,----------------------------~l---t~;P/PM10/PM2. ! r r~nit ... ---------------------------- _r::R;i0.~iP.t.l0.J?fEmissions : $$jlllJ::?851 I Emissions durinq SCR .99Y!U!iDJf!: ! SSM T-0737 : SSM Misc 1 _; Emissions from roof landing --- :: Emissions from cata! st handEn NQx co voe 5 so2 . _ pp-h-- c::::iiii :1 ppry pp~ !e"x. ....ie.h---r----iii:::::: -- pph ! tp ~-- , JQ:L j 1.2 20.2 2.~ ~......2.:.9 1 0.2______________ ?:13.~I 0.3 0.5 ------l- QJ 'I - J l~.:9.... __Q&...... ________________ ---L.... - -, [__::__ : [ -- -- -- 1.5 J <O.1 -- -- , SSM~RU3- J~~=,;~sRu!~;,;;;;;~;~d- r55=r~;;:;-=;;~~~- ~ <0.1 J_ =159.o ~<I 6] <~-: I I "Tl i l}!j z :0r- SSM T-OO?B ;e~i,f~:ons from roof landing and tank __ 0 - _ J 0 0 ACC Form Part 1 Permit# P051-R2 & R2Ml 0 01 Ver 4.1 02i25/2fH 5 .N..... I I __ _ .7 177 0----- -------2----------------' --------------------'--- - __ I _ j ----------------- . Page 35 of 144 01 EPA Inspection Report - Page 755 of 1969 Version 02,25J 5 I -- SSM T~0079 \ ;~!i!~~onsfrommon~:~ingandtank 1- . -- .. -- + 306.o i 4.6 I r----.-- i T-1225 . SSM }-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-................, ..............E.-.-.-.m.....i..s.-.-.s-.-.-.i-.-o.-.-.-.n...s-.-., ..f.r...o...m.......r..o....o...t....l.a...n....d...i..n...qw............................ SSM Fl-HEP- Temporary, portable flare for natural . ',','''',',',',',',',',',','--...,!,. .,- . . . . . . [ i 87.o____!'..... 2.8 .....1 t , , ,, , , ,. . IJJ!~~~dt:t::J!;' ::J:1!i_:_, ~--~=~:j:0:1 SSivJE!?L?Y?R Flares Ma!f Ca 1 . , I 1 ! J?~-~l i SM Misc 2 I t",L. SSMTanksMisc Emissions from venting SSM activity gases to Fl400, Fl-40'1,FL402, FL- 403, orFL,-404. . U. set and Ma!function Emissi9,r:i_f,,,,,,,,,..... ; Low-Emitting .Maintenance Activities sueh a.s de-inventorying small I equlpm~nt: cleari:1g piping a~sodated with ern1sswn urnts, and rnutme maintenance activities such as heat { <;!?hil:11:Z?!:Y\C(;li~: + 162.9 ....1.:UL I I I 1 I HU l 1?4~:Q,,,,.[ ?L9......'._ 10.0 J -- 10.0 i i I i i .........1Jl.._J____J?_7. 1__.l____..!:.? .....+ ! Stora_g_eJanks - - ,......... _ -"' _----~ 211.6 -- 21 .2 112.0 b' I I 1i 33. 1-1.:.2... .. J . 4 __J 14.9 :1.QJLJ .l -----4---............. ........~.::......J 10.0 ! i !. i I i .4 10.6 - -- J, - =..... __:::_ 0.4 0.1 .........L .. l ....!2:Z.--l-..01:.:.....j 0.1_1 2 h::~~'.~~~w11. ~tt~: I ;;;hedule mainlemmce or-;;;,;ii~~~tion o;;;;'.ScR rontrol9~tem. nAcT ;:; H:9851 shall~ u!,,;.i-;;;;;-NJ~ ~u,.;,e~ n~ lore than 0. 03 lb per MMBtu {LHV) on a hourly rn11ing 3-hour average basis at 3%) excess oxygen. Pound per hour and tons per year limits are based on the !MMBtu limits and were used to demonstrate compliance with the lbiMMBtu limits and the Ambient Air Quality Standards {iv\QS). Al07 Facility: Allowable Startup, Shutdown, & Maintenance (SSlVI) and Malfunction Emissions B. The authorization of emission limits for startup, shutdown, maintenance, and malfunction does not supersede the requirements to minimize emissions according to Conditions BlOLC and B107J\, Navajo complies with the conditions ofB10LC and Bl 07..A, Except for specific deviations as noted elsewhere in this document and events reported per 20.2-7 NMAC. !S'.! Continuous !S'.! Intennitient 0Ycs fu.7l N"" iS'.! Yell: 0No I "Tl z :r- 0 0 0 0 ACC Fom1 Part 1 Pennit ff P051-R2 & R2Ml 0 01 Ver 4. l 02125/2015 .N.... 0) Page 36 of 144 EPA Inspection Report - Page 756 of 1969 Version 02.25.15 r Al 07 Facility: Allowable Startup, Shutdown, & Maintenance (SSM) and Malfunction Emissions C. SSM Flaring and combustion Emissions ~ Continuous ~ Intermittent ! D Yes I ~ No ~Yes 0No Requirement: The pennittee shall comply with the flaring and combustion SSM NOx, co, voe, S02, TSP, PM10, PM2.s, and H2S emission limits at Table 107.A for the following SSM events: 1) SSM H-9851, Emissions during SCR downtime 2) SSM SRU-TGI, Emissions from SRU3 startup and shutdown 3) SSM FL-HEP-PORT, Temporary, portable flare for natural gas pipeline maintenance 4) SSM SRU2-TGI (H-0473), Emissions from SRU2 startup 1), 2), 3), 4), 5), and 6) Navajo obtains fuel gas analysis monthly from New Mexico Gas Company. Navajo continues to comply with these requirements except for specific deviations as noted elsewhere in this document and events reported per 20.2.7 NMAC. and shutdown 5) SSM Flare Cap, Emissions from venting SSM activity gases to FL-400, FL-401, FL-402, FL- 403, or FL-404 6) SSM Misc 2, Low-Emitting Maintenance Activities such as de-inventorying small equipment, cleaiing piping associated with emission units, and routine maintenance activities such as heat exchanger repair. I (NSR 0195M35, Condition A107.C and "Tl z revised) :r- 0 0 0 0 ACC form Part l Permit# P05 t-R2 & R2M1 0 01 Ver 4.1 02/25/2015 .N..... -..,J Page 37 of 144 EPA Inspection Report - Page 757 of 1969 Version 02,25, 15 Monitoring: The pennittee shall monlior all flaring and combustion due to routine and predictable startups, shutdowns, and scheduled maintenance events, This shall be accomplished by collecting all the SSM flaring and combustion infonnation ___spt:'.c;iP:s?~~n A107C Recordkeeping. Navajo Environmental Department keeps an up-todate events summary with emission units and pollutant. ~ Continuous ~ fote:rmithmt O Yes lKi'::7-.Jl l!'~<'o ~Yes 0No Record.keeping: The permittee shall D Continuous 0Yes ~Yes record the date, start and end times, and duration of every SSM flaring or ! combustion event The NOx, CO~ VOC, I 1 ' S02, TSP, ?Mm, and H2S emissions shall 1 I ~ Intermittent 0No 1 0No be calculated for each event based on the volume of gas sent to the .flare and the ] total sulfur content of the flared gas, Compliance with the hourly emission rates sha11 be demonstrated by calculating the hourly emission rates for each event and comparing the results to the hourly emission rate at Table 107,A, The annual emission rate shaU be I Navrtjo keeps records of SSM events, h_faintcnancc calculated as fi-Jllows: scheduling is based on engineering judgment and , operating experience, 1) To demonstrate comp1mnce during the first 12 months of monitoring, the pcrmittce shaU cafou]ate and sum the monthly cumulative total of NOx, CO, VOC, S02, TSP, PMrn, Plvhs, and H2S emissions; and 2) After the first J2 months of monitoring, the pen11ittee shall caktda.te and sum the total of NOx, CO, VOC, S02, TSP, PM10, I PM2,s, and H2S emissions on a "Tl z monthly ro1hng ]2 month basis, :0r- 3) The pennittee shall maintain all 0 0 0 ACC Form Part 1 Pennit # P051-R2 & R2M1 0 01 Ver4,l 02i25!2015 .N..... OJ Page 38 of 144 EPA Inspection Report - Page 758 of 1969 Version 02.25.15 records in accordance \:vith ,,~.,,,,-,,,,..... ..........._.,,,,... : ----. ~ - - -S-ec-tio-n -B1-09-. - - - - - - - - - 1 - - - - - - - - - - - - - - - . ........ ...j.......... ------------ +-- ........ j Reports required by Section B110 are submitted as ' Reporting: The pennittee shall report in necessary, except for specific deviations as noted D Continuous 0Yes [SJ Yes accordance with Section B 110. elsewhere in this document and events reported per [SJ intermittent ~k'.::-,1Nl 0 0No .......------------------1_2_0_._2_.7_N_T_M_A_C_'_.------------ + --------+--------1-------1 A107 Facility: Allowable Startl.rp, D Continuous I D Yes :8J Yes Shutdown, & Maintenance (SSM) and Malfunction Emissions [gl In.ter:mittent I c5'.l No 0No D. SSM VOC Emissions (Facility-\Vide, Navajo complies with the requirements listed in Non-Cornbustion Sources) table 107.A. RcquJrement: The permittee shall comply with the SSM VOC emission limit at Table 107.A. Monitoring: The pennittee shall monitor aU VOC emission activities due to routine and predictable startups, shutdowns, and scheduled maintenance events, This shaU be accomplished by collecting VOC emission calculation information for the following SSM VOC emission activities: l) SS?vI T-0737, Emissions from rooflanding 2) SSM T-0078, Emissions from roof landing and tank refilling 3) SSM T-0079, Emissions from rooflanding and tank refilling 4) SSM T-1225, Emissions from rooflanding 5) SSM Tmiks Miscellaneous , I ' Navajo complies with tllese requirements, except for specific deviations as noted elsewhere in this document and events reported per 20.2.7 NMAC. ! D Continuous 12:1 Intermittent 0Yes 12:!No 12:!Yes 0No ~No--- ...J.. I "Tl Re~o~d____k____e___ eping:The annual SSM VOC ~avajo ~omplie~ ":ith tllese requirements, ~xcept D Continuous D Yes I [gl Y 8 ,! z emrnswn rate shall be calculated as for specific devrnt10ns as noted elsewhere m tlus I :0r- fr,Ho:;ys: ........ --- . document and events reported per 20.2.7 NM~_:.' kSl Intermittent D N~ 0 0 0 ACC form Part 1 Permit# P05 l-R2 & R2Ml Page 39 of l44 0 01 Ver 4, l 02/25/2015 .N.... (!) EPA Inspection Report - Page 759 of 1969 Version 02.25.15 l) To demonstrate compliance during the first 12 months of monitoring the pennittee shall calculate and sum the monthly cumulative total of voe emissions; and 2) After the first 12 months of I monitoring the permittee shall J calculate and smn the total of 1 voe em1ss10ns on a monthly rolling 12 month basis, including the methodology and/or assumptions used in the calculation(s). The permittee shall keep records to demonstrate compliance in accordance with Condition B109C, except the requirement in B109.e(2) to record the start and end times of SSM events shall not apply to known quantities of voe emissions. 3) The permittee shall maintain all records in accordance with Section B 109. Reporting: The permitt.ee shall report in II ~avajo ~ompHe.s ':ith these requirement.s, except accordance with Section B] 1o. for specific deviat10ns as noted elsewhere in this document and events reported per 20.2.7 NMAC. D Continuous t8'.l Intermittent t8'.J Yes D No 0Yes r2J No I "Tl z :r- 0 0 0 0 ACC Forrn Part I Permit# P051-R2 & R2Ml 0 01 Ver 4.1 02/25/2015 N N 0 Page 40 of 144 EPA Inspection Report - Page 760 of 1969 Version 02.25.15 F Al 07 Facility: Allowahk Startup, 1 Shutdown, & Maintenance (SS1VI) aurl Malfunction Emissions ! ........... '1 ....................... ,,- - - - - , - - - - - - - - - - - . - . - - - - - - - - ~ D Contimums OYes rgJ Yes !;SJ Intermittent KJl 1'.Y LJ t~O 0No E. SSM Particulate Emissions (Unit SSM Misc 1) Navajo complies with these requirements, except for specific deviations as noted elsewhere in this document and events reported per 2(LL7 NMAC Requirement: The permittee shall minimize particulate emissions due to SSM events. e - - - - - - - - - ~ - - - - - - - - - - i - - - - - - - - - - - - - - - - - - " " 1 " " " " ' ' ' ' ....................... -!------ lVhmitoring: The permittee shall monitor D Continuous [SJ Yes all particulate emissions due to routine ,,,,,_ __ _ , 0Yes and predictable startups, shutdow'Tis, and scheduled maintenance events. For the , event t:n,e ofFCCU Catalyst Loading, the I maximum material usage shall not exceed ! 1 hr-duration, 1 loading event/yr; and Navajo compties with these requirements, except for specific deviations as noted elsewhere in this document and events reported per 202.71\1v1AC ['g] lnte:rndttent 0.No uK?ln"''o I 237,048 1b/event/vT. r~.........-------------------------:------------"'--------------------------------------------------------j ........................ ) Recorrlkeepmg: For each event, the 1 i pennlttee shall maintain records of the I J duration in hours, events per year, and I I material usage for the particulate matter I Catalyst loading data collected on a daily basis and emitting SSM event - FCCU Catalyst i maintained by the Navajo Process Engineering Loading, The annual material usage shall l Department be based on monthly rolling 12-month I totaL The permittee shall maintain all I D Continuous 0 Intermittent 0 Yes []No .....------ --------------,...._/ 0Yes 0No 1r-e-c-o-r-d-s-i-n-a-c-c-o-r-d-a-n-c-e-w--it-h-1Se-c-t-io-n--B-1-0-9-.---------------------- ................,,-,_.,,,, ---------- Reporting: The permittee sha11 report in Navajo complies with these requirements, except D Continuous !Z] Yes 0Yes for specific deviations as noted elsewhere in this accordance with Section B1Hl document and events reported per 2(L2.7 :NlvlAC. ['g] lnte:r.m.Hteat 0.No ['g] No -------------------------"'-------------------------------"'-----------------------1 .............................,,-----~----------' I "Tl z :r- 0 0 0 0 ACC Form Part l Pennit # P05 l-R2 & R2M 1 0 01 Ver 4. l 02/2.5/2015 N .N.... Page 4 l of ]44 EPA Inspection Report - Page 761 of 1969 Version 02.25.15 I A.107 Facility: Allowable Startup, Slmtdown, & JViainteuance (SM) and 1 Malfunction .Emissions l :F. SSM and Malfunction Flaring Emissions (SSM flare Cap and Flares MalfCap) . . " Reqm.rement: TI1e penmttee shall not exceed the pound per hour (pph) and ton I I l I Navajo complies with these requirements, except I for specific deviations as noted elsewhere in this j document and events reported per 202.7 NlV!:AC. D Continuous ~ Intermittent j OYes I ~No I I ~Yes 0No per year (tpy) emission limits in Table ! A107.A and shall demonstrate 'j compliance with these limits by calculating and summanzmg these , emrnswn rates as required in ! recordkec2.h.~1~g"".'"'"""""""""""""'"""'''''''"'"'''""''''''""""''''- """"""l- Monitoring: ! A ?as Jfo;,v!neter and flow totalizer, I eqmpped ,v1th a chart recorder or ----------------------------------------------------------------- I D Continuous I ~ Yes I rgi Intermittent I D No 0Ye !zJ No ,,,,,,,,,,,,, .... electronic data logger, shal1 be installed in the Hare line to measure and record the total standard cubic feet (scf) of all gas (process gas, purge gas, pilot gas, and supplemental fuel gas) sent to the flare during each hour and each month. . . , Navajo complies w1th these requirements, except ! I The permittee shaH measure the H2S for sped fie deviations as noted elsewhere in this content, the total sulfur content, the VOC document and events reported per 202,7 NMAC content, and the heating value (Btu/scf) of the gas sent to the flare for combustion. H2S shall be measured at least once every 24-hours on each of the inlet gas types/streams using a stain tube of the appropriate size range or an inHne H2S I monitor. The total sulfur content, VOC "Tl z content, and heating value (Btu/set) ofthe :0r- ~ na t- ur- al ~ gas~ se- nt to -- t- he-f- la r- e - sh- al l-b~ e 0 0 0 ACC Fonn Part l Penn.it# P051-R2 & R2M1 0 01 Ver 4,1 02/25/2015 N N N u.-.-1.-.-.-.-. .-.-.-.-.-.-.-.-.-.-.-.............................-..~.-...u~l -'-'-'-'-'-'-''1'._ Page 42 of 144 j EPA Inspection Report - Page 762 of 1969 Version 02.25J5 r---------------------------------------- measured at least once annually with an extended gas analysis, The flow meter and fiow totalizer sha1] be operated, caHbrated, and maintained as specified by the manufacturer and as necessary to ensure correct and accurate readings. If used, the inline monitor sha11 be operated, calibrated, and maintained as specified by the manufacturer and as necessary to ensure correct and accurate readings, Reco:rdkeeping: The fol1owing records shall be kept: stain tube and/or inhne H2S measurements ammal extended gas analysis both the hourly and monthly volume (sd) of gas sent to the flare D Continuous ~ Intermittent 0Yes ~No ~Yes 0No Each month, the pennittee shall record and summarize in a table fom1at the following. H2S and the total sulfur content Navajo complies with these requirements, except for specific deviations as noted elsewhere in this percent VOC content document and events reported per 202.7 NMAC gas heating va1ue (Btu/set) the maximum hourly gas fiow rate (scfYhr) that occurred during the month each hourly gas fimv rate (scf/hr) for any hour(s} that exceeded any pph emission limit during the mooth 1 the total month's scf of gas sent to I "Tl the flare z :r- I the monthly rolling 12-month total . ---- 0 0 0 0 ACC form Part l Pennit # P05 l. --R2 & R2M1 0 01 Ver4,t 02/25/2015 N N (,) Page 43 of 144 EPA Inspection Report - Page 763 of 1969 Version 02.25,15 of gas sent to each flare (sc:1yr) Each month, the permittee shall record all I routine and predictable startups, shutdowns, and scheduled maintenance events and shall also meet the recordkeeping requirements in General Condition B109 of this perrnit, except the requirement to record the start and end times of SSM events shall not apply, Records of flm:vineter, totalizer, and inline monitor certifications, calibrations, documentation of the manufacturer's recommended calibration / maintenance schedule, breakdowns, reasons for the breakdown, and corrective actions taken shall be maintained. Each month, to demonstrate compHance with both the SS?vf and malfunction emission limits, the permlttee shall calculate and summmize the maximum pph emission rate, any pph emission rate exceeding the permitted limits, and the mont11ly rolling 12-month total ton per year emission rates of NOx, CO, voe, S02, and H2S for both SSM and malfunction events, using the folkn:ving infbrmafam: the H2S content, total sulfor content, VOC content, and the gas heating va1ue (MMBtu/scf) from the most recent H2S measurements and gas analyses 1 @ the emission factors used to 1 I "Tl calculate NOx and CO z @ the maximum hourly gas flow rate :r- 0 0 0 0 ACC Form Part 1 Permit# .P051-R2 & R2M1 0 01 Ver 4. 1 02125/2015 N N .i:,,. Page 44 of 144 EPA Inspection Report - Page 764 of 1969 Version 02.25.15 ' (scft1rr) ..........- ..........-. ................... ~! m each hourly gas flow rate (scf!lrr) for any hour(s) that exceeded any pph emission limit during the I month, including the dates and times of these occurrences the monthly rnHing 12-month total ofgas sent to the flare (sdJyr) For each event, the permittee shaU record whether the emissions are due to SSM and/or malfunction, Jf the emissions arc due to malfunction} the permlttee shall indicate whether the emissions resulting from the event are included in the amount allowed by this permit's malfunction limit or whether the event is reported under ~ 20.2,,,,..,...7... NlVIAC, ,,,,,,,,,......,,-,,_-.,~.~.-----~ ,,,,._,,,,,..,..,,............,,,,,,,,,,,,,,,,,,_ _ _ _ _ _ _ _ _ _- 1 - - - - - - - - 1 - - - - - - - - + - - - - - - - Navajo complies with these requirements, Navajo D Continuous 0Yes [SJ Yes Reporting: The permittec sha11 report complies with these requirements, except frJr according to Condition B110. specific deviations as noted elsewhere in this 2?J Intermittent [81 No 0No i--- Al 08 Facility: Hours of Operation ~ document and events reported per 202.7 N1vLAC I D Conthl.uons +------ t8'.) Yes ----+-------i 0Yes A. This facility is authorized for continuous - operation. . Monitoring, I No requi.rement_ recordkeepmg, and reportmg am not required to demonstrate compliance with continuous hours of operation, A109 Facmty: Reporting Schedules 1 [81 Intermittent 0No [81 No D Continuous kS] Yes 0Yes A. A Semi-i\.nnual Report of monitoring I Navajo submitted the requested monitoring reports !8J Intermittent 0No [g] No activities is due within 45 days following as follows: the end of every 6-month reporting , period, TI1e six month reporting periods ! 10/11/2018 04/11/2019 : ! l ! I start on September 1st and lVlarc.h ] st of "Tl z each year, :r- 0 0 0 0 ACC form Part J Permit# P051-R2 & R2Ml 0 01 Ver4.102/25/2015 N N 01 Page 45 of 144 EPA Inspection Report - Page 765 of 1969 Version 02.25.15 ' A109 Facility: Reporting Schedules D Continuous ............................- r , , - - - - - - - - - ~ ~Yes OYes B. The Almual Compliance Certification Navajo submitted the requested compliance Report is due within 30 days of the end of certification repmt as follows: every J2-month reporting period, The 12- 09/27/20]8 month reporting period starts on J September ].t of each ~ar.~----------------------------------------- -----------------------Al09 FaciHty: Reporting Schedules ~ intermittent 0No D Continuous 0Yes ~No I l 1 [gJ Yes C ln addition to the reports required by the appHcab1e NSPS, NESHAP and MACT Subparts (including any voluntary programs referencing NSPS, NESHAP, or MACT Subparts) and by the applicable parts of 202 NMAC, the reporting required by the Consent Decree shal1 be subrnitted to the Department The reports shall be submitted to the Air Qua11ty Bureau within forty five (45) days ofthe en<l of each calendar quarteL If any reports indicate potential non-compliance with the terms of this permit, the Bureau may impose a more frequent reporting time-frame, TI1e Department shall handle The Department has not requested more frequent reporting time-frames. ~ Intermittent ~No 0No any confidential information in accordance vvith the provisfons of 1 A109 Facility: Reporting Schedules 20.2,Ll 15 Nl\tL,\C I I D Continu~~~:--,,,+----------- I t2:) Yes 1 ~ Intermittent I 0No ------------ Oves 0No D. Reporting required by the Consent Navajo submitted the Annual NOx Control Decree {not an exhaustive listing) Technology report as follows: (]) The permittee shaU :notify , 1212712018 : ., i ' the Department s 1 I "Tl Enforcement Section, Air z l :r- "'-------------------------------..... _Qi:iali!z___~~I~~:!jQ_ \:~.:,,;':.:.:ti:::n'.:ff;gt_L...,__________________..........__ 0 0 0 0 ACC Fonn Part 1 Permit# P051-R2 & R2M l 0 01 Ver4J 02/25/2015 N N 0) .................,,,,,,,-,_,,,,,,, - - - - " ' - - - - - Page 46 of 144 EPA Inspection Report - Page 766 of 1969 Version 02.25.15 of the annua1 progress of installation of NOx Control Technology required by Paragraph 16 of the Consent Decree, The report shall be submitted to the EPA and the NMED on or before December 31st of each calendar year commencing with the year 2002, (CD 9!16,E) (2) No later than forty-five (45) days following the end of an AG Flaring or TG Incident, the pennittee shall submit to EPA and the NMED a report that sets forth the items detailed in the Consent Decree. (CD 1f20, CD9!21) Al 10 Facility: Fuel and Fud Sulfur Requirements (as Required} A. Fuel, Fuel Sulfur, and NSPS J, Ja Sulfur Requirements (See Tables 103.E, H, I, & K, Summary of Applicable , Requirements) 1 Refinery fuel gas is con~inously monitored for H2S 1, content on a 3-hour rollmg average, Exceedances Requ~~eme.nt: (NS~ Ol95M35, 'I' are ~~ported on N:vajds Subpart J and Subpart Ja Cond1t1011 At tO,A and revrned) semiannual report~, !ZI Continuous !ZI Intermittent D Yes l'8:l No l'8:l Yes 0No (1) To comply with NSPS Subpart J, I "Tl NSPS Subpart Ja, and the PSD BACT z requirements in Section l 06, the :0r- 0 perrnittee s_l:..~I!_____j;~~!.<i:U.,........?.~E~rate and 0 0 ACC Fom1 Part 1 Permit d P051-R2 & R2M1 0 01 Ver 4.1 02/25/2015 N N -..,J ............... --------------- .~_ _ _ _ _.....____ _ _ _ __,, Page 47 of! 44 EPA Inspection Report - Page 767 of 1969 Version 0225. 15 maintain a continuous monitoring system (CMS) to continuously measure and record either the hydrogen sulfide (H2S) in the refinery fuel gas streams being bumed in the Heaters and Boilers or the concentration of sulfur dioxide emissions to the atmosphere, ----------------------------------------------------~,-----------~ (2) All stationary combustion equipment shall be fired with NSPS quality fuel gas with a maximum H2S content of 0, 1 grains/dscf (approx, 162 ppmv), based on a hourly rolling 3-hour average, (3) All stationary combustion equipment shall not combusl gas wlih an annual average sulfur content exceeding 60 ppmv (approx. 0.f)37 grains) as a daily roiling 365-day average, (4) AH stationary cornbustion equipment shaU be affected facilities, as defined in NSPS 40 CFR Part 60, Subparts A and J I or Ja, if refinery-produced fuel gas is combusted in the heaters and boilers, and shall comply with all applicable requirements of NSPS Subparts A and J orJa. {See Table 103.E, Summary of Applicable Requirements) Monitoring: D Continuous l2;J Yes OYes (1) The permittee shall install, certify, l2;J Intermittent D No lzj No I calibrate, maintain and operate a fuel gas l) CMS has been installed and is certified, "Tl calibrated and maintained, z continuous monitoring system (CMS) at :0r- i....-.t--h----e---f---u----e----l----g----a----s----m-------i--x------d-- rum outlet in accordance ! 2) CMS mmual RATAs were completed as follows: I L,,,,,,,,____________________________________________, - , - - - - - - - - " 0 0 0 ACC Form Part l Permit# P051--R2 & R2MJ. Page 48 of 144 0 01 Ver 4.1 02i25i2015 N N OJ EPA Inspection Report - Page 768 of 1969 Version 02.25.15 with the requirements of 40 CFR 60.11, 60,13, and Part 60 Appendix A, and the applicable perfom1ance specification of 40 CFR Part 60 Appendices Band F. (2) The follmving CMS shall be certified initially and recertified annually: * D-0019 Low Pressure Fuel Gas H2S C:tv1S D~0770 High Pressure Fuel Gas H2S CMS D~OO l 9 Low Pressure Fuel Gas H2S 3/07/2019 D-0770 High Pressure Fuel Gas H2S 3/07/2019 3) The CCR stabilizer off gas, the H2 recycle gas and the CCR feed streams are analyzed a minimium of quarterly. (3) As required by the EPA-approvable alternative monitoring procedure (/,.MP), CCR off-gas streams that enter the refinery fuel gas system downstream of the H2S CMS shall be monitored quarterly for H2S using gas detector tubes or an equivalent method as follows: (a) CCR stabilizer off gas stream, (b) H2 recycle gas stream, and c) CCR teed stream. i....................... ........................ --------------- ---------- Record.keeping: The pem1ittee shall comply with the applicable record.keeping requirements of 40 CFR 60, Subparts A, .......4 l'2J Co:nd:num:rn ~ Yes ~ Intermittent D No 0Yes ~No J, and Ja. l 1) Fuel records are maintained in PL (1) Records of the quantity of the refinery fuel gas and the monthly average heating value of the refinery fuel gas. This is used to demonstrate 2) Repair, maintenance, and calibration records are maintained by Navajo Instrument and Electricai Department I compliance with lb/mmBTU and 1b!11r limits shown in Table 106.A. (permit limit) , 3) CCR off-gas stream analysis records are j maintained in the Navajo Environmental I (2) Records ofrepairs, maintenance, and DepartmentFilcs(REEART.3JD5.A). "Tl z cahbrations performed for the :0r- instruments that measure :fiow or 0 0 0 ACC fonn Part 1 Pennit # P051-R2 & R2Ml 0 01 Ver 4, 1 02/25/2015 N N (!) 1 i - 1 ~.Ii Page 49 of 144 EPA Inspection Report - Page 769 of 1969 Version 02.25J5 concentration for an applicable pennit limit shall be kept. Examples include, but are not limited to, CMS, acid gas flmv meters, and fuel gas fiow meters. (40 CFR 60, Appendix F) (3) Records shall be kept of Alternative Monitoring Plan (Al.\,1P) lhS analyses of the CCR off-gas streams that enter the refinery fuel gas system downstream of the fuel gas H2S CMS, (NSPS J or Ja) Reporting: The pcnnittee shaH comply Reports required by Subpart A are submitted D Continuous !:8J Yes D Yes with the applicable reporting semimmuaHy. Reports required by Subparts J, Ja, requirements of 40 CFR 60, Subparts A, [SJ Intermittent D No r8:J No and Section Bl 10 are submitted as necessary. . ' J. , and fao, and Section B 110, """"""''' ...............................,,, '"" """""i-- l A111 Facility: 2fL2.36 NlV[AC D Continuous 0 Yes \ D Yes A. Facility: 20.236 NMAC \Z1 Intermittent I D No ~No Requirement: 20.236 NMAC (Petroleum Refinery - Sulfur, 11/30/95) applies to the refinery as a \vhok Quarterly refinery-wide suffur balance reports shall be filed in accordance with 20.236J 13 NMAC AH fiarcs and stacks Navajo Refinery is no longer affected by 20.236 NJ\1AC. This rule was repealed on February 15, 2016< shall meet the applicable height requirements of 20.236. 114 NMAC as demonstrated through air dispersion modeling done at the time of unit installation. (NSR 0195M35, Condition A11 LA} . ""'""- """" """+----------, M?nitori.ng: Quarterly monitoring of Navaj~ R~!i~cry is no longer affected by 20.2<36 D Continuous !:8J Yes OYes rdmery-,vide sulfur balance< NMAL l hrs mle was repealed on February 15, 2016. r8:J fotermittent D No r8'.] No ! """"""'"-l -------.-.-.-.-.-.-.-.-.. """""""'".. - - - - - - - - - - - + - - - - - - - i Recordkccping: The per I mittee shaH_, Navajo Refinery is no longer affected by 20.236 D Continuous r8:] Yes 0Yes "Tl keep record ofa copy ofthe FaciHly-Wide NMAC This rule was repealed on Febrnary 1.5, z Sulfur Balance Report and the actual 2016< ~ Intermittent D No l:2'] No :r- 0 0 0 0 ACC Fonn Part l Permit# P051-R2 & R2M1 Page 50 of !44 0 01 Ver4.l 02i25!2015 N (,) 0 EPA Inspection Report - Page 770 of 1969 Version 02.25.15 hei~t of flares and stacks. "-.-.-.-.-,, .-.-.-.-u, ,uuu.-.-uuuuuuuu<u.-.-uuuucccccc "-Uuuu.-u.-.-.- .-.-.-.-.-.-.-.-. ---------- ----------------------~~ ----------------------------------- -- . , . , Reporting: The permittee shall report in accordance with 20236.11 JA N?vi.A.C Navajo Refinery is no longer affected by 202.36 :i\ilVfAC. This rule was repealed on February 15, 2016. D Continuous 2?J Intermittent ~~,;-:;,:.::. :S":".. ~~-~A .. ~$~~'''!i',"""$".t:-:..;$,s..,~ s indicating loss of flame g order. D Continuous [Zl Intermittent ................. rgj Yt$ 0No [Zl Yes 0No 0Yes ...., .....................-.- uu.-.-uu.-.- rz:l No ---- -nu D Yes l'SJ No ;enerator exhaust is for CO, to mercaptan and H2S emissions from the refinery, Section 200,C applies to FL- 0400, FL-0401) FL-0402, FL-0403) and FL-0404 and requires an alarm in good working order to signal non-combustion of the gas. g regenerator is tested annually tor l'M. NavaJo has submitted an alternative monitoring plan (MiP) to comply with the FCC opacity monitoring requirement because the FCCU has a wet scrubber which prevents continuous opacity monitoring. Under the J\lvIP, opacity is monitored monthly using 40 CFR 60 Appendix A Method 9. I I I I (2) Section 201 .A (CO)) applies to the refinery's FCC regenerator stack The owner or operator of an existfog petro1eum processing facility shall not 4) There are no process vents to the atmosphere, so !he refinery is not expected to emit ammonia. i\:ny trace ammonia emissions are expected to comply with the 25-ppm limit permit, cause) suffer or allow carbon monoxide emissions to the atmosphere from a catalyst cracking recirculation or regeneration unit in excess of20,000 ppm by volume in the um:l.iluted effluent gas stream or streams. 5) Navajo continues to comply with the appUcable requirements ofNSPS Subpart QQQ at refinery oil/water seperators, The oil/water separator is inspected at least semi-annually, and the carbon vapor control is tested at least monthly. 6) Blowdowns are accomplished by venting to (3) Section 202,C(l) (PM); The mvncr or I fiares that are designed to be operated smokekssly. I operator of a new petroleum processing fodl.ity sh~H not penn.it) ca~1s~; suffer or allow particulate matter cmrnsmns to the Navajo Refi?ery i~ ~o,long~r affected by 202.37 NT\1AC This rule wa:, repealed on September 12, I atmosphere from the cata1ytic. cracking 1 2016- "Tl z rcgenerator vessel in excess of 1.0 :0r- Kg/1000 KgJL0 ____1b/1000____1b)....._ot_~_co_k_e__,___ _ _ _ _ _ _ _ _ _ _ _ _ _ ___.__ _ _ _. 0 0 0 ACC Form Pa:rl 1 Permit # P051-R2 & R2M l 0 01 Ver4J 02/25/2015 N (,) ..... Page 51 of 144 EPA Inspection Report - Page 771 of 1969 Version 02.2:US burnoff or visible emrnswns of thirty percent (30%) opacity or greater except for one six-minute average opacity reading in any one-hour period, (4) Section 203 (Ammonia, undHuted emissions :S 25 ppmv) applies to aH emission points ofthe refinery. The owner or operator of a petroleum processing facility shall not pen11lt, cause, suffer or allow ammonia emissions to the I atmosphere fa excess of 25 ppm by ,volume in the undiluted effluent gas Istream or streams. (5) Section 204 (Hydrocarbon Separation Facility) applies to all oil/water separators at the refinerv~ . Compliance with this II condition is met by complying with the I applicable NSPS Subpart QQQ requirements, (6) Section 205 (Facilities - Storage - Handling - Pumping - Blowdown System) app1ies to certain of the following: storage tanks for organic compounds, loading and unloading of organfo compounds, seals on pumps and compressors, and disposal (Haring) of hydrocarbon gases. Tue permittec shal1 not permit, cause, suffer or a11mv the operation of a b1owdown system without disposing of the gases in a manner which wfl l minimize hydrocarbon emission to the atmosphere. If combustion is the I means of disposal, it shall be by: "Tl z smokeless fiare; or any other method that :0r- is equa]Jy effective to achieve complete 0 0 0 ACC Form Part 1 Permit # P05 l ..R2 & R2M l 0 01 Vcr4J 02i25/2015 N (,) N cccccccccc . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ., ~ , . , , , , . , , , , , ._ _. , , _ _ __ _ _ _ _. . . . . . . . ) ._ _ _ _ _ _~_ _ _ _ __ _ ) Page 52 of 144 EPA Inspection Report - Page 772 of 1969 Version 0225. 1.5 lVfonitoriug: (1) For Units FL-0400, FL-0401, FL0402, FL-0403, and FL-0404: The permittee shall install and maintain a flare pilot flame monitoring system. (20237.200.A.2 NMAC) (2) A CO CMS has been installed to monitoring the emissions from the FCC (3) The annual EPA Method 9 Opacity Test and annual Stack test 011 Unit FCC (lb/hr PM emissions) and the calculated Coke burn rate v,1iU be used for the annual detennination of pounds of PJVI per l 000 pounds of Coke burned, (4) None (5) No additional monitoring since compliance is met by complying with the applicable NSPS Subpart QQQ requirements. See other conditions of this pennit for applicable NSPS or :tviACT requirements. (6) Compliance is demonstrated through NSPS K, NSPS Ka, NSPS Kb, or MACT CC for Tanks; through MACT CC for Loading Racks; through NSPS OGG, NSPS GGGa or MACT CC for Pumps and Compressors; and through NSPS Suh ,art A for Blowdowns. Recordkec_ping: 1) AJ.1 flares have alarms indicating loss of flame that are in good working order, rg) Continuous IZl Intermittent 2) The FCC catalyst regenerator exhaust is continously monitored for CO. 3) The catalytic cracking regenerator is tested annually for PM. Navajo has submitted ,m alternative monitoring plan (AMP) to comply with the FCC opacity monitoring requirement because the FCCU has a wet scrubber which prevents continuous opacity monitoring, Under the Alv:IP, opacity is monitored monthly using 40 CFR 60 Appendix A Method 9. 4) Not monitoring require:menL 5) Navajo continues to comply with all requirements except for specific deviations as noted elsewhere in this document 6) Navajo continues to comply with a11 applicable requirements except for deviations previously reported. or identified at the end of this report Navajo Refi:1my is no longer affected by 20.2.37 ~IAC. This rule was repealed on September 12, I "'016 I 1) Records are mai;;t;;;;fi:n PL --------------- [8'J Continuous iZl Ye~ 0No IZl Yes 0Yes !ZJ No i ; I I j D Yes ", I (1) Pilot flame monitoring records 2) Records are maintained in Pi. , IZl Intermittent D No IZl No "Tl z :r- l (2) CO CMS measurements ! 3) Stack tesl.1.:gpgrts__are_maintained by_t_he_N_m_,a,,,__J_o _,,__ _ _ _ ___.__ _ _ _ ________,_ _ _ _ __ 0 0 0 0 ACC Fonn Part 1 Pennit # P051-R2 & R2Ml Page 53 of 144 0 01 Ver4.1 02/25/2015 N (,) (,) EPA Inspection Report - Page 773 of 1969 Version 0225.15 (3) Copy of annual coke bum rate detennination, stack test report, and opacity test report (4) None (5) Applicable NSPS Subpart QQQ requirements (6) Applicable NSPS K, NSPS Ka, NSPS Kb, or MA.CT CC for Tanks; through MA.CT CC for Loading Racks; through NSPS GGG, NSPS GGGa or IviACT CC for Pumps and Compressors; and through NSP_S Subpart A for Blowdowns reqmrements Reporting: The permittee shall report in accordance with applicable NSPS or MACT requirements and Section B110. A113 f.'adlity: 20.238 NMAC A, 20.2.38 1\'l'IAC Environmental Department 4) No record.keeping requirement 5) NSPS QQQ reports are maintained by the Navajo Environmental Department 6) NSPS K, NSPS Ka, NSPS Kb, NSPS GGGa, NSPS J, NSPS fa, and MACT CC reports are maintained by the Navajo Environmental Department Navajo Refi~ery is no longer affected by 20.2.37 ~AC. This rule was repealed on September 12, ,.,Ol6. NSPS J, Ja, GGGa, QQQ, and MACT CC reports are submitted semiannually. Navajo Refinery is no longer affected by 20.2.37 Nrv1AC. This rnlc was repealed on September 12, 2016. i I 1 D Continuous t8J Intermittent D Continuous ~ Inter:mittent [2;J Yes 0No I 2l Yes I D No 0Yes [gj No 0Yes ~No Requirement: 202.38 NMAC (Hydrocarbon Storage Facilities, 1l/30/95) applies to the refinery as follows: 1) The .Artesia Refinery includes storage vessels that store hydrocarbons containing hydrogen sulfide. The vessels comply with the requirements of20.2.38.109 by using submerged fiIL L Section 109 (Tank: Storage Associated with Petroleum Production or Processing Facility [Sour Hydrocarbon Liquids]) applies to the 1oading and storing of hydrocarbons containing H2S, 2) and 3) The vessels comply with the requirements of 20.2.38.110 and 113 by using internal or external floating roofs ,vith the required seals. I "Tl z 2, Section 110 (Tank Battery or Storage :0r- Facility - Within Muni5:i1~,~JI!:(,,__1?2.YE.., ____________________ ,,,,,,,,, 0 0 0 ACC Fonn Part 1 Permit# P051-R2 & R2M l 0 01 Ver4.1 02/25i2015 N (,) .i:,,. ,,,,,,,,,,,,, .................... , Page 54 of 144 EPA Inspection Report - Page 774 of 1969 Version 0225.15 Hydrocarbon Liquids]} applies to certain tanks storing sour hydrocarbon liquids ,vhose vapors contain ~24 ppm H2S. I I 3. Section 113 (New Tank Battery and the Pecos~Pe1111lan Interstate Air Quality Control Region [Sour Hydrocarbon Liquids]) applies to certain tanks storing sour hydrocarbon liquids whose vapors I contain ::::24 ppm H2S, (NSR 0195M35, Condition AJ13J\) Monitoring: 1, None 2, and 3. Demonstrated through NSPS K, Ka, Kb, and MACT CC floating roof seal inspection, 2) and 3) Navajo inspection Department pcrfonns seal inspections and maintains those records. D Co:ntimwus [gJ Intermittent :g].yes 0No 0Yes [gJ No Record.keeping: D Continuous !gj Yes 0Yes 1, Records of Tank design showing inlet piping connections. 2, and 3. No additional requirements other than app1foab1e requirements of NSPS and rv1ACT. 1) Records of tank designs are maintained in the Navajo Engineering Library, Reports required by B 110 are submitted as necessary. iz:l Intermittent 0No I lz:l No Reporting: The pcrmittcc sha11 report in Reports required by B 11 Oare submitted as ! D Continuous IZJ Yes 0Ycs accordance with Section Bl 10. ~ , i AH8 Facility: MACT Subpart UUTJ necessarv, K7l 1 t ''" t k'.\l n ermi.ten lSJ Continuous 0No 1ZJ Yes ---~~- lz:l No D Yes A. 40 CFR 63, Subpart UUU FCC, FUG70-CCR, SRUs 1, 2,an<l 3 For the FCC, Navajo monitors and records the daily average coke burn rate and of the continuously monitored CO emissions. For the lz:l Intermittent 0No lz:l No CCR, Navajo monitors and records the weekly Requirement: The permittee shall average ChlorSorb catalyst inlet and outlet chloride comply with all applicable requirements content, the CltlorSorb inlet and outlet of 40 CFR 63, Subpart UUU, National temperatures, and the CCR firebox temperature. I Emission Standards for Hazardous Afr For the SRUs, Navajo monitors and records the "Tl z Pollutants for Petroleum Refineries: S02 concentration frmn the tail gas incinerators. :0r- Cata1ytic ....,Cracking Units, Cataly1ic j 0 0 0 ACC FonnPart 1 Pem:rit #PD51-R2 & R2Ml 0 01 Ver4J 02/25/2015 N (,) 01 Page 55 of 144 EPA Inspection Report - Page 775 of 1969 Version 02.25-15 ~ Reforming Units, and Sulfur Recovery Units, for all affected sources shmvn in Tables 103H&I attached. (6301560 and 6.,....,], 15'7' 0.), ?.-fonitoring: The perrnittee shall comply with the applicable monitoring and testing requirements of 40 GFR 63, Subpart lJUU. Record.keeping: The permittee shaU comply \Vith the applicable recordkeeping requirements of 40 CFR 63, Subpart UUU. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 63, Subpart UUUo Al 19 40 CFR. 61 Subpart FF. Nation.al Enlission Standard for Benzene vVaste Operations uuu,.-.-.-.---.-.-.-.- =nN For the FCC, Navajo monitors and records the daily average coke bum rate and of the continuously monitored CO emissions. For the CCR, Navajo monitors and records the weekly average ChlorSorb catalyst in1et and outlet chloride content, the ChlorSorb inlet and outlet temperatures, and the CCR firebox temperature. For the SR.Us, Navajo monitors and records the S02 concentration from the tail gas incinerators. Process records arc maintained in Pi. Reports required. by Subpart UUU were submitted semiannuaUy as fr1llows: 1/30/2019 7/30/2019 t8J Continuous :8] lnic:rmJtteut [8:J Contl.nuou.s [Sl Intermittent D Continuous !Zl Intermittent " " " " " " -~~~~. .~ h U N D Continuous k6J Intermittent - - -..-; !Zl Yes [ I I Ii ~ - - - - - - ~ . c c c u u . - . - . - , 0Yes 0No :gj No !Zl Yes 0.No -- ... -~~~~~- !Zl Yes 0.No [8;lYes 0.No 0Yes !Zl No OYes !Zl No 0Yes r::::711,x k:::::J .t,O A. 40 CFR 61 Subpart FF, National Emission Standard for Benzene Waste The refinery complies with the applicable Operations (Units subject in Table 103.C requirements of N'ESHAP Subpart FE Because &G) the refinery's total annual benzene (TAB) quantity is less than 10 rv1g/yT, none of the standards in this Requirement: The pe1111ittee shall regulation apply, comply with an applicable requirements of 40 CFR 61, Subpart FF, National Emission Standard for Benzene Waste Operations for the affected sources in I "Tl Tables 103.C, G. z :r- 0 0 1\!fonitoring: The permittee shall comply I The refinery complies \.vith the applicable 0 0 ACC Form Part 1 Pem1it # P05 l~R2 & R2M1 0 01 Ver 4. 1 02i25/2015 N (,) 0) D Continuous [gJ Yes 0Yes Page 56 of144 EPA Inspection Report - Page 776 of 1969 Version 02.25.15 with the applicable monitoring and testing requirements of 40 CFR 61, requirements ofNESHAP Subpart FF. Because the refinery's total annual benzene (TAB) quantity L8J Intermittent 0No Subpart FF. is less than 10 Mg/yr, none of the standards in this ~,nnnnn..nn.. . - - cuuo" regulation a p _ p ! ~ -~~'< ----------------------------------------------------------~ - nn~ Recordkeeping: The pennittee shall D Continuous L8J Yes comply with the applicable recordkeeping requirements of 40 CFR Records are maintained by Navajo Environmental Department. [XI .Intermittent 0No 61.356. L8J No ! 0Yes [XI No I "Tl z :r- 0 0 0 0 ACC Form Part 1 Permit# P051-R2 & R2Ml 0 01 Ver 4.1 02/25/2015 N (,) -..,J Page 57 of 144 EPA Inspection Report - Page 777 of 1969 Vcrnkm 02,25. 15 Re, po.rtino~: The p erm, ittee shall comp, ly \v1th the apphcable rcportmg rc~qm,rements of4ro,C,FR611,j"..,s;,;:7, ~""""""""""""""""" A201 Engines NavaJ,o :mbm1'tted the annua1T.~~n report. 03128120 19 ',. --=~NN~NNNN D Conti.mums l'v'l. , V\llntenmtte:nt D Conti.nuous ~ Yes D No [SJ Yes D Ye1. R7l , V\lNo j --------------- 1 I D Yes A. Maintenance and Repair Ivfonitoring [gj Intermittent D No I [SJ No (Units G-0100, G-0101, V-0543, V-0545, V-0546,E-8010,E-0600\V,E-0601A1, E- 0602E, E-0603, and E-0901; Units G- 0100, G-0101, V-0543, V-0545, V-0546, E-8010, E-0600\V, E-0601M, E-0602E, E-0603, and E-0901) Navajo complies withMACT Subpart ZZZZ. Unit M-8010 was installed 1li04/2013. The engine was operated a total 5J hours during the Requirement: These units are subject to l reporting period, Title V since they are subject to NSPS and/or MACT requirements. No emission limits were established since their emissions are small. The pennittee shall ensure these units are properly maintained and repaired. Monitoring: Maintenance and repair D Continmnrn I ~ Y($ 0Ycs shall meet the minimum manufacturer's or pern1itteds recommended maintenance lZJ Intermittent I O No 25] No schedule, Activities that involve maintenance, adjustment, replacement, or repair of functional components with . the potential to affect the operation of an Navajo comphes with MACT Subpart ZZZZ, emfasion unit shaU be doctrrnented as 1) and 2) Unit M-8010 operating hours are 1. they occur for the following events: (1) Routine maintenance that takes a unit out of service for more than two hours dwing any hventy-four hour monitored. the u:nit was not taken out of service greater then t,vo hours in any twenty-four hour period, peri.od. :r-I (2) Unscheduled repairs that require a "Tl z unit to be taken out of service for more than two hours in anv twentv-four h o u r 0 - - - - - - - - ~ "- c ~ c c c ;:;..,.ccccccccccccccc-----;------------i. ~~ uu; .. u ... uu~=n 0 0 0 ACC Form Part I f'ermit # P051-R2 & R2Ml 0 01 Ver4,l 02/25/2015 N (,) OJ .._ . ., ,. . .. , . , . , . , . , , . . , Page 58 of 144 EPA Inspection Report - Page 778 of 1969 Version 0225.15 period. "~--r~~""""""'- ------------------------~~~~~~~~nu Reco:rdkeeping: The pcrmittee shall maintain records in accordance with Navajo complies with MACT Subpart ZZZZ. Section B109, including records of maintenance and repairs activities and a copy ofthe manufacturer's or permittee's recommended maintenance schedule, Unit M-8010 is equiped with a non-resctable runtime meter. Navajo keeps quarter\y rolHng annual total hours on fik Reporting: The pennittee shaH report in ! Reports required by Bl 10 are submitted as accordance with Section Bl W. ! necessary. A201 Engines B. 40 CFR 63, Subpart ZZZZ (Units G0100, G-0101, V-0543, V-0545, V-0546, E-8010, E-0600\V, E-0601M, E-0602E, E-0603, and E-0901) {Units subject in Table 103J) Requirement: The units listed as subject in Table 103.J are subject to 40 CFR 63, Subpart ZZZZ and the pern1ittee shaU comply with all applicable requirements ,...gL.'.IEEIL~...!!!!sL\i_~E~~---'?_'?_'?_'?_:____________________ Monitoring: The pcrmittee sha11 comply with an applicable monitoring and testing requirements of 40 CFR 63, Subpart A and Subpart ZZZZ, Record.keeping: The pennittee shall comply with all applicable recordkeeping requirements of 40 CFR 63, Subpart A and Subpart ZZZZ, including but not limited to 63,6655 and 63J 0. Navajo complies with Subpart ZZZL Navajo compHes with Subpart ZZZZ. Navajo complies with Subpart ZZZZ. D Continuous lxJ Intermittent [:8:J Yes 0No D Continuous lxJ Intermittent D Continuous [:8:J Intermittent I lxJ Yes 0No lxl Yes 0No r """"" --- ... 1 0Yes ixJ No D Yes ixJ No "'""" 0Yes !SJ lN0 0 Conthmous [:8:J Intermittent .....-_..._------------}--------------- lxJ Yes OYes D No [:8:J No D Continuous lxl Intermittent i ~ Yes I D No Oves ixJ No I "Tl z :r- 0 0 0 0 ACC Fon11 Pa.rt l Permit# P051-R2 & R2Ml 0 01 Ver4.1 02/25i2015 N (,) (!) Page 59 of 144 EPA Inspection Report - Page 779 of 1969 Version 02,25.15 Reporting: The permittee shall comply with aH appEcab1e reporting requirements of 40 CFR 63, Subpart A and ZZZZ, including but not limited to 63,6645, 63.6650, 63,9, and 63, 10, A201 Engines C. 40 CFR 60, Subpart nu (Diesel Engines subject in Table l 03 ,J Reports required by Subpart ZZZZ were submitted semiannually as follows: J.i30!2019 7/30/2019 ------------------.,-------------~---------~ 0 Continuous ~Yes 0Yes r:gj Intermittent []No r:gj No I[J Continuous I rs;:] Intermittent ~Yes I D No 0Yes rs;:] No Requirement: The units listed as subject j Navajo complies with Subpart lill. in Table l03J are subject to 40 CFR 60, Subparts A and UH and shall cornply with the notification requirements in Subpart A and the specific requirements of Subpart fH-l-L- - - - - - - - - - - - - - - - - - 4 - - - - - - - - - - - - - - - - c c c c c c Monitoring: The permittee shaH comply ,vith all applicable monitoring and testing requirements in 40 CFR 60, Subpart A I Navajo complies with Subpart nn. and Subpart IHI, including but not limited to 60A211, Recordkeepmg: The pennittee shall comply with an applicable recordkceping requirements in 40 CFR 60, Subpart A ! Navajo complies with Subpart mt and Subpart nu, including hut not limited t --------------- . - - - - + - - - - - - - + - - - - - - - - ! [J Continuous !El Yes []Yes ~ Interm.ittent D No ~No D Continuous !Zl Intermittent !Zl Yes D No 0Yes IZ] No Rtoe6p0o.r4t2in14g,: The pem1ittee shall comply b~: with al1 applicable reporting requirements 1,11 4r,.i C,FR 60, S, ubpa, "."i' A. and S,.'ubpart 11Il, in~ludinu not limited to 60A214, A-03 Tanks A. NS.PS Subpart K, Standards of " ---------------------,----D---------C ontinuom. w , , , ,. , , 1 Na"'vaJO ccmphes with Subpart IIII. , !8:J Intermittent 1 I , , . ~ . ________ ----------~; Nav~JO contmu~-s to c,o~nply with the appLtc?ble D Continuous requirements of MAC1 Subpart CC as apphcable to the affected storage tan.ks, except for inspections !Zl Intermittent r:gJ Yes D No ~ Yes D No O Yes I rl !8:J No j ' : _ --, I D Yes I ! IZl No Performance for Storage Vessels for listed as deviations in previously submitted reports, I Petroleum Liquids for \Vhich External and internaL floating roof tank seals are "Tl z Construction, Reconstruction, or periodically inspected as required, Records are :0r- Modification Commenced After June 1L maintained of the materials stored and the storage -.-.-.-.-.-.-b.-.-.-.- .,, 0 0 0 ACC Form Part 1 Pennit # P051-R2 & R2M1 0 01 Ver 4, 1 02i25/2015 N .i:,,. Page 60 of 144 0 EPA Inspection Report - Page 780 of 1969 Version 02.25.15 1973, and Prior to May 19, 1978 (Tanks subject in Table 103,C} tcmpernturn as required. Requirement: The pern1ittee shall comply with all applicable requirements of 40 CFR 60, Subparts A & K for the affected sou~~ces in '[:~l~ 103'..~~:<~N~;~Jo~;;;fI;;;:;~;t;--~o~~~p"iy-;EE"thc applic~ble D Continuous ~--~~~~- I D Yer/ Monitoring: The pcrmittce shal1 comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart K Recordkeeping: The pcrmittce shall comply ,vith the app1icab1e recordkeeping requirements of 40 CFR 60, Subpart K reqmrements oflAACT Subpart CC as apphcable to the affected storage tanks, except for inspections listed as deviations in previously submitted reprnts. External and internal floating roof tank seals are periodically inspected as requirei:L Records are maintained of the materials stored and the storage temperature as required. Navajo maintains records at the Environmental office. ~ Intermittent D Continuous k?J Intermittent D No Lil Yes 0No I [a No 0Yes [gl No Reporting: TI1e permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart K, i A203 Tanks i B. NS.PS Subpart Ka, Standards of ' Perfon11ance for Storage Vessels for Petroleum Liquids for Which Constmction, Rcconstmction, or Modification Commenced After May 18, 1978, and Prior to July 23, 1984 (Tanks Navajo submits notifications of seal inspections to I the Department I Navajo continues to comply ,vith the applicable requirements ofMACT Subpart CC as applicable to the affected storage tanks, except fbr inspections listed as deviations in previously submitted reports. External and internal floating roof tank seals are D Contimious ;gj Intermittent D Continuous ~ Intermittent 1 1' ~Yes 0No ;gj Yes 0.No 0Yes [SJ No 0Yes ~No subject in Table 103.C) periodically inspected as required. Records are - Requirement: The pem1ittee shall comply with all applicable requirements maintained of the materials stored and the storage temperature as required. of 40 CFR 60, Subpmts A & Ka for the j affected sources in Table 103,C I ------------------,------- "Tl . Navajo continues to comply with the applicable OconHnuom; r2] Yes 0Yes z Monitoring: The pem1~tte~ sha1l comrly requirements ofivL\CT Subpart CC as ~pplica~le :0r- with !be al'Plicable momtonng a n ~ ~the a f f ~ x c q , t for m,pcctmns I I... hgr 61 of 144 0 0 0 ACC Form Part 1 Pennit # P051,,R2 & R2Ml 0 01 Ver 4J 02/25/2015 N .i:,,. ..... EPA Inspection Report - Page 781 of 1969 Version 0225. 15 requirements of 40 CFR 60, Subpart Ka. l~stcd as deviations in _pre~iously ~ubmitted reports. External and mterna1 tl.oatmg roof tank seals are ~ Inter.mi.ttent I D No . ~No , periodically inspected as re,;1irecL Records are 1 f maintained of the materials stored and the storage L ..........-..................-.................. .........!~:~P~~t.~~--~.~2,~(1uired. J Recordkeeping: The pcrmittec shall 1 , ,, ". ~ , ,. ." ' 1 1 comn v 'th h w1 t c - bl dk . app11ca e recor eeprng 1 .NavaJo mamtams 1 f'c: records at the Em1ron.ms;;ntal ; Y - 1 o nee 1 requirernents of 40 CFR 60, Subpart Ka. I I Reporting: The pennittce shal1 comply IN ' b ' . - , f 1 ..................:. 'lilt ' , 11_t e app h 1JCao e reportrng . . '"'l . l avaJ o su n11ts not1hcat10ns o sea mspect10ns to I the Department reqwrements of 40 CFR 60, Subpart Ka. 1 ! - - - - - - - - - - - - - - - - - - - + - -1'---------------.............. 1 Navajo continues to comply with the applicable requirements ofMACT Subpart CC as applicable . I ..... + 1 D Continuous [8J Yes 0Yes rs:] Intermittent . D No lSJ No l I ro_c_o_n_ti_nu_o_u_~-;-1-[8]-Y_e_s___--l,.-1-0-1-,-,e-s___............... k8'.l lntermittcnt ........_._._._._......... D No 1 !6! No I J I D Continuous [8J Yes OYes to the processes shown in Table 103 B, C, D, G, l8J Jutenn.ittent 0No [8J No except for deviations previously reported or A203 Tanks identified at the end of this report C, .NSPS Subpmt Kb, "Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) for \Vhich Construction, Reconstruction, or Modification Commenced After January 23, 19EW' (Tanks subject in Table 103.C) Requirement: The permittee shall comply with aH app1foable requirements of 40 CFR 60, Subparts A & Kb for the affected sources in Table 103,C. Fugitive components subject to these rnles are included in the Leak Detection and Repair (LDAR) program, Navajo uses a third-party contractor for the LDAR monitoring and recordkeeping. Navajo continues to comply with the applicable requirements of MACT Subpart CC as applicable to the affected storage tanks, except for inspections listed as deviations in previously submitted reports. External and internal floating roof tank seals are periodicaHy inspected as required, Records are maintained ofthe :materials stored and the storage temperature as required. The loading rack subject to portions of MACT Subpart R incorporated by reference into MACT CC is equipped with a carbon adsorption system monitored by a Clv1S. I I . . . . . 1 . Fugitive components subje~t to these nd~s are _ .. I [J Continuous I ~ Yes I D Yes I Momto.rmg. The pern11tte~ shall comf Y included in the Leak Detectwn and Repair (LDAR} . "Tl z witb ,the applicable monitonng an~ testmg progr_am.. Nava_J_: 0 1:ses a third~party co,11tractor for rgj Intermittent ! D No rs:l No :0r- reqmrements of 40 CFR 60, Subpart Kb. I the LDAR momtonng an4.E2~.2~~~.~P1!l:~.: ,,,,, L ............. 0 0 0 ACC Form Part ! Pennit # P051-R2 & R2Ml Page 62 of l 44 0 01 Ver4.l 02i25/2015 N .i:,,. N EPA Inspection Report - Page 782 of 1969 Version 02-25-15 --------------, Rccordkccping: The perrnittee shall comply with the applicable recordkeeping requirements of 40 CFR 60, Subpart Kb. The loading rack subject to portions ofMACT Suhprut R incorporated by reference into MACT CC is equipped with a carbon adsorption system monitored by a CMS, Navajo maintains records at the Environmental office. D Continuous rgj Intermittent l8J Yes 0No 0Yes rg} No Reporting: The perrnittee shaH comp1y , . , bl . wit11, t1le app11ca e reportmg requirements of 40 CFR 60~ Subpart Kb, Navajo s~~mited Subpart CC reports semiannually as foHows, 212812019 8/22/2019 D Continuous l8J lntermW:ent [Zl Yes 0No 0Yes ['.8'.]No Navajo continues to comply with the applicable n:~guirements ofMACT Subpart CC as applicable D Continuous [Zl Yes OYes A.203 Tanks to the affocted storage tanks, except for inspections listed as deviations in previously submitted reports, External and intemal Hoating roof tank seals arc [2J Intermittent 0No [2J No D. MACT Subpart CC, "National Emission Standards frn- Hazardous Air Pollutants from Petroleum Refineries" periodically inspected as required. Records are maintained of the materials stored and the storage temperature as required, (Tanks subject in Table 103.C) Navajo maintains records at the Environmental office, with the on-site LDAR contractor, and with Holly Energy Partners (HEP) for the gasoline loading rack Navajo continues to comply with the applicable requirements of MA.CT Subpart CC as applicab!e D Continuous [Zl Yes ,,,,,,,,,,,. 0Yes Requirement: The permittee shall comply with all applicable requirements of ?viA.CT Subpart CC, "National Emission Standards for Hazardous Air .. Pollutants from Petroleum Refineries" for I all affected sources shown in Table 103,C ' attached, (63,640), to the affected storage tanks, except for inspections listed as deviations in previously submitted reports. External and internal floating roof tank seals are periodically inspected as required. Records are maintained of the materials stored and the storage temperature as required, Navajo maintains records at the Environmental office, with the on-site LDAR contractor, and with [2J Intermittent 0No [Zl No Holly Energy Partners (HEP) for the gasoline I "Tl loading rack z :r- , D Continuous l'.8'.l Yes I D Yes 0 0 Monitoring: The pen.:::.:.~:,~:shall comply. LNavajo_maintany,; records at the Environmental I 0 0 ACC Fonn Part l Pemrii # P051-R2 & R2Ml Page 63 of 144 0 01 Ver 4-1 02/25/2015 N .i:,,. (,) EPA Inspection Report - Page 783 of 1969 Version 02.25.15 with the applicable monitoring and testing requirements of 40 CFR 63, Subpart CC office, with the on-site LDAR contractor, and with Holly Energy Partners (HEP) for the gasoline loading rack. :gj Inte:rmJtteut 0No :gj No Recordkeepiug: The permittee shall comply with the applicable rccordkecping requirements of 40 CFR 63.655, Reporting: The permittee shall comp1y with the applicable reporting requirements of 40 CFR 63.6550 A203 Tanks Navajo maintains records at the Environmental office, with the on-site LDAR contractor, and with Holly Energy Partners (HEP) for the gasoline loading rack. Navajo submfred MACT Subpart CC reports semiannually as foHmvs: 2i28/2019 8i22/2019 D Confumou11 !Zl Intermittent D Contnmous r2J Intermittent r2J Conthmous !Xl Ye11 0No :gj Yefi 0No 0Yefi 0Yes !Xl No 0Yes :gj No :gj Yes K Tank Throughput, Temperature, and VOC and H2S Limits (Units shown in Tables I 06.B & C) k?J Intermittent :gj No 0No Requirement: Compliance with the allowable throughput limits and emission I Navajo complies through Pi data, limits in Table 106.D & E shall be demonstrated by not exceeding the monthly rolling 12-month total ; throughput to the unit(s) of ga11ons per year (barrelsiyear) shown in Table 106D and not exceeding the allowable vapor pressure 1isted in Tables l 06.B & C. J\'fonitoring: The pennittee shall monitor the monthly total throughput, rnaximum I NavaJ-o comp1,-est.hroug.hp. t d ata. temperature once per month and the vapor - !Zl Continuous ~ lntermittent [8'.l Yes 0No I D \~es I [8'.l No .. p,~,r_e,,,,s,,,s,,,u,,,,r,-,e_,,,o,,,,,f,,,,e,,,,a,,,c,,,,h,,,,,,t,,,a,,,,n,,,,,k,,,,,,,......,,,,,,,,,,,,,,,,,,,,,,,-,_,,,,,,,,,,-,--- ~ - - - - - - - - - - - - - - - - - + - - - - - + - - - - - f I . - - - ~ -----------, Recordkeeping: The pcrmittce sha11 !Zl Continumrn :gj Yes 0Yes record the monthly total throughput of I "Tl hquids and the vapor pressure of each I Navajo complies through Pi data, z tank Each month, during the first 12 :0r- 0 months of monitoring~ the pennittee shal1 0 0 ACC Form Part l Permit# P051-R2 & R2M l 0 01 Ver 4.1 02i25i2015 N .i:,,. .i:,,. fgJ Intermittent 0No :gj No Page 64 of 144 EPA Inspection Report - Page 784 of 1969 Version 02.25J5 record the cumulative total liquid throughput and vapor pressure and after the first 12 months of monitoring, the pennhtee shall calculate and record a monthly rolling 12-month total liquid throughput and the vapor pressure ofeach tank The pen11ittee has calculated the VOCs and H2S annually based 011 the 12-month totaL Tank hreathfog and working em1ss10ns were calculated using the USEPA Tanks program Version 4J19.d or more cuffenL Emission rates computed using the same parameters, but with a different Department approved algorithm that exceed these values wm not be deemed non-comphance with this pen11it Records shall also he maintained in accordance with Section B109. Reporting: The permittee shall report in Navajo complies through Pi data, accordance with Section B 110, D Continuous r2:I Intermittent r2:I Yes 0No 0Yes r2:i No I "Tl z :r- 0 0 0 0 ACC Fom1 Part l Pennit # P051-R2 & R2Ml 0 01 Ver 4.1 02/25i2015 N .i:,,. 01 Page 65 of 144 EPA Inspection Report - Page 785 of 1969 Version 02.25,15 A204 Heaters/Boilers A, Operational Inspection (AH I heaters/boilers in Tables 103.E & 104.A) 1 Inspections were performed to ensure proper l. . , , operation. I Reqmrement: Complrnnce w1th the i allowable emission limits in Table 106.A I shall be demonstrated by performing ! periodic inspections to ensure proper : operations, t:wio.nitorii1ii=~rhe..pei111itteesi1aifcond~ict1--------------------- ------------------------------------- i annual operational inspections to , I detem1ine that the heater(s)1bo1ler(s) are I operating properly, The operational i inspections sha11 include operational I checks for indications of insufficient I excess air, or too much excess combustion i Inspections were performed to ensure proper air. These operational checks shall i operation. include observation of common physical ' indications of improper combustion, including indications specified by the , heater/boiler manufacturer, and I indications based on operational experience with the/these unit(s), Recordkeeping: The permittee shall maintain records of operational inspections, describing the results of all operational inspections noting chronologically any adjustments needed to bring the heater(s);boi1er{s) into compliance. The pem1ittee shall maintain records in accordance with Section B109, Inspection results arc maintained by Navajo Environmental Department I "Tl z :r- 0 0 0 0 ACC Form Part l Pcnnit # P05 l-R2 & R2M l 0 01 Ver4_1 02/25/2015 N .i:,,. 0) D Continuous (gj Intermittent 0 Yes 0No 0Yes (gj No o Continuous (gj Intermittent I 0 Yes 0No ,,,,,,,,,,,,, 0Yes (gj No D Conthmous 0 Intermittent 0Yes 0No 0Yes ~No Page 66 of 144 EPA Inspection Report - Page 786 of 1969 Version 02.25.15 Reporting: The permittee shall report in accordance with Section B110, Within ninety (90) days of pennit issuance, the permittee shall submit for Department approval a procedure which the pcnnittee wiH use to carry out the operational inspections, The pennittee may at any time submit revisions for Department approvaL Navajo submited MACT Subpart DDDDD reports semiannually as fr)Uows: 1/30/2019 7/30/2019 D Continuous rs:] Intermittent II ~ Yes D No 0Yes [8'.] .No A204 Heaters/Boilers B. Periodic Emissions Tests (Units Heaters H-0019, H-0020, H-0362, H0363, H-0364, H~2421, H-3402, and H3403) Requirement: Compliance with allowable emission limits in Table 106.A shaH be demonstrated by perfonning periodic emissfons tests. (NSR 0195M35, Condition A204,A, revived) Testing was perfonned H-0019 02/20/2019 H-0020 02/20/2019 1Ul362 02/14/2019 H-0363 02/14/2019 H-0364 02/14/2019 H-2421 04/18/2019 H~3402 02/15/2019 H-3403 02/14/2019 />Jl heaters ,vere within as follov,is: aHowable emission limits. 0 Continuous l8'.l Intermittent 0Yes 0No 0Yes [gl No Monitoring: The pennHtee shall conduct l8'.l Continuous 0 Yes 0Yes annual periodic portable analyzer emission tests or EPA Reference Method Testing was performed as follows: ~ Intermittent D No ~.No Tests for NOx and CO. H-0019 02/20/2019 H-0020 02/20/2019 Test results that demonstrate compliance H-0362 02/14/2019 with the CO emission limits shall also he H-0363 02/14/2019 considered to qcmonstrate compliance H-0364 02/14/2019 with the VOC emission Emits. H-2421 04/18/2019 Section B108 General Monitoring H-3402 ?2115!2019 Requirements apply to this condition. H-3403 02/14/2019 AU heaters were within allowable emission limits. I The perrnittee shall meet the testimr I requirements in Section B111, ~ "Tl z :r- Recordkeeping: Records of periodic Periodic emission test results are maintai 0 uuuccc,--------, ------------------------------------------~.. uu~n .uu>"NNN~ 0 0 0 ACC Form Part 1 Permit# P051-R2 & R2Ml 0 01 Ver 4J 02/25/2015 N .i:,,. -..,J D Continuous ! 2s] Yes 0Yes Page 67 of 144 EPA Inspection Report - Page 787 of 1969 Version 02.25. 15 ~--------------------------.....--------"""--""""""" emission tests shall include the How rate I Navajo Emimnrnental Department. and the stack gas exhaust temperature_ If a combustion analyzer is used to measure NOx, CO, andior e~cess air in the fiue gas, ' records shall be kept of the make and model of the instrument and instrument calibration data. If an ORSAT apparatus or other gas absorption analyzer is used, the pen11ittee shall record all calibration results. Records shall be kept of all raw data used to detennine :flue gas :flow and of all calculations used to determine :flow rates and emission rates. The permittee shall maintain records in accordance with 1 Section Bl09, BUO, and B11 L "-""""""""-i"""""""" -------------~--------- Reporting: The permittee shall summarize in tabular fom1 the results of the initial or subsequent periodic I emrns1ons tests for NOx and CO. I specifying the mass emissions rates i~ I All testing reports wt.Ye submitted to the NMED at I pounds per hour- The table shaH include I <stackiestaqb@state_nm.us>. I the average concentration of aU relevant [ poUutant species. The pe1111ittee shall i report in accordance with Section Bl09, l B110, and Bll L I A204 Heaters/Boilers I [8'.] Intermittent D Continuous rsl Intermittent I [g] Continuous f D No ' ~ Yes D No l D Yes C. Summary of Compliance Methods for Heaters and Boilers for Table 106,A, 20233 NMAC, 202,37 NMAC (Boilers and Heaters in Tables 103,E and 104.A) Navajo complies with these requirements, except for deviations previously reported or identified at the end of this report. kSJ Intermittent ~No [8'.] No ........... 1 0Yes rgj No rgJ Yes 0No Requirement: (NSR 0195M35, I "Tl Condition A204,B) z :r- 0 0 0 0 ACC Form Part 1 Permit# P05 l ~R2 & R2M l 0 01 Vcr4J 02i25/201.5 N .i:,,. OJ Page 68 of 144 EPA Inspection Report - Page 788 of 1969 Vernion 02.25-15 (1) Demonstrate compliance v.rith Table 106,A Allowable Emissions. (2) 202.33 NMAC (Gas Burning Equipment~ Nitrogen Dioxide, 10/31/02) , applies to existing and new gas burning equipment having a heat input of greater than 1,OOOJJOO million British Thermal Units per year. It applies to process heaters identified in Tables 103,E and 104,A These unJts sha11 be equipped with burners emitting less than 0.2 lb NOx per MM Btu, Compliance with 202.33 NMAC is demonstrated by compliance with the NOx lb per MM Btu hrnits in Table Al 06.A. lvfonitoring: I 1) Fud use measured by PL (1) The permittee shall monitor the fuel ' usage of the all boilers and heaters, The j 2) Refinery fuel gas is analyzed at least once per fuel usage shall be monitored for specific week heaters and boilers subject to 202.33 Nl\1AC, ! 3) Refor to response for Section A100.A 2sJ Continuous 2;J Intermittent ! [gJ Ye1. ! ! D No 0Yes ;gj No (2) For specific heaters and boilers subject to 202.33 NMAC, the permittee shall col1ec1 and analyze samples of ihe refinery fuel gas at least once per week The refinery fuel gas ana1ysis shall include the composition of the refinery fheI gas, the 5>ross heating value, and the net heating value. (3) Sec Condition A110,A for H2S monitoring requirements, _ _ ll h _1 1 '] 1 11 (4J A process eaters anu om em si1au 4) No combustion sources fire only purchased gm;, 5) The following combustion sources have CMS that axe recertified annually as follows: B-0007 03/19i2019 B-0008 03/19/2019 B-0009 03/20/2019 H-9851 03/2! /2019 H-2501 02/19/2019 6) Test results referenced in Condition Al 04J3 meet this requirement. I fire ~nly_ refinery_ gas in accordance with j 7) Navajo complies through Pi data. "Tl z Apphcat1011, Sect1on 2, Table 2~J. I 8) Navajo Refinery is no longer affected by :0r- {5} For those combustion sources re,iuired f 202.37 NMAC. This rule was repealed on 0 . . ----------------------------------------------------------------- ---------------------'-------------.-.---.-.-.-.-.-.--.-------------------'--------'--------"''- 0 0 ACC Form Part 1 Permit# P05 t-R2 & R2M1 Page 69 of 144 0 01 Ver4,l 02/25/2015 N .i:,,. (!) EPA Inspection Report - Page 789 of 1969 Version 0225.15 ! to have a continuous monitoring system I September 12, 2016, (CMS) (Hsted in (a) below), the pem1ittee shall install, certify, calibrate, maintain, and operate the CMS for each required poUutant in accordance with the applicable requirements of 40 CFR 60 or 63. The hourly average CMS data, the refinery fuel gas usage data, and the refinery foe1 gas cornposWon data shall he used to estimate the actual emission mtes, (a) The fi:)llowing CMS shaU be recertified annually: Boiler B-0007 NOx and 02 CMS * Boi1er B-0008 NOx and 02 CMS Boiler B-0009 NOx and 02 and CO2 CMS I H-9851 NOx 02 CMS I H-2501 NOx 02 CMS I (6) For those combustion sources required to conduct periodic stack exhaust testing as stated in Condition A204.B, the test reports shall be used to demonstrate compliance with the NOx, CO, and VOC limits in Tah1e 106.A (7) For those units and pollutants that are not required to have a CMS or a periodic stack test, (Units H-009, H-0011, H- 0018, H-0028, H-0030, H-0040, H-0303, H-0312, H-0352, H-0353, H-0354, H- 0355, H-0421, H-0464, H-0473, H-0600, H-0601, H-8801, H-8802, and H-3101) I "Tl the permit application emission factor, z :r- the_~\:te}11sa,g_e,and_the_refinery-fu-e-l__,,,g'--a-s_L,__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _.__L_ _ _ _ _ _L,__ _ _ __ 0 0 0 0 ACC Form Part 1 Permit# P051~R2 & R2M1 Page 70 ofl 44 0 01 Ver 4.1 02/25/2015 N 01 0 EPA Inspection Report - Page 790 of 1969 Version 02.25.15 shall be used to calculate the emission rates of NOx, CO~ VOC, and Plvl (8) Compliance \Vith the particulate em1ss1011 limitation set forth in I 202,37.202.A NMAC shall be . determined as specified in 20237.202D(3) NMAC. Combustion of j' only gaseous foe1 has been approved by the Department as the compliance method 1 u n d e r 2 0 2 3 7 2 0 2 , D ( 3 } NMAC. ---------------------------------------------------------,,,,,,,,_______________.,,, ___,,,,,,,,-.,,,,,,___.,,,____. _ , , , , , , , , , , , , , , , - , _ , , , , , - - - - - . , . , . + - Record.keeping: The permittee shall maintain the foUowfog records: ( 1) By March 31, the amrnal fuel usage ~ Continuous ~ Intermittent ~ Yes D No 0Yes ~No for aU boi1ers and heaters for the previous calendar year, (2) By March 31, the average fuel composition and heating value for a11 boilers and heaters for the previous 1) Fuel usage records are maintained in PL calendar year, (3) For those units required to have a 2) Fud composition records are maintained in Pi. CMS (B-0007, B-0008, B-0009, H-9851 and H-2501 ), the CMS hourly average data. (4) For those units requ.fred to conduct 3) CMS data is maintained on PL I 4) Test reports arc maintained by Navajo I Envirnmnental Department periodic stack exhaust testing, the periodic test report, (5) For all boilers and heaters, a sun11nruy spreadsheet shall be maintained 5) The summary spreadsheet is included in the Emission Inventory. comparing the actual ammal emissions with the aUowab1e emission limits expressed in tons per year and lb/MMBtu. I us111g the appropriate method of "Tl compliance demonstration. This z :r- ,,,~preadsheet shall be updated by March 31 0 0 0 0 ACC Form Part l Pcm1it # P051-R2 & R2M ! 0 01 Ver 4.1 02i25i20l5 N .0..1.. Page 71 ofl44 EPA Inspection Report - Page 791 of 1969 Version 0225-15 of each year for the previous calendar veaL -, ] Reportin;Thep~itt:~h:ireport~,::::- : ~~:::~::, : ~: : ~::' . accordance w1th Sect10ns B 110. necessruy. A.204 Heaters/Boiiers [gl Contbrnous D Yes [gl Yes D. Consent Decree NOx Emission Limits for Boilers B-0007, B-0008, and B-0009 (new as of 201.3) [gl !ntennitient [gl No 0No Requirement: (NSR Condition A204.C) 0195M35, (1) In accordance with the Consent Decree lodged December 20, 2001, NOx emissions from boilers B-0007 (no later than December 31, 2002), B-0008 (no later than December 31, 2003), and B. 0009 (nev,: as of 2013) shaH not exceed i the limit in Table 106.A during any hou:r1y romng 3-hour period, 1) Data :maintained in Pi, 2) No requirement Demonstration of compliance with the NOx limit for B-0007, B-0008, and B- 0009 shall be estabHshe<l by averaging the CMS Data over any 3-hour period and I comparing the average concentration to J the parametric limit of.:=.; 42-l ppm NOx, ! corrected to 6.] '}o 02 as determined by the CMS, (CD'lfl6.D) This also satisfies the requirement in 20233-108.A NMAC that NOx emissions shall not exceed 02 I 1biMMBTU. "Tl z 2) Navaio is authorized to onerate all :r- 0 0 0 0 ACC Form Part 1 Permit# P051-R2 & R2M1 0 01 Ver 4.1 02/25/2015 N 01 N Page 72 ofl44 EPA Inspection Report - Page 792 of 1969 Version 0225.15 three boilers (B-0007, B-0008, and B- ! -------------...----- 0009) simultaneously as needed. I . ----------------l""""""_ _,,,,,,,,,,,,,,,,,,,,,-------------+------+---- ! Monitoring: For the Controlled Boilers l2S'.J Continnom [Zl Yes (B-0007, B-0008) as listed in the Consent Decree and B-0009 (new as of 2013), l8J lnte:rmHtent 0No continuous compliance with their respective NOx permit emissions limits shall be demonstrated by monitoring as follows: (CD9IliiC) (1) For boilers (B-0007; B-0008, and B- 0009) \vith a heat input capacity greater than 150 MMBTU/hr of HHV, the permittee shaU instaU or continue to operate ClV1S to measure NOx and 02, Each CMS shail be installed., certified, calibrated, maintained, and operated in 1) B-0007, B-0008, & B-0009 have c:tvIS installed and data maintained in PL accordance with the requirements of 40 CFR 60, 11, 60, 13, and Part 60 Appendix A and the apphcab1e performance specification test of 40 CFR Part 60 Appendices B and F. These CMS shall he used to demonstrate compliance \Vith emission limits. The permittee shaH make CMS and process data avai1able to the applicable Federal and State Agencies upon demand as soon as practicab1c; I (C~16.C.i) 1 -"-"~""" """""""---.-.-.-.-.-. -~~~~----~nun Recordkeeping: The pennittee shall keep records of the CMS recertification's monitored m Condition A204.B, CMS recertifications are maintained by the Navajo Environmental Department [8J Continuous [8J Intermittent [8J Yes 0No Summary of Compliance. u u-.-.-.---------.---------.- ~~~~~ , n u n OYes t8J No 0Yes [8J No l ' ' u.-.-.-.-.-.-.-.------- I "Tl z :r- 0 0 0 0 ACC Fom1 Part 1 Permit# P051-R2 & R2M1 0 01 Ver 4.1 02/2512015 N 01 (,) Page 73 ofl 44 EPA Inspection Report - Page 793 of 1969 Version 0225.15 Reporting: The pennittee shall report in All testing reports were submitted to the NMED at accordance ,Nith Section B 110, <stacktcstaqb(~)statc,nm. us>. A204 Heaters/Bollen D Continuous 13:l Intermittent ~ Continuous !X:l Yes 0No r8:l Yes Dves l3J No ,.-.-.--.-.-.-.----- 0Yes E. NOx Monitoring and Testing for ControHed Heaters Subject to the Consent Decree (Units H-0020, H-0352~ H-0353, H-0354, H-0600, and H-0601) I Requirement: For the Controlled Heaters I as listed in the Consent Decree, I continuous compliance with all NOx ' emfasions limits shall be demonstrated by monitoring as foHov,/s. (CD~f16.C) (NSR 0195M35, Condition A204,D) lV[onito.ring: CMS installed and data maintained in Pi. rzJ Intermittent 0No ~No 13:l Continuous ;:g:J Yes 0Yes (] ) For heaters wlth a heat input capacity of equal to or less than 150 MMBTUihr (HHV) but greater than 100 MMBTU/hr (HHV), Navajo sha11 (a) install or continue to operate CMS to measure NOx and 02 by no later than the date of the instal1ation of the applicable NOx Control Technology on the heater or boiler; or I 1 1) H-9851 is equipped with NOx and 02 CMS that ls certified, calibrated, maintained and operated in accordance \vith the referenced requirements. 2) Referenced heaters meet these requirements. All initial performance tests have been reported. ~ Intermittent 0No l3J No (b) submit for EPA approval, by no later than 60 days after the date of installation of the applicable NOx Control Technology on the heater or 3) Referenced heaters were initially tested and are tested annually, H-0601 is monitored weekty usiJ1g a handheld portable analyzer, boiler, a proposal for monitoring based on operating parameters, I including but not limited to, firebox "Tl z temperature, air preheat temperature, I :r- ! heat input rate, and combustion 02, 0 -.-.-uuuuu~.-.-u~.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-. 0 0 0 ACC Fonn Part 1 Permit# P05 l-R2 & R2Ml 0 01 Ver 4-1 02125/2015 N 01 .i:,,. -.-.-.-.-.-.-~.-.-.-.-.-.- .J- Page 74 of 144 EPA Inspection Report - Page 794 of 1969 Version 02.25.15 Navajo shall evaluate the necessity of using firebox or bridgewaH temperatures and additional operating parameters and agrees to use such parameters as a means of monitoring perfommnce where Navajo and EPA mutually-agree to their effectiveness. (CD~l 6.C.ii). As of January 23, 2014 (notarized date of application), there are no heaters or boilers at the Artesia Refinery with a capacity of equal to or less than 150 MMBTU/hr (HHV) but greater than l 00 MMBTU/hr (HHV) subject to Monitoring requirement (1 ). (2) For heaters with a heat input capacity of equal to or less than 100 MMBTU/hr of HHV, the pe1mittee shall conduct an initial performance tests for NOx. The results of these tests shall be reported based upon an average of three (3) onehour testing periods and shall be used to 1 develop representative operating I ! parameters for each unit, which will be ! ' used as indicators of compliance. (CD~l 6.C.iii). This condition applies to the following heaters: Heaters H-0352, H-0353, and H-0354 Heater H-0020 Heaters H-0600 and H-0601 The permittee has completed all I of the initial performance tests. "Tl z (3) For heater H-0601 compliance shall :r- be demonstrated by conthmously 0 0 0 0 ACC Form Part 1 Permit# P051-R2 & R2Ml 0 01 Ver 4.1 02/25/2015 N 01 01 Page 75 ofl44 EPA Inspection Report - Page 795 of 1969 Version 02-25-15 ,_ monitoring stack oxygen {02) to maintain a 3~hour average below 6.0 voFViio As a further check of compliance, Navajo shaJ] monitor stack NOx at least twice a month using a portable analyzer to assure that the rneasured NOx value does not exceed the compliance threshold of 38 ppmv NOx. ~J2_:Ciil} Recordkeepiug: (1) The permittee shall keep records ofthe Fuel firing rates and Sulfur limits I 1) Fuel firing rate records are maintained in Pi. monitored for Condition A11 Cl.A. ' 2) and 3) Test records arc maintained by the (2) The pem1ittee shaU keep records of the I Navajo Environmental Department. initial perforn1m1ce tests. (3) TI1e permittee shall keep records ofthe stack oxygen monitoring and the portable analyzer tests" I Reporting: The pern1ittee shaH report in accordance with Section B 110. Condition Reports required by B110 are submitted as R 111 .D(7) does not apply to portable applicable. I m1alyzer tests. j ' I A204 Heaters/Boilers ; F. NOx Monitoring and Testing for I Heaters permitted after the Consent i Decree (Units Heaters H-0019, H~0362, I HAH63, H-0364, H-2421, H-3402, H- I 3403, H-2501, H~8801/8802, and H- I 9851) I Navajo complies with these requirements. liSI Continuous liSI Intermittent r8J Yes I D No D Continuous liSI Intermittent l'8J Yes 0No liSI Continuous l8J Intermittent l'8J Yes 0No I 0Yes liSI No 0Yes r8J No 0Yes [SJ No Requirement: For the HeatcTs pcnnitted after the Consent Decree, continuous I "Tl compliance with their respective NOx z permit emissions limits in Table 106,A :r- 0 _shall be demonstrated by monitoring as 0 0 0 ACC Form Part 1 Permit# .P051-R2 & R2Ml 0 01 Ver4J 02/25/2015 N 01 0) Page 76 of 144 EPA Inspection Report - Page 796 of 1969 Version 02,25, !.5 1 fo1lows. (NSR 0195M35, Condition - -~ A204.E) .lVfonito:ring: (1) For heaters vvith a heat input capacity greater than 150 MM Btu/hr (LHV Basis), the permittee shall install and operate CMS to measure NOx and 02 by the startup date of each heater. Each CMS shall be installed, certified, calibrated, maintained, and operated in accordance \.Vith the requirements of 40 CFR 60.1 L 60.13, and Part 60 Appendix A and the applicable perfonnance specifications of 40 CFR Part 60 Appendices B and F. ' These CMS shall be used to demonstrate 1) H-9851 has a CMS installed and data , . . . , maintained in PL comphance with en11ss10n lnmts. The , permitte: shall make CM~ and process 12) H-2.501 ~ H~.8801:/88?2 has a CMS installed , data available to the applicable Federal and data mamtamed m Pl. and State Agencies upon demand as soon i as practicabk Condition A204.F(1) 3) Initial perfrnmance tests were completed as applies to heater H-9851, required, !:8J Continuous , !Z:l Intermittent i I cgi Yes ! D No OYes ~No (2) For heaters with a heat input capacity of equal to or less than 150 MM Btu/hr (LHV) but greater than 100 MM Btu/hr (LHV), Navajo sha.11: 4) Navajo complies with these requirements, (a) install and operate CMS to measure NOx and 02 by the startup date of each heater; or (b) submit to the Permit Program Manager for NMED approval, by no later than 90 days after the startup date of each heater, a proposal for I "Tl monitoring based on operating z :r- -p_ar_a_m_e_t_er_s_,_O._,ip,__e_r_a_ti_ng'"'--'p.._ar_a~~!,~=~,,L """"--------- ,, 0 0 0 0 ACC Form Part l Pennit # P051-R2 & R2M l 0 01 Ver4J 02/25/2015 N 01 -..,J <' - - - - - - - - - - - - - - - - - - ' - - - - - - - - ' Page 77 of 144 r EPA Inspection Report - Page 797 of 1969 Version 02.25.15 to consider include, but are not limited to, firebox temperature, air ; pre-heat temperature, heat input rate, and combustion 02. Navajo agrees to use such parameters as a means of monitoring performance. Condition A204.F(2) applies to heaters H-2501 and H-8801/8802 (3) For heaters with a heat input capacity of equal to or less than l 00 MM Btu/hr (LHV basis), the pennittee shall conduct an initial performance test by no later than 180 days after the startup date. The results of this test shall be reported based upon an average of three (3) one-hour testing periods and shall be used to develop representative operating parameters for each unit, which will be used as indicators of compliance. This condition applies to the following heaters: Heaters H-0362, H-0363, H0364, and H-2421 Heater H-0019 Heaters H-3402 (AMP approved by EPA, see (4)) , initial performance test completed on July 10, 2013 Heater H-3403, initial perlommnce test completed on April 30, 2013 I1 (4) US EPA has approved an Alten1ative I ! Monitoring Plan (AMP) for Unit H-3402 "Tl z for utilizing the oxygen monitor on the :0r- H-3402 Unit 34 Hvdrocracker Reboiler 1 0 0 0 ACC Form Part 1 Pennjt# P051-R2 & R2M1 0 01 Ver4.1 02/25/2015 N 01 OJ Page 78 of 144 EPA Inspection Report - Page 798 of 1969 Version 02.25.15 as a parametric means for demonstrating compliance with NSPS Ja, NOx monitoring via a CMS, In accordance with the AMP, the permittee shall accomplish the fo11owing: (a) lnstaH flow indication on the fuel Ene to provide historical data of the fuel to the Mild Hydrocrackcr (Unit 34) by January P, 2015. (b) Monitor the process historical data of the HEP purchased natural gas 1 pressure, and the high pressure fuel balance drum (D-0770). (c) Upgrade the existing the Mild Hydrncracker (Unit 34) Reboiler Heater (H-3402) oxygen monitor to perfo1111 daily calibrations as required in 40 CFR60,13(d)(1). (Note that the sample placement docs not confonn to CMS requirements for process reasons), (d) Conduct biennial performance tests according to the requirements in 40CFR 60.104a(i). (e) Establish a maximum or curve excess 02 operating limit (TvIOPV) as required under 40 CFR60J07a(c)(6) utilizing the existing monitor, (t) ]ndnde Reboiler Heater (H-3402) hours of refinery fuel gas usage and I "Tl any deviations during such time as z :r- required hv 40 CFR 60.7 for 0 0 0 0 ACC Form Part l Pem1it # P051-R2 & R2M l. 0 01 Ver 4.1 02i25i20l5 N 01 (!) Page 79 of 144 EPA Inspection Report - Page 799 of 1969 Version 0225.15 periodic reporting. ! I Record.keeping: (1) Thepern1ittee shal1 keep records ofthe monitoring proposals submitted to the Pennit Program Manager for approval and whether the submittal ;vas approved. 1) Records are maintained by the Navajo Environmental Department t8'.I Continuous t8'.I Intermittent t8'.I Yes 0No 0Yes [8'.I No (2) The fK,'ITTiittee shaU keep records ofthe CMS data, calibrntion, and recertification's monitored in Condition A204,A, Summary of Compliance. 2) CMS data maintained in PL 3) Performance tests are maintained by the Navajo Environmental Department. (3) The pennittee shall keep records ofthe performance tests. (4) The permittee shall keep records ofthe implementafam of the AMP and all required monitoring specified in the M1P. 4) the Al"\1P is maintained by the Navajo Environmental Department Reporting: 111e permittee shall report in Reports required by B 110 are submitted as D Coath!uous rg) Yes 0Yes accordance \Vith Section B110, A204 Heaters/Boilers applicable, .,........................,,,,,,, I [8'.I Intermittent 0No ! - - - - - - - --.-.-uu~.-.-.-.-. t8'.I Continuous [8'.I Yes [8'.I No 0Yes G. NSPS Subpart Db, Standards of 1 Performance for Industria1-Commercial- I Institutional Steam Generating Units . [8'.I Intmmhtent I 0No [8'.I No I ' (Boilers and heater subject in Table J' H.eater H-2501 and Bo!krs B-0007, B-0?08, and l 03,E) IB-0009 each have a NOx CEMS as required by NSPS Subpart Db. Requirement: The permittee shall comply with al] applicable requirements of 40 CFR 60, Subparts A & Db (N0x- I "Tl 60A4b, S02-60A2b, & PM-60A3b) for z ___!__~e affected sources in Tab1e 103,R :r- 0 0 0 0 ACC Form Part 1 Penn.it# P051-R2 & R2Ml 0 01 Ver 4.1 02/25/2015 N 0) 0 Page 80 of 144 EPA Inspection Report - Page 800 of 1969 Version 0225.15 l\fo:nitori:ng: The pcrmittec shall comply with the applicable monitoring and testmg i requirements of 40 CFR 60A8b, Subpart Heater H-2501 and Boilers B-0007, B-0008, and B-0009 each have a NOx CEMS as required by NSPS Subpart Db. [Xl Continuous !Ll Intermittent !8J Yes [JNo 0Yes rgj No 1 Db. ..4............................................- - - - - - - - - - - - - j - - - - - - r - : rR~~~rdkceping: The pennittee s~aH ! NOx records are maintained in PL Test records arc lSJ Continuous !8J Yes ! comply with the applicable recordkeepmg maintained by the Navajo Environmental \ requirements of 40 CFR 60.49b, Subpart Department. ~ fotennhtent 0No I 1 Db. 0Ycs ~No Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60.49b, Subpart Navajo submited NS.PS Subpart Db reports semiannually as follows: 1/30/2019 D Continuous ~ Intermittent k?SJ Yes 0No 0Yes ~No Db, 7/30/2019 uuu~=~- Compliance Test: The pennittee shall comply with the methods and procedures stipulated in 40 CFR 60, Section 60.45b Navajo complies with the requirements of the Compliance Testing, I R$J Continuous I !8J Intermittent ['8'.l Yes 0No 0Yes I !8J No I and 60A6b. A204 Heaters/Boilers !8J Continuous [Xl Yes 0Yes H. NSPS Subpart De, Standards of Performance for Sman Industrial- CommerciaL - lnstitutioual Steam Generating Units (Boilers and heater subject in Table 103 .R} Navajo complies wfrh the requirements of steam generating units. Requirement: The permittee shall comply with all applicable requirements of 40 CFR 60, Subparts A & De (N0x- 60.44c, S02-60A2c, & PM-60A3c) for the affected sources in Table 103.E I JV[onitoring: The pennittee shall comply 1 with.the appllca.bk monitoring and testing I N.avajo .compl,ies with the requirements of steam reqmrcmcnts of 40 CFR 60A7c, Subpart generatmg umts. De. !8J Intermittent 01'-fo rgj Continuo__u...s..........+1 !8J Ye.s..........._....,,,, rx Intermittent 1 D No !8J No D Yes [Xl No I "Tl z :r- 0 0 0 0 ACC Fonn Part l Permit# P051-R2 & R2M l 0 01 Ver4J 02/25i2015 N 0) ..... Page 81 ofl44 EPA Inspection Report - Page 801 of 1969 Version 02,25. l.5 rccccccc------------------ .............. .Recordkeeping: The pennittee shaH comply '>Nith the apphcab1e record.keeping requirements of 40 CFR 60A8c, Subpart De. Navajo complies with the requirements of steam generating units. ~ Contl.uu.ous [8:l Inte:rmatent ~Yes 0l'<fo Reporting: The permittee shall comply with the applicable reporting requirements of40 GFR 60A8c, Subpart De Navajo complies with the requirements of steam generating units. D Continuous ~ Intermittent ~Yes 0No Compliance Test: The permittee shall I r:8:J Coutiuuous comply with the methods and procedures \ Navajo complies with the requirements of steam stipulated in 40 CFR 60, Section 60,44c I generating units. 1:8'.J Intermittent and 60A5c. i !-----ccccccc-ccc-ccccccc. ccccc--ccc-- .. ------- ----- + - - - - " " " ' - - - - - - - - - - - - - - - - - - - - - 4 - - - - - -cuu- Navajo continues to comply with the applicable I 2sJ Contim1ous monitoring requirements ofNSPS Subpart J as i ' applicable to the affected heaters, boilers, R.0 Intermittent SRU1iSRU2, and the FCC shown in Table 103E. ~Yes 0No .. -----------------~~ [gj Yes ! 0No 0Yes ~No -uu~.-.-.-~.-.-.-.-.-. 0Yes ~No 0Yes f-71 ,._,,,. ~l~...s I 0Yei;: f [ [SJ No A204 Heate.rs/BoHe.rs H2S content on a 3-hour rolling average basis. The refinery fuel gas is continuously monitored for I I. NSPS Subpart J, Standards of ?erfon11ance for Petroleum Refineries The SRU1!SRU2 tail gas incinerator is (Boilers and heater subject fa Table continuously monitored. for S02 content, corrected 103,E} to 0%i 02, on a 12-hour rolling average basis. . Requirement: The permittee shall comply with all applicable requirements The FCCU Catalyst Rcgcnerntor Scrnbber exhaust is continuouslv monitored for S02 and CO, .PM is monitored am{ually, Navajo has submitted an , o~ ,40 CFR 60, ~ubparts A & J for the 'I alternative m~nitorin pl~n (iu\1~) to comply with affected sources m Table 103 ,E, the FCC opacity momtormg reqmrement because the FCCU has a wet scmbber which prevents continuous opacity monitoring. Under the AT'vfP, opacity is monitored monthly using 40 CFR 60 A.ppendix A Method 9. - - - - - - - - - c c - c c c c c c c c c - c c c c c c c c . cccccccccccc-------! ---,-,- I Monitoring: The pennittee shall I "Tl z comply with the applicable monitoring , All of the continuous monitors are operated, :0r- and testing requirements of 40 G~J3;ccO, CCCCCJ .~.~~=tai~:~' and certified as required, 0 0 0 ACC Form Part 1 Permit# P05 t~R2 & R2M1 0 01 Ver 4. l 02/25/2015 N 0) N cccc-ccc. + ccccccccc.. ------~---------------+------- ! ~ Continuous i rs:; Yes 0Yes : I ~ fotermitt~nt ...J...D ~-~ I ~ No I Page 82 of 144 EPA Inspection Report - Page 802 of 1969 Version 02.25, I5 I Subpart Jo I Recordkeepiug: The permittee shall comply with the applicable rccordkecping requirements of 40 CFR 60, Subpart J, Records are maintained by Navajo Environmental Department and on PL Reporting: The permittec shall comply with the applicable reporting requirements of 40 CFR 60, Subpart J, Navajo submited NSPS Subparts J reports semiannually as follows: 1/30/2019 7/30/2019 12:l Contimious ~ Intermittent D Continuous 2$J Intermittent ~Yes 0No !2:) Ye; 0No u u u ~ u u ~ ~ -- -~~~~~~~~=~~~~.= 0Yes ~No 0Yer,; rgj No I "Tl z :r- 0 0 0 0 ACC Form Part 1 Pennit # P05 l -R2 & R2M1 0 01 Ver4.l 02i25/2015 N 0) (,) Page 83 of 144 EPA Inspection Report - Page 803 of 1969 Version 02.25.15 Navajo contmues to comply with the applicable A204 Heaters/Boilers monitoring requirements of NSPS Subpart Ja as applicable to the affected heaters, SRU3, and flares J. NSPS Subpart .fa, Standards of as shown in Table 103E. Pcrfonnance for Petroleum Refineries for I ,vhich Construction, Reconstruction, or 1 Modification Comm,enced After May 14, The refinery fuel gas is continuously monitored for H2S content on a 3-hour roUing average basis. 2007 (Boilers and heater subject in Table The flares met the minimum heating value, tip 103.E) velocity, and visible requirements as documented by the compliance testing detailed in previous Requirement The pennittee shall I responses, comp1y with an app1foab1e requirements of 40 CFR 60, Subparts A & Ja for the The SRUJ tail gas incinerator is continuously affected sources in Tabk 103,E, monitored for S02 content, corrected to 0% 02, on cccc,cccc,cccc cccc,cccccccccc ,cccccccccc,,cc ,cccccccccc,cccc,--- cccccccccccccccccccc,~cccccccc, " a 12-hour, rollh1K averageJ:asis, lv~onitoring: The pcrmittce shall comply . . with.the applicable monitoring and testing All, of \he contmuou~ monitors are operated, reqmrermmts of 40 CFR 60., Subpart Ja, mamtamed, and certified as required. 25] Continuotrn 25] Intermittent , U I ZJ Continuo rk:.:'..:)>J1 Intcrnu,tt,mt I 0Yes 0No ; 25] Yes 0No 0Yes kr:::-7J! N. n .!. u Recordkeeping: The permittec shaH comr1y with the apphcab]e recordkeeping reqmrements of 40 CFR 60, Sub part ,Ja, Reporting: The pcrmittec shall comply with the applicable reporting requirements of 40 CFR 60 Subpart]" ' a. Records are maintain~d by Navajo Environmental Department and on PL Nav~jo submiled NSPS Subparts Ja reports semiannually as foUows: 1130!2019 7/30/2019 :zJ ContinumIS I uNJ lntermHt,mt ! D , . ii!i Contmum I :zJ Intermitt,!Ut !8:]Yes 0No uuuuu :g:J y. es 0No A204 Heaters/Boilers ~ Continuous 0Yes ~Ye1i K, BACT NOx Limit, Continuous D Intermittent :g:j lN0 0No Monitoring Systern (CMS) (Unit B-0009) Navajo complies with the BACT requirements frir Requirement: The permittee shall B-0009, except for deviations previously reported comply with the aUowab1e emission or identified at the end of this repmt. limits in Table 106,A and Condition AJ 06.E that represent NOx BACT Emits I "Tl for the BACT requirements. (NSR z . ()] 95M35, Condition A204J and revised), :r- 0 0 0 0 ACC Form Part 1 Permit# P051-R2 & R2M1 0 01 Ver 4. 1 02/25/2015 N 0) .i:,,. """L , ....................... .l~......... - - - - - - - ' Page 84 of 144 EPA Inspection Report - Page 804 of 1969 Version 0225.15 11\/[o:nito:ring: C Continuous [2'.] Yes CYes ! (1) Tue Pcnnittec sha11 comp1y with the CMS monitoring as detailed in Condition I 1) Navajo complies with Conditon A.204.D, A204D, rs: Intermittent D No Kv.:?:,Jl l"!'~<'<v> (2) The pennittee shall conduct an EPA Method test vvithin six (6) months of permit issuance using EPA reference test methods in 40 CFR 60 for NOx and 0 2 and CO2. Data from the CJv1S Rl\.TA testing may be used to satisfy this testing requirement 2) B~0009 went into service on 4/14/2015. The initial RATA compliance test was completed on 11/06/2015, except for deviations previously reported or identified at the end of this report Reconikeeping: D Continuum, 0Yes 0Yes (1) The pcrmittee shall keep records ofthe CvIS initial calibration and recertification monitored in Condition A204.B, Summary of Compliance. (2) Records ofEPA Methods tests shall be maintained for the Boiler. Reporting: l) Navajo complies with A204.R 2) The initial compliance test was completed on 11/06/2015. [2'.] lnte:r.mJttent I D No [2'.] No < <----1----------------,,---+-------+----------l D Continuous rs:! Ye 0Yes (J) TI1e permittee shall report in accordance with Section B 110~ to include the CMS initial calibration and recertification. (2) The pennittee shall summarize m tabular fom1 the results of the EPA Methods tests fr,r NOx and 02 and CO2, specifying the emissions rates in pounds per hour and lb/Mlv1Btu. The table shall include the average concentration of al1 ~ relevant_pollutantspecies, 1) Navajo complies with Bl 10. 2) The initial compliance test was compteted on 1!/06/2015, except for deviations previously reported or identified at the end of this report rs:! Intermittent D No !,'g! No I "Tl z :r- 0 0 0 0 ACC Form Fart 1 Permit # P051-R2 & R2rv1 l 0 01 Ver 4.1 02/25/2015 N 0) 01 Page 85 of 144 EPA Inspection Report - Page 805 of 1969 Version 02.25.15 A204 Hcate.rs/BoHers L. MACT Subpart DDDDD, Industrial, Commercial, and Institutional Boilers and Process Heaters (Boilers and heatc'f subject in Table 103 .E} Navajo perrorms the annual tune up required by MACT Subpart DDDDD. Requirement: The units are subject to 40 CFR 63, Subpart DDDDD and the permittee sha11 comply with the applicable requirements of 40 CFR 63, Subpart A and Subpart DDDDD. Monitoring: The pem1ittee shal1 comp1y with.an applicable mon!toring ~:1d testing rcqmrcmcnts of 40 CFR 63, Subpart A I and Subpart ?DDDD, . Recortlkeepmg: The perm1ttee shall com~ly with the applicable recordkeeping reqwrements of 40 CFR 63, Subpart A and Subpart DDDDD. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 63, Subpart A and DDDDD. I~av,1_~ performs the annual tune up required by MAC 1 Subpart DDDDD. I I Records are maintained by Navajo Environmental Department MACT Subpart DDDDD reports were submitted semi-an:nuaHy as foUows: 01/30/2019 07/30/2019 I A204 Heaters/Boilers :!VI. EPA Methods Test (Unit B-0009) ~ Continuous ~ Intermittent ~ Continumrn ~ Intermittent I D Continuous ~ Intermittent D Continuous !ZJ Intermittent D Continuous 2$] Intermittent ~Yes 0No 2;J Yes D No I I !ZJ Yes I D No !Z] Yes CNo 2;J Yes D No 0Yes I ~No I I t 0Yes Rv:::7:J1 "n'-"o I - 0Yes ~No 0Yes !2:] No CYes 2;J No Requirement: Compliance with CO ! Navajo comphes with A204X. The initial ! BACT Limit and aHowable emission i compliance test was completed on 11/06/2015. I1 Emits in Table 106.A shall be ! dcmonstratcd by emissions tests ensuring I I zI the unit is operating correctly and within J "Tl desired parameters. (NSR 0195M35, :r- Condition A204J( and revised.) 1 0 - C C C ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , C ' ' ' ' ' " " ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' " " " " ' ' ' ' ' ' ' ' ' " " ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' " ' ' ' l______'c'c'c'c"" c'c',-'c'c'c'c'"""' 0 0 ACC FonnPart l Permit# P051--R2 & R2Ml 0 0 Ver 4, ! 02/25/2015 01 N 0) 0) Page 86 of 144 EPA Inspection Report - Page 806 of 1969 Version 0225-15 Monitoring: The permittee shall conduct D Continuous ..... ! l:8] Yes 1 D Yes an EPA Method test no later than 180 I days after permit issuance using EPA reference test methods in 40 CFR 60. Navajo compUes vdth A204.R The initial Emission testing is required for CO. Test compliance test was compk~ted on 11/06/2015. results that demonstrate compliance with [Z] Intermittent ! D No t8J No the CO emission limits shaU a1so be considered to demonstrate compliance ! ;~~o~:k~~~n=~iss~~~:!t~o .of "EP,\ _ .. . Methods tests shaU be mamtamed for the Boiler. ~ N , l' 'ti.. ')04 B Th m'1"t1'al ------ro~:~;~nuous awl) o comp ies \Vl 11 /)J., . . " compliance test was completed on 11/06/2015. I [g] Intermittent I ~ Yes ! D No I O Yes I I ~ No Reporting: The pennittee sha11 report in accordance with the requirements of Section B 111,D and summarize in tabular form the results of the EPA Methods test for CO, specifying the emissions rates in pounds per hour. The tab1e shaH include the average concentration of all relevant The initial compliance test was completed on 11/06/2015, except for deviations previously reported or identified at the end of this report MACT Subpart DDDDD reports were submitted semi-annually as foHows: 01/30/2019 07/30/2019 D Continuous t8J Inte:rml.ttent l2?J Yes 0No 0Yes !2?J No I:r-1~~~::~'::~ilcrs -----j-~Dcontlnnou, I0Yes I~Yes I N. Verification of Energy Efficiency [Z] Intermittent ! ~ No 0No BACT Control Requirements (Unit B~ 0009) Requirement: The pe1111ittee shall comply with the al1owab1e emission limits and the foUowing BACT requirements. (NSR 0195]\/135, Condition i\.204.L and revised) Navajo complies with these conditions. The most recent periodic inspection and tunc~u.p was completed on 04/09/2019, l, Operation and Maintenance (BACT #6): I "Tl z a. Periodic Boiler Tuning - :0r- The boiler shall be tuned 0 0 0 ACC Form Part 1 Penni!# P05 l-R2 & R2Ml 0 01 Ver4.1 02/25/2015 N 0) -..,J Page 87 of 144 EPA Inspection Report - Page 807 of 1969 Version 0225.15 annually to optimal efficiency, maintain thermal bo Periodic Boiler Inspection and Repair for air leakage - The boiler shall be inspected annually to maintain optimal therma1 efficiency, c. Periodic Boiler Inspection and C1eaning for tube fouling - The boiler shaH be inspected arnmally and necessary deaning perfi:.im1ed to prevent tube fouling. 2, Next Generation Ultra-low-NOx high efficiency burners (NGCLNB) (#5) shaU be installed in the boiler design. 3. Flue gas economizer (BACT #2) A heat exchanger shaU be fastaUed to recover heat from the exhaust gas to preheat incoming boiler feedwater to attain industry standard perfon11ance (IMO) for thermal efficiency. 4. Boiler insulation (BACT #4) - The boiler shal1 be designed and installed v,dth boiler insulation lo an optimum insulation thickness and material to achieve maximum energy efficiency, The OMP shall include the insulation design and maintenance schedule. I "Tl 5. Oxygen Trim Control {BACT #7) - z :r- An Oxygen Trim Control svstem shall :s: ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ 0 0 0 0 ACC Fonn Part I Permit# P051-R2 & R2M1 0 01 Ver4-102/25/2015 N 0) OJ Page 88 of 144 EPA Inspection Report - Page 808 of 1969 Version 0225.15 be designed and installed 011 the boiler to monitor oxygen concentration in the flue gas, and the inlet air flow is adjusted to maximize thermal efficiency, 6. Boiler blowdown minimization using manual analysis (BACT #3) ~ The Operation and Maintenance Plan (OMP) shafl include methods and procedures to minimize blmvdowns from the boiler to keep emissions at a mmmmm, 7. Condensate recovery (BACT #8): Condensate shall be recovered as represented. in the application to achieve maximum energy efficiency. Condensate recovery shall be maximized through annua1 steam trap i- in?ections and r~airs, M.onitoring: The Permittee shall develop an Operation and Maintenance Plan (OMP) to indude at 1east the requirements listed above within 12 months of commencement of operations, The Permittee shall review the OMP annually to ensure ifs effectiveness in meeting the requirements above and recommend changes, -1-- Navajo complies with these conditions. The initial compliance test was compkted on 11!06i2015, The OMF was submitted on 04/12i2016. ! D Continuous ;g] Intermittent 1 ...............................................;......._ _ _ _ ___, ~Yes 0Ycs 0No L]No Recordk.eeping: (1) Records demonstrating compliance with the energy efficiency requirement shail be recorded and summarized in the I Navajo complies with these conditions, D Contim1.ous ~ :Intermittent 0 Yes D .No [ 0Yes ii !r,.;:;:;;::.:''l.::":J'.l'~"v ! OMP. I "Tl (2) The Pen11ittee shaU maintain a copy of z the OMP onsite and available for :r- 0 0 0 0 ACC form Part 1 Permit# P05 l-R2 & R2M1 0 01 Ver4.1 02/25i2015 N 0) (!) : Page 89 of 144 EPA Inspection Report - Page 809 of 1969 Version 02-25, 15 fi.n-sp-e-ct_ion,.. , , - - - - - - - - - - - - - - - 1 - - - - - - - - - - - - - - - - - - - - + - - - - - - + - - - - - , c c c c c c c c c c Reporting: L.-J, t-:o:ntinuous ~Yes (1) The pennittee shall notify the Department when the OMP has been prepared and available for reviev,-. (2) The permittee shall report in the semiannual report a summary of actions Navajo complies with these conditions. The OMP was updated during this reporting pe1iod. Reports required by B110 are submitted as applicable. [X] lnte:r.mJ.ttent 0No covered 111 accordance with the OMP, and in accordance with Section Bl 10, A204 Heaters/Boilers D Continuous ~Y!c t--"' """0Ycs [X] No 0Ycs ..- - - - 1 O. Periodic Emissions Tests (Unit B-009, CO BACT Limit) ~ Intermittent 0No [ZJ No Requirement; Compliance with the CO Navajo complies with these conditions, , BACT Limit and a11owab1e emission ' hmits in Table 106.A shall be demonstrated by perfonning periodic emissions tests. f------------------------i-- Monitoring: The pem1iHee shall conduct periodic portable analyzer emission tests or EPA Reference Method Tests for CO at the intervals in the fo11owing schedule: First Test --- in accordance with the schedule in Section B111.A(2). Second Test --six (6) months after the first test is completed. All subsequent testing shall be done annually, Navajo complies with these conditions. Periodic test completed on: 03i20!2019 L~J Continuous L:8J Intermittent ~ Yes D No ,cc,cccccc t .......... ~------- -----1 ' 0Yes L:8J No Section B108 General Monitoring Requirements apply to this condition, The permittee sha11 meet the testing requirements in Section B] 11, I "Tl z Record.keeping: Records of periodic I Data is maintained in PL :0r- emission tests shall include the boiler fuel 0 0 0 ACC Fonn Part 1 Permit# P051-R2 & R2M1 0 01 Ver 4-1 02125/2015 N -..,J 0 D Continuous [ZJ Yes 0Yes Page 90 ofl44 EPA Inspection Report - Page 810 of 1969 Version 02.25.15 flow rate and the stack gas exhaust temperature. If a combustion analyzer is used to measure CO, and/or excess air in the flue gas, records shall be kept of the make and mode] of the instrnment and instrnment calibration data. If an ORSAT apparatus or other gas absorption analyzer is used, the perrnittee shall record all calibration results. Records shall be kept of an raw data used to determine flue gas flow and of an calculations used to determine flow rates and emission rates. The pennittee shall maintain records in accordance with Section B109, Bl 10, and Bl 11. Reporting: The permittee shall summarize in tabular form the results of the initial or subsequent periodic emissions tests for CO, specifying the mass emissions rates in pounds per hour. The table shall include the average concentration of alI relevant pollutant species. TI1e perrnittee shall rep01t in accordance with Section B109, B110, and BllL Reports required by Bl09, Bl 10, and Bl 11 are submitted as applicable. ~ Intermittent 0No D Continuous ~ Intermittent ~Yes 0No ~No I 0Yes I ~No I "Tl z :r- 0 0 0 0 ACC Form Part 1 Permit# P051-R2 & R2Ml 0 01 Ver 4J 02/25/2015 N -..,J ...... Page 91 ofl44 EPA Inspection Report - Page 811 of 1969 Version 02.25.15 A206 Ffares A, FL-0400, FL-0403 t8'.I Continuous D Intermittent t8'.I Yes 0No 0Yes t8'.i No Rcqui.rcment: (NSR 0195M35, Condition A206.A) 1) FL-0403 (ALKY/CCR) is equipped with a flare (1) An alarm system in good working almm. order shall be connected to Flare FL-0403 which wm si&snal non-combustion of the 2) The fuel gas required lo provide supplemental gas. heat to either Flare FL-0400 or FL-0403 is monitored during add gas flaring by a flow meter. I (2) The acid gas flow meter for flare FL- No acid gas Haring has occurred since September 1 0400 or FL-0403 shall be operated and 5, 2006, calibrated at a frequency and by the procedure specified by the manufacturer, A chart recorder or data logger (electronic storage) shall continuously record the amount of gas measured by the flow meter. lVfonitoring: The fue1 gas required to provide supp1ementa1 heat to either Flare FL-0400 or FL-0403 as required under A105,B shaU be monitored during flaring by a now meter. l';8l Continuous D Intermittent t8'.I Yes 0No 0Yes t8'.i No The flow meter shall be operated continuous1y 24 hours per day, 365 days per year except for periods of flow meter maintenance or repair. The upper range ofthe flow meter shall The fuel gas required to provide supplemental heat to either Flare FL-0400 or FL-0403 is monitored during acid gas fiming by a fiow meter, be sufficient to record the highest expected flow rate of fuel gas sent to flare, The reading of this flow meter and the I flow meter to measure acid gas flow as "Tl z required under Condition Al 05,B shall be :0r- used to dete1111ine compliance with 0 0 0 ACC fonn Part 1 Pennit # P051-R2 & R2Ml 0 01 Ver4,1 02/25/2015 N -..,J N Page 92 of 144 EPA Inspection Report - Page 812 of 1969 Version 0225.15 --e--m---i-s--s-i--o--n---l-i-m---i--t-s--a--t--A----J--0--6--.--C----------------------------+----- --------------------------------------------------------------------------------~. l Record.keeping: (l) Records of all [8J Continuous [8J Yes 0Yes periods of operation during which the [8J Inte1mittent 0No [8J No flare pilot flame is absent as included in the MACT subpart CC semi-annual reports. 1) Flare pilot outages are included in the MACT CC semimmual reports dated as follows: O')l')Q/"J0" 19 (2) Records of the quantity of "<"'w,";, l 1 ' I d d . 1. 1 08;22tL019 supp ementa ue use unng eacu acu ) d -- R , d . f _ 1 fu i d ..--1 . . 'd t ....i 1 an 2) ecor s o supp1ementa e, use an gas uarmg l h me1 enflt o prov1ue fl .1 t] - - d - p are p1 ot ame are mamtame m . i. supp1ementa eat to are FL-04 00 or I : I I : I ' ; 1 flare FL-0403. (3) The pcnnittcc shall maintain records from the fimv meter of the amount of gas ! I I sent to the flare. Reporting: The pcnnittcc shall report in accordance with Section Bl 10. 1) Flare pilot outages arc included in the MACT CC semiannual reports dated as follows: 02/28/20! 9 D Continuous ~ Inte:rnlittent 0Yes IZJ No -1 ~y~ 0No !-----.. --------------------------------------------------------------------------------------------- _ A206 Flares --+-----08/22/2-019- - - - - - - - - - 1 - - - - - - L D Continuous 0Yes B. MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" (Flares listed in Table t 03,K) Requirement: The pem1ittee shall comply with all applicable requirements of MA.Cr Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" for all affected sources shown in Tables Navajo complies with all the requirements of MAC'I CC as shown for aU affected sources in table 103.R Navajo uses a third party LDAR contractor, except for deviations previously reported or identified at the end of this report IZJ Intennittent 25] No I ~y~ 0No ?:, 103,B. (63.640). I ----~------- ---------------------------- --------------------------------..-------+.---------i I JVfonitorino-: The pcrmittce shall complv I Navajo complies with all the r~quirements of_ D Continuom, I t2:! Ye D Ye "Tl . :s , . , - I MACT CC as shown for all affected sources m l z with the a_.1:l)phca,ble mo.mto'rimg and te_stmg- I I t a bl c 103 ,B , Nawu.o uses a thrrd party LD" n f"li"- 1\71 k:::J -'--"-tenmtten,, 1I 1D 1"''-"10 l"7l "'' V::::J ;~o :0r- reqmrements of 40_CFI::.. ~~h?~lt ~~ J contractor------------------- __ ____ 0 0 0 ACC Form Part 1 Permit# P051-R2 & R2_Ml Page 93 of I44 0 01 Ver 4.1 0212512015 N -..,J (,) EPA Inspection Report - Page 813 of 1969 Version 0225.15 Rcco.rdkccping: The permHtee shaU Navajo complies with all the requirements of Ocont:inumg, comply with the applicable recordkeeping MACT CC as shown for aH affected sources in table 103.B. Navajo uses a third party LDAR ~ Intermittent requirements of 40 CFR 63.655. contractor. ;,,,,,,,-----------------+-------------------...+--c.c.cccccccc. Reporting: The permittee shall comply Navajo complies with all the requirements of D Continuous MA.CT CC as shown for all affected sources in with the applicable reporting table l 03J3. Navajo uses a third party LDAR IBJ lnten:nittent requirements of 40 CFR 63.655. rnn!Tactor. 1-----------------+-----------------ccccc.jc A207 Sulfur Recovery Plant (SPR), !Z] Conthmou Tail Gas Incinerator ffGl) rz:l Intermittent A. Consent Decree Requirements for SRP and TGI [SJ Yes 0No 1S'J YetiJ 0No IBJ Yer; 0No 0Ycs [2J No 0Yes IB] No 0Ycs [SJ No Requirement; In addition to the applicable requirements ofNSPS, 40 CFR 60, Subparts J and Ja, the permittee shall accomplish the following: 1. Navajo shall route all Sulfur Recovery 1} Sulfur Recovery Plant (SRP) sulfur pit emissions are routed to the Tail Gas Incinerators and are continuously monitored as part of the Plant (SRP) sulfur pH emissions from the applicable Sulfur Recovery Plant's tail gas SRP so that sulfur pit emissions to the enlissions that meet the NSPS Subpart J limit for atmosphere either are eliminated or are S02. included and monitored as part of the app1foable Su]fu'.r Recovery Plant's tail gas emissions that meet the NSPS Subpart J or Ja Emit for S02. (CD ip 8.C.ii) 2) The SRP and TGU are operated and maintained, to the extent practicable, in accordance with the obligation to minimize SR2 emissions through implementation of good air pollution control 2, The SRP and TGI (and any practices required hy 40 CFR 60. 1l(d), at all times, supplemental contro1 devices) shall be including periods of start-up, shutdown, and operated and maintained, to the extent malfu:nctinn. practicable, in accordance with the obligation to minimize SRP emissions through implementation of good air poHution contro1 practices required by 40 CFR 60. 11 (d), at all times, including I periods of start-up, shutdown, and "Tl z malfunction. (CD 9f18.C3ii) :0r- ___(NSR__01?5~1~5, gg~~4~:,m A207.A) 0 0 0 ACC Form Part 1 Pcnnit # P05 l-R2 & R2Ml 0 01 Ver4.l 02i25/2015 N -..,J .i:,,. Page 94 of 144 EPA Inspection Report - Page 814 of 1969 !..............................,..........................,,,,,,,,,,,,______ Version 02.25J5 - - - - - - - - - - - - - - - - - - , - ,--------"""""'"________ ------------------------ -------------~~"------~-----~-~-----~ l\Jonltoring; The pern1ittee shaU comply ! AJJ t' b ~ , , . .. , ., ... , 1 ~ Continuom, j ~Ye;; 0Ycs 'th ti r bJ 't . , ,,-,, o t e contmuous momtorn arc op,;rateo, Wl . ie fapp lea ~- mom onng i maintained, and certified as required. reqrurements o N SPS Suopmi J or JfL 1 ~ Intermittent I I 0No ~No ~~~ ~~---.~~~-.-.~~~=.~~~~~=~~~n{,-n.~~~.-.-------------------+---------l--- u.-u.-.-.-. Recordkeeping: The pennittee shall i lZJ Continuom; [gj Yes 0Yes maintain records in accordance with the I Records are maintained by Navajo Environmental applicable requirements of NSPS I Department and on Pi. lZJ Intermittent 0No lZJ No f,,c~l.liJQArts.J ..an4.Ja...............................,................................................. .Reporting: The pe1111ittee shall report in accordance with the applicable requirements ofNSPS Subparts J and Ja. -CCCC-CCC,"CCCCCC-------i---------1- Navajo submitted NSPS Subparts J and fa reports semiannually as follows: 1/30i2019 I D Conti:mwm I ~ Intermittent lZJ Yes 0No 7!30i20l9 l 0Yes ~No A207 Sulfur Recovery Plant (SPR), Tail Gas Incinerator (TGl) D Continuous [gJ Intc:rm.ittent ~y. es 0No 0Yn, [gJ No B. The following BACT S02 -s,vork practices and equ1pment shall apply to the SRP (SRU3/TGTU3/TGB): (PSD-NM- 0195-M25) Maintain at least 98% SRP onstream operations, This includes curtailing refinery operations as necessary when SRU capacity is limited during planned stmtup, shutdown, and maintenance events, Navajo has instaHed BACT, and impkmented the work practices, as described in this permit condition, Maintain adequate SRP excess capacity to reduce the frequency and quantity of refinery excess 802 emissions. After the refinery expansion project proposed units are constructed, the proposed SRU3 wm provide at least 25% excess capacity. I "Tl Continue to maintain and use a z sulfur shedding plan to prevent :0r- or reduce acid .g....as flaring events 0 0 0 ACC Form Part ! Pennit # P051-R2 & R2Ml 0 01 Ver 4,1 02/25/2015 N -..,J 01 Page 95 ofl44 EPA Inspection Report - Page 815 of 1969 Version 02.25,15 ~ ,...-...-~...-~ .u...-...- -~- - ___ ....~ from refinery upsets, An acid gas flaring event is defined as excess S02 emissions greater than 500 pounds in a 24-hour period. The plan shall state specific actions that may be taken to reduce or prevent acid gas flaring. The actions taken during any event will he based on the refinery operators' discretion, considering safety and other factors related to prudent operation, This plan is subject to review by NhdED or EPA, and shall be amended upon written request by NMED or EPA. i ! The sulfur shedding p1an may ' include~ but is not limited to the following options: (a) Store sour water to reduce acid gas generation from the sour water strippers (b) Reduce the operating rate of one or more amine strippers to lower the acid gas generation rate (c) Reduce one or more hydrotreahng unit throughput rates to 1ower acid gas generation rate I Use hydrogen, when available, as , "Tl z L___ _______SRU fuel during startup and hot I :r- 0 0 0 0 ACC Fom1 Part 1 Permit# P05!-R2 & R2M1 0 01 Ver4.1 02/25/2015 N -..,J 0) Page 96 of 144 EPA Inspection Report - Page 816 of 1969 Version 02.2-5,J,,,5-,,,,,,,,,,~,,--""" ,,,,,,.,,,,.-1 ............,,..................................................................................,,,,,, -"' standby to minimize carbon deposits on the SRU catalysts. , During startup and shutdown and I to the extent practicable, process I vessels shall be depressurized I into other process equipment i rather than venting to a fiarc. i The permittee shaH document I instances when this is not i practicable, I A:207 Sulfur Recovery Plant (SPR), Tail Gas Incinerator (TGI) C. SRUl, SRU2, and SRU3 1) A flm.v meter is in place on the sour water stripper streams into Units SRU1, SRU2, and SRU3. [2;'.l Continuous [2;'.l Inkrmittent lxl Yes 0No OYes [2J No 2) The S02 CEMS and flow meter on foe Requirement: (NSR 0195M35, SRU1/SRU2 and S.RU3 incinerator stacks, and the Condition A207.C and revised) instruments used to measure sulfur concentration The permittee shall demonstrate compliance with the H2S, S02, lb/hr, tpy emissfon limits by completing the and How rates of the gas streams into SRUl, SRU2, and SRU3, are calibrated and maintained at a frequency and method specified by the manufacturer, or as dictated by operating following requirements, monitoring, conditions. The S02 CEMS follow tbe quality recordkeeping and reporting: assurance and quaUty contro1 procedures in 40 CFR 60 Subpart J and Appendix F, (1) A flow meter shall be installed, operated, calibrated, and maintained on the sour water stripper strearns that go to the SRUs. 3) The minimum acceptable level of data capture for aH instruments measuring flow and concentration of sulfur streams into the SRU1, SRU2, and SRU3 including the CEMS and fiow ' l\.?= ) ,An S02- CEMS and flow meter shaH I be installed on the SRU1/SRU2 _ ,and meters on the incinerator stacks shall be at least 9001,0 1.r.or eac1J. mont.h, ,.l'he 100Yo' lost da ta 111clude,0, periods when the concentration and corresponding SRU3 incirn:.,'fator stacks, In add1t10n, flow are not being measured as a result of I these units shall be equipped with , calibrations or breakdowns. The data capture is I instruments to measure. and record sulfur reported in the semi-annual NS.PS Subparts J and "Tl z concentration and flow rates of the gas Ja reports, :0r- streams into SRUl, SRU2, and SRU3. 0 0 0 ACC Form Part 1 Permit ti ?05 I-R2 & R2MJ 0 01 Ver4,1 02/25/2015 N --.J --.J Page 97 of J44 EPA Inspection Report - Page 817 of 1969 Version 0225.15 TI1e GEMS, flow meters, and data loggers shall he calibrated and maintained, In addition, the calibration ofthe S02 CEMS shall follow the quality assurance and quality control procedures in 40 CFR 60 Subpart J or Ja and Appendix E (3) The minirnum acceptable level of data capture for aH instruments measuring flow of sulfur streams into the SRU1, SRU2, and SRU3, as well as the CEMS and flow meters on the incinerator stacks, shaU be at least 90%) fr.r each semi-annual period. The 10% lost data \Vill include all periods when the concentration and corresponding flow are not being measured as a result of calibrations or breakdowns. Monitoring: The gas stream foeding SRUl SRU2, and SRU3 from the amine regeneration units and the sour water stripper shaJ] be tested at least monthly for H2S concentration. The permittee shall monitor the fo 11mvfrlg: (1) Flow rate of sour water stream to SRUs, (2) S02 concentration in SRU incinerator stacks and (3) Flow rate of the SRU incinerator stacks, 1), 2), and 3) Navajo complies with the requirements of this pem1it condition. I "Tl z :r- 0 0 0 0 ACC Form Part 1 Pcm1it # J'05 l-R2 & R2Ml 0 01 Ver4.l 02i25i20l5 N -..,J OJ I D Continuous ~ .Intermittent ~Yes 0No 0Yes ~No Page 98 of144 EPA Inspection Report - Page 818 of 1969 Version 02.25.15 NN---------- ---- --~ ---- ------------ Recordkeeping: The permittee shall maintain records in accordance with the I applicable requirements of NSPS I Subparts J or Ja and MACT Subpart r uuu. -------""-"t' n - - - - - - - , - - - - - - - - - . - - - - - - - - - ~ ~ Continuous [gl Yes OYes ~ Intermittent [gl No [gl No The permittee shall also keep records of the following: (1) Flow rate of sour water stream to SRUs, I), 2), and 3) Records are maintained by Navajo Environmental Department and on Pi. (2) S02 concentration in SRU incinerator stacks and (3) Flow rate of the SRU incinerator I stacks. I Reporting: The permittee shall report in Navajo submitted NSPS Subparts J, Ja and MACT accordance with the applicable Subpart UUU reports semiannually as follows: requirements of NSPS Subparts J or Ja, 1/30/2019 MACT Subpru.t UUU, and Section Bl 10. 7/30/2019 A207 Sulfur Recovery Plant (SPR), Tail Gas Incinerator (TGI) D Continuous [gl Intermittent D Continuous [gl Intermittent 0Yes [gi No ~Yes 0No ~Yes 0No 0Yes [gi No D. 40 CFR 60, Subpart J (Unit(s) SRUl Navajo complies with the requirements of Subpart and SRU2) J. Requirement: The permittee shall I , comply with the applicable requirements i ' I of 40 CFR 60, Su~:,~!:LL________________________________________________________ J ---------------------------------------------------------------------------------"'!-"-'----------,;------ I I ' Monitoring: The permittee shall install a i I l8J Continuous I l8J Yes I 0Yes continuous monitoring device to monitor I H-0473 SRUl and SRU2 TGI has a CMS installed. I compliance with the lhS limit. (40 CFR I I l8J Intermittent I 0No [ [gi No 6o:!os(a)(3-4))____________________________________ ----------------------L-- ------------------------------_,,_______ - - - - - - - - - - t - - - - - - - - - - - - i - - = - - I I Recordkeeping: The permittee shall I Records are maintained by Navajo Environmental [gl Continuous ~Yes i 0Ycs I maintain the continuous emission records. Department and on Pi. [gl Intermittent 0No [gl No "Tl z +-- :r- D Continuous I ~Yes [ 0Ycs 0 0 ..~.~~.~.~~:~~~....~.~~~.~:~--~~~l~------~~~~--~~----J----~~;1l~:::i~~i~:~o~~_ ~~: Su_ bpart_ J repo_ rts ___1__ _ __1__ _ _Li : 0 0 ACC Form Part l Pennit # P051-R2 & R2M1 Page 99 of 144 0 01 Ver4.l 02/25/2015 N -..,J (!) EPA Inspection Report - Page 819 of 1969 Version 02.25J5 1 1 wi:h the reporting requirements of 40 _CI<R 60, Subpart J, li30/2019 7/30/2019 r2:l Intermittent r D No rgj No A209 ~Fugitives A. NSPS Subpart GGG, Standards 1 As of May], 2016, Navajo has elected to compiy I with 60,592a(e) ofNSPS Subpart GGGa for all i process units affected by NSPS Subpart GGG of I regardless of \vhether or not those process units 0 Continuous r2:l Intermittent [8'.] Yes 0No 0Yes [2;J No Performance for Equipment Leaks of VOC in Petroleum Refineries for which ! construction. reconstruction, or ' modificatio~ commenced after January 4, have triggered NSPS Subpart GGGa applicability. Fugitive components subject to this rule are i included in the Leak Detection and Repair (LD.A.R) program. Nava~o ~ses a third-party co:1tr~~tor for I I 1983, and on or before N(wember 7, 2006 the LDAR momtonng and recordkeepmg.lhese are (Fuglfrves subject in Table l 03 .B) mon_itored and reported in a NSPS Subpart GGGa I I semiannual re 1ort ,------------------~--------------------1-'"-------+--------+.--. A~ of May 1, 201~, ~avajo has ele~ted to .comply Requirement: The pcrmittce shall w1th 60.592a(e} o1 NSPS Subpart GGGa 1or all O Contimwut;; rgJ Yetii 0Yes comply with aU applicable requirements process units affected by NSPS Subpart GGG r2:l Intennittent D No [2J No of NSPS Subpart GGG for an sources in regardless of whether or not those process units Table 103.B (affected units and have triggered NSPS Subpart GGGa applicability. 1 j l I ' voluntarily units), This table also Fugitive components subject to this rnle are includes areas that are vo1untarily following the NSPS Subpart GGG monitoring requirements. (See footnote 1 to Table 103.B) lVfonito:ring: The permittce shall comply with. all applicable monitoring reqmremm1ts of 40 CFR 60, Subpart included in the Leak Detection and Repair (LDAR) program. Navajo uses a third-party contractor for the LDAR monitoring and recordkeeping.These are ; monitored and reported in a NSPS Subpart GGGa ! semiannual Nav~jo :ises a third-party c~mtractor for the LDAR momtonng and rccordkccpmg. 1 I I D co:ntimmm; I .._.. , I [8'.] Intermittent [8'.] Yes 0No 0Yes [8'.] No GGG, 1 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - + - - - - - - - - - ;-- + .......... ---.---------! Reco.rdkeeping: The pem1ittce shall D ConUnuous [8'.] Yes 0Yes comply \vith aU apphcab]e recordkeepfag Navajo uses a third-party contractor for the LDAR requirements of 40 CFR 60, Subpart monitoring and record.keeping. [8'.] lntt>:r:mHtent 0No [8J No GGG. Reporting: The pcrmittee shall comply with the app1icah1e reporting requirements of 40 CFR 60, Subpart Navajo submitted NSPS Subpart GGGa reports semiannual.ly as follows: 2/28/2019 0 Continuous [8J Intermittent [8'.] Yes 0No 0Yes !SJ No GGG. I "Tl "Z"'"' F 't' , z .& u::., . ug1 nes :r- 0 0 0 0 ACC Fonn Part 1 Penni!# P051 -R2 & R2M l 0 01 Ver 4.1 02/25/2015 N OJ 0 8/22/2019 Navajo continues to comply with the applicable reqm,rements of "1~"'Sl),"::, 0c ubpart G'GG'a as app1ica'ble, .. ex:ct:p; .. f2!.th?.4?Y!?:~l?!!?.PT~Yi?Y?1Y D Continuom, cc j, [8'.] Yes D Yes Page 100 of 144 EPA Inspection Report - Page 820 of 1969 Vernion 02.25.15 B, NSPS Subpart GGGa, Stan. dards of Performance for Eqmpment Leaks of VOC in Petroleum Refineries for \vhich . Con~t:uct~on, Reconstruction, or I, h1o<lihcatlon Commenced After ! N.1 o. vemiu. er 7, 2006. (Fugi.tr,ves subJ, ect m. Table 103J3) re, port,ed or identified at th e end of this re, port, h1g,bve components subJect to either of these rules are included in the Leak Detection and Repair (,LDAJ~.) progra~, Navajo us:s a.third-party contractor for the LDAR momtonng and record.keeping . I K7l k'.::,I 1nterm1, ttent I D . 7 No ~No Requirement: The permittee shall comply with all applicable requirements of NSPS Subpart GGGa for all sources in Table 103.B (affected units and voluntarily units} This table also inc1udes areas that are voluntarily , fi)Howing the NSPS Subpart GCK1a , l I~--;:: ........,.................. monitoring rec uirements. :lV[onitoring: The pennittee shaU cmup]y vvith all applicable monitoring requirements of 40 CFR 60, Subpart Navajo uses a third-party contractor for the LDAR monitoring and rccordkeeping. D Conti.nuous I L8J lnte:rmHtent I D No ,t....... l OYes [8'.l No GGGa. Recordkeeping: The permittee shall comp]y with all appHcabJe recordkeeping I Navajo uses a third~party contractor for the LDAR requirements of 40 CFR 60, Subpart monitoring and recordkeeping. D Continuous ~ Intermittent I IT;'.] Yes ! D No OYes [8'.J No GGGa. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart GGGa. A209 Fugitives c. MACT Subpart CC, "Nationa] Navajo submitted NSPS Subpart GGGa reports semimmually as follows: 2i28!2019 8/22/2019 D Conti.uuom, ;s;'.l Intermittent ;s;'.l Yes l D No D Continuous ~ Intermittent . I [8'.l Yes I D No 0Yes [sl No ""''.. 0Yes ~No , ....... J Emission Standards for Hazardous Air The Gasoline Loading Rack is equipped with a Pollutants :l:'i'om Petroleum Refineries" carbon adsorption system. (Fugitives subject in Table 103.B) I "Tl z :0r- ! Requirement: The permittee......~.~!~IL., ..................................... ........ . . - ..........,,,,,,. 0 0 0 ACC form Part 1 Perm1t # P051-R2 & R2Ml 0 01 Ver4,l 02/25/2015 N .O..J.. . .... Page 101 ofl44 EPA Inspection Report - Page 821 of 1969 Version 02,25,15 comply \vith all apphcab]e requirements of MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" for all affected sources shown in Tables 103,R (63.640), For all activities in Table 103,B that are not subject to MACT CC, the permittee voluntarily perfo1ms a LDAR program for those tu1lts and that program meets the 1 requirements ofMACT CC I Monitoring: TI1e pennittee shaU complv Iwith the applicable monitoring and testing \ ~9~~:~~~~~E~!~?f ~Q~FR 63) Subp~1! ~c.'.,,, The Gasoline Loading Rack carbon absorption has a VOC CEMS installed in the exhaust air stream, ksl Continuous D Intermittent i2:] Yes 0No i Recordkeeping: The permittee shall Records are kept by Holly Energy Partners (HEP) lZJ Contim:n:nrn ksJ Yef! I comply with the applicable record.keeping either at the Gasoline Loading Rack or at the HEP j requirements of 40 CFR 63.655, A.rtesia Office, ~ Intermittent 0No . .. ,,...,,,..,,,,,,,,,,,,,.._._.,,,,,,,,_._.,,,,,,,,_._._._._._._._.,,,,,,,,,,,.._._.,,,,,,,,.._.,,,.._._.,,,,,. ....,,,,,,,,,,,,,,_._.,,,,,,,,,,,,.,,,,,,,,,,,,.::=~==~~-:;;--;;--:;---:-:::-:::::::-----+-----1-: Reporting: The permittee shall comply Nav~jo submitted NSPS Subpart GGGa reports D Continuous lZJ Yes ~~(~J; with the applicable reporting senn?nn,mlly as follows: I requirements of 40 CFR 63.655. 28 1 /22 9 i2:] Intcrmitte:nt 0No r- l\209F;gitive~---------------------------------------------------------+----------~-: ' ,,,c !------.. ------------------4------l- D Continuous I 0Yes 0Yes ksJ No 0Yes ksJ No 0Yes [8J No [ZJ Yes l D. NSPS Subpart QQQ, Standards of I Navajo cru1ti,mes !o comply with fae applicable I Pcrlormance for VOC Emissions from .i requirements ofNSPS Subparts QQQ throughout [21 Intermittent I l8'.1 No 0No Petroleum Refinery Wastewater Systems I the refinery: exc~pt for deviations previously (Fugitives subject in Table 103,B) i reported or 1den~1fied at the,end of this report Oily i water sewer dram hubs are mspected at least :P Rc11uiremcnt Th 'tt _]] I monthly, Junction boxes, and the oil-water ,? - ] ,. ble pen1:1 ee s11a ?0!1 1Y I separator arc inspected. at least semi-annuallv. w1 to 1 ai appi1H.:a e reqmrements of NSPS, [ 40 CFR Part 60,690, Subpart QQQ, . 1 Navajo continues to comply with the applicable Monitoring: The permittee shall comply requirements of NSPS Subparts QQQ throughout j -+cccc , ....................... <-------l D Continuous 0Yef! [gj Ye1, with the applicable monitoring and testing the refinery, except for deviations previously ~ Intermittent f-71 l'<l,. k::::j l.,H 0No I requirements of 40 CFR 60, Subpart reported or identified at the end of this report Oily "Tl z QQQ, (60,695) water sewer drain hubs are inspected at least :r- monthly. Junction boxes, and the oil-water 0 0 0 0 ACC Form Part 1 Pennit # P05 l-R2 & R2M1 0 01 Ver 4J 02/25/2015 N OJ N Page 102 of 144 EPA Inspection Report - Page 822 of 1969 Version 02.25. 15 --------- --------------------------------------- ------ --------------- ____scparator_ arnim;pecte~ at_least semi-annuaUy. Reco:rdkeeping: The permittee shall Records are maintained by Navajo Environmental comply with the applicable recordkeeping Department, except for deviations previously requirements of 40 CFR 60.696. reported or identified at the end of this report Reporting: The pcnnittee shall comply with the applicable reporting requirements of 40 CFR 60.697. Navajo submitted NSPS Subpart QQQ reports semiannually as follows: 1/30/2019 7/30/2019 uuuuucccccccccc ------------------------ -~-~.u~ .~~~uu.-.-.-.-.- -------------~~~~~-- D Continuous 0Yes ~ fotennittent rE] No "~"---- nun D Co.ntimmus 0Yes 0 Intermittent 0No ! I ~Yes ! ' 0No 0Yes 0No uuuu.-.-.-.-.- I "Tl z :r- 0 0 0 0 ACC FonnPart l Permit# P051-R2 & R2Ml 0 01 Ver 4.1 02/25/2015 N OJ (,) Page 103 of ] 44 EPA Inspection Report - Page 823 of 1969 Version 02,25, 15 I A209 Fugitives l J O ~o~;~~~~~~--------r-~--~, e;,, i O Yes I E. :tviinor changes within the facility to piping and components that affect fugitive voe emission source shall be updated and added during the next avai1ab1e Signifi.ca:nt pennit revision in accordance with 202.72 NMAC The facility \Vide fugitive VQC emission limit shown above and in Table 106,A of this permit A210 Loading Racks Navajo understands that minor changes to the facility piping and components that affoct fugitive emissions will be added during the next permit modificaiton. lZJ Intermittent 0No ~ Continuous ! [8:l Yes [2'.l No 0Yes A. Truck and Rail Loading (Unit shown in Table 106.G) ~ lnte:r:mittent ! D No ~No Requirement: Compliance with the Navajo complies with these requirements, allowable emission limits in Table l 06.G shall be demonstrated by not exceeding the monthly mlHng t2-month tota] throughput for each loading rack for each different product in gallons per year I {baffels/year), Monitoring: The pennittee shaJ] monitor the throughput volumes 011 a monthly Tb~ Tr~ck. & Ra.il L~ading Rack~ volumes are mamtamed by Nava,1o's Accountmg and basis, ! Environmental Departments, ! [X Continuous ! 0 Yes [X Intermittent D No ! C Yes [8:l No Reco:rdkeepi:ng: The pennittee shall ~ Continuous [8:l Yes D Yes record the monthly throughput vo1umc for [8'.l Jntennittent D No t8J No each loading rack for each different product Each month during the first 12 The Trnck & Rail Loading Racks volumes are months of monitoring the pe1111ittee shall maintained by Navajo's Accounting and record the cumulative condensate loadout Environmental Departments, volume and after the first 12 months of I monitoring~ the pe1111ittee shall calculate "Tl z and record a monthly rolling i2-month :0r- total loadout volume, 0 0 0 ACC Fonn Part l. Permit# P051-R2 & R2Ml 0 01 Ver4.1 02/25/2015 N OJ .i:,,. Page 104 of 144 EPA Inspection Report - Page 824 of 1969 Version 0225, 15 f cccccccccccccc Records shall also be maintained 111 accordance with Section Bl09, Reporting: The pem1ittee shall report in accordance with Section Bl 10, A210 Loading Racks Navajo submitted MACT Subpart CC reports semiannually as follows: 2/28/2019 8/22/2019 B. Fuel Tmck Loading Rack (Units subject in Table 103,D) (40 CFR 63, Subpart CC) D Cont:i:numn. ~ Intermittent ~Yes 0No ~ Continuous ~ Intermittent I !SJ Yes I D No 0Yes !ZJ No 0Yes uu~.-.-.- ~No Requirement: The pennittee shall . , comp1v w1'th a 11 app. 1w' able reqm,rements I Thet Truck . Loadmg 1 d Rack has a carbon absorpt10n or.-"iv,,~(A.C, T.Subpart c.C,, N1 atm. na1.Emr,nsm, n sys em ms1a11e , Standards for Hazardous Air Pollutants From Petroleum Refineries. SpcciaHy, the truck loading rack shaD be equipped wlth a carbon adsorption system for compliance with the ?vi.A.CT requirements. l\!lonitoring: The pennittee shall comply with the applicable monitoring and testing requirements of 40 GFR 63, Subpart CC rs:] Continuous D Intermittent ~ Yes D No 0Yes ~No SpedficaHy 63A27(a)(2), where a carbon adsorption system is used, a continuous The Truck Loading Rack has a CEMS installed, emission monitoring system (CEMS) capable of measuring organic compound concentration shall be installed in the exhaust air stTeam. Recordkeeping: The permittee shall comply with the apphcab1e recordkeeping requirements of 40 CFR 63, Subpart CC Records are kept by Holly Energy Pmi:ners (HEP) either at the Gasoline Loading Rack or at the HEP Artesia Office. ~ Continuous D Intermittent ~ Yes D No 0Yes ~No Reporting: The pern1ittee shaU comply Navajo submitted MACT Subpart CC reports D Continuous ~ Yes 0Yes I semiannually as follows: "Tl ,:vith the applicable reporting z 2/28/2019 ~ Intermittent D No ~No requirements of 40 CFR 63, Subpart CC 8/22i2019 ! :r- ,____________________________..______________________________~--< u-u-- <<-------------------~---- ------------------------ ,,__,, =l NN~N l 0 0 0 0 ACC Form Part l Permit# P05 t-R2 & R2Ml Page 105 of 144 0 01 Ver4,l 02/25/2015 N OJ 01 EPA Inspection Report - Page 825 of 1969 Version 02.25.15 I "Tl z :r- 0 0 0 0 ACC Form Pmt 1 Permit# P051-R2 & R2Ml 0 01 Ver 4.1 02/25/2015 N OJ 0) Page 106 ofl44 EPA Inspection Report - Page 826 of 1969 Version 02.25.15 ' i211 Fluid Catalytic Crncking Unit (FCC) A. Continuous Monitor Systern(CMS) (Unit FCC REGEN) ~ Continuous ~ Intermittent D Yes ~ No ,uuu------------0 ~Yes 0No .Requirement: (J) Consent Decr:ee Limits on PM ani:LfiQ;c emissions from the FCC: By 110 later than December 31, 2003, the Wet Gas Scrubber (WGS) on the FCC Regenerator shall comply with the follo'>ving limits: l d) The FCC cataiyst regenerator exhaust is continously monitored for SOL (CD 1[12.B & 1[13.B) 1e) The catalytic cracking regenerator is tested (d) S02 concentration not to ex.ceed annually for PM and was tested on the following 25 pprnvd on a daily rolling 365- date: day average basis and 50 ppmvd 02/13/2019 on a daily rolling 7-day average basis, each corrected to 0% oxygen. Compliance with this emissions limit shall be li) Navajo has submitted an a1ternative monitoring plan (A\:IP) to comply with the FCC opacity monitoring requirement because the FCCU has a wet scrubber which prevents continuous opacity demonstrated on an ongoing monitoring. Under the AMP, opacity is monitored basis through the use of CMS; weekly using 40 CFR 60 Appendix A Method 9. and 2) The FCC exhaust is continously monitored for (e) a particulate matter (PM) NOx and CO. Deviations were reported to the emission limit of 1.0 pound of Department as excess emfasion events and on the PM per 1000 pounds of coke NSPS Subpart J report. burned cm a 3-hour average basis (CD 1P3.B). To demonstrate compliance with this requirement, the Pem1ittce shaU conduct an annual EPA Method 5 Test for PM and weekly EPA Method 9, OJ:1acity Test in I "Tl accordance vvith their approved z Alternative Monitoring Plan :r- 0 0 (AMPJ 0 0 ACC Form Part 1 Permit# P051-R2 & R2Ml 0 01 Ver4.1 02/25/2015 N OJ -..,J Page 107 of 144 EPA Inspection Report - Page 827 of 1969 Version 02.25, 15 (f) As the FCC Regenerator is subject to the provisions of 40 CFR 60. l 02 (NSPS Subpart J), it shall not discharge to the atmosphere gases exhibiting greater than 30 percent opacity, except for one six-minute average opacity reading in any one-hour period, ....... - - - - - - - - - - - - - , - - - - - - - - ~ I (2) Consent Decu;.Q___Li1:p.its __Q_n____N.Q~__.J.+:ng I CO emissionsfrom the FCC: The FCC shall comply with NOx and CO emission limits as follows: (a) The concentrntfon-hased (ppmvd) NOx emission Emit , based on daily rolling 7-day and daily rolling 365-day averages, corrected to 0% oxygen as estabHshed pursuant to the Consent Decree, unless EPA rejects the proposed limit and estah1ishes a different NOx emission limit, in which case the FCC shall comply with EPA's established limit Under no circumstances shall this emission limit be greater than a concentration-based limit that would be equivalent to 34.9 lbs/hr. The 7-day FCC NOx emission limits, shall not apply during periods of Hydrotreater f Outage provided that the FCC I I "Tl (including associated air i z pollution control equipment) is I :r- 0 0 ~ - - - - -m-aiunta~ineud ..-.-.-a.-.-..n.-.-.-.-d.-.-.......o.~-~-reratcd i~n a~~~~~ i ,n n n n n . - - - - - - - - - - - - - - - - - - , 1 , w ~ - - - - - ~ 0 0 ACC fonn Part 1 Permit# P051-R2 & R2Ml Page 108 of144 0 01 Ver4,l 02/25/2015 N OJ OJ EPA Inspection Report - Page 828 of 1969 Version 02.25,15 manner that mm1m1zes emissions in accordance with m1 EPA-approved good air po11ution control practices phm. Navajo shall comply with the plan at all times, including periods of start1ip, shutdown, and ma hydrotreate 365-day av limit shall of hydrotr NOx Hmits ! ! ! I I (1) 87,3 1 corre ' daily avera (2) 58, 1 corm daily avera (b) The NSPS Sub of 500 ppmvd CO a 1-hour average l CO corrected to 00, 365-day average b 31_,__200 December_ ---------------------------- ---~~------~~~---uunn nun~ ""~ 1\fonitoring: , (]) A continuous monitor system (Cl'v1S) for CO, 02, S02 ant NOx shall be 1) The FCCU Catalyst Regenerator Scrubber exhaust is continuously monitored for CO, 02, , S02, and NOx. PM is monitored annually. ~ Contirmous ~ Intermittent [;gj Yet;; 0No 0Yes ~No instaHed, cahhrated, maintained, and 2) The FCC regenerator CMS were recertified on operated on the FCC Catalyst the following dates: I Regenerator vent stack(s) downstream of co 02/13/2019 "Tl z the scrubber in acco dance with 40 CFR S02 02/13/2019 :0r- Part60,160) 3,_Ap1 endix A, and the NOx 02/13/2019 0 0 0 ACC Form Part 1 Permit# P051-R2 & R2M1 0 01 Ver 4. l 02/25/2015 N OJ (!) uuuuuu~. ---------------- -------- -~~~~~~ Page l 09 of 144 EPA Inspection Report - Page 829 of 1969 Version 0225, 15 applicable pe1formance specifications of Appendices B (Specifications 2 and 3) andF. The CMS shall be used to demonstrate compliance with CO, S02 and NOx emissions limits and to report compliance with the terms and conditions ofthe Consent Decree. 02 02/l 3/2019 3) CMS data is used to ensure emissions Emits are met 4) The catalytic cracking regenerator is tested annually for PM and was tested on the following date: 02/13/2019 ~uu. .-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.~. .. ~~~~~n I ! I I The CMS and process data shaU be made available, by permittee, to applicable Federal and State Agencies (NMED) upon demand as soon as practicable. (CD ~1 LF, 12 D, and 14.C) (2) 111e FCC Regenerator Scrubber NOx, S02, CO and 02 CMS shall be recertified ammally, Nawtjo has submitted an alternative monitoring plan (A.MP) to comply with the FCC opacity monitoring requirement because the FCCU has a wet scrubber which prevents continuous opacity monitoring. Under the Al\1P, opacity is monitored weekly using 40 CFR 60 Appendix A Method 9, (3) The CMS data shall be monitored to ensure the CO, S02 and NOx emission limits for the FCC are met , (4) The Permittee shall conduct an I annual EPA Method 5 Test for Ptvr and weekly EPA Method 9 Opacity test to demonstrate compliance with the particulate matter (PM) emission limit of l 1,0 pound of P\'1 per ] 000 pounds of ! coke burned on a 3-hou:r average basis and opacity limit of 3mL Pe1111ittee shall meet testing requirements ofB11L ----------------- -- ---------- -~~---~~~--~~~=~~ ~......... ""'""----.-.- Recordkeeping: The permittee shall maintain the records of: 1), 2), 3), 4), and 5) Records are maintained by [2'.l Continum.rn r8J Intermittent rgj Yet. 0No 0Yes rgj No I Navajo Environmental Department and on PL "Tl z (1) The certification and re-certification :r- of the CMS, 0 ~"""""------.-.-.-.-.-.---.-.-.-.-.-.-.-.-. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ." " " ' 0 0 0 ACC Form Part 1 Pennit # P051-R2 & R2Ml 0 01 Ver4.1 02i25/2015 N (!) 0 Page 110 ofl 44 EPA Inspection Report - Page 830 of 1969 Version 02.25.15 I (2) Modifications to the FCC' s good air pollution control practice p1an to mm1m1ze NOx em1ss1ons shall be surnmarized on an annual basis if any changes were madeo ( CD ~11.G) (3) The pe1111ittee shall keep records of C!v1S data monitoring N02, S02, PM10 and CO emissions from the FCC (CD ~1 LF, CD T12D & CD 9114.C) (4) Records of NOx, CO, S02 ppmvd, lb/1u, tpy; PM lb/1u, tpy and opacity. TPY shall be based on a monthly roHing 12- month totaL (5) The permittee shall keep records of annual PM stack tests and weekly Method 9 observations conducted on the FCC For any opacity obsc1Vations conducted in accordance with the requirements of EPA Jvfothod 9, record the infommtion on the fonn referenced in EPA Method 9, Sections 22 and 2A ~ - - - - - - - - - - - - - - - - t - - - - - - - - - - - - - - - - - - - + - - - - - - - + - - - - . t .. ~----..............i Reportino: The pennittee shall report 111 Nav~jo su.bmittc~ NS.PS Subparts J and Ja reports D Continuom, ! !8J Yer,; 0Yes 0 "' . . . . senuannually as foUows: acco~ dance w1t~ Section B 110 and testmg 1/JO/lO19 [2l Intermittent l D No Kk:7'.l\J"r<''o reqmrements of B 111. 7/30/2019 I "Tl z :r- 0 0 0 0 ACC Fom1 Part 1 Permit# P051-R2 & R2M1 0 01 Ver 4J 02/2512015 N (!) ...... Page 111 ofl 44 EPA Inspection Report - Page 831 of 1969 Version 0225.15 A2H Fluid Catalytic Cracking Unit (FCC) B. Perfonnance Testing (Unit FCC REGEN) D Continuous 0 Intermittent 0 Yes D No 0Yes 0No I Requirements: (1) The permittee sbalI demonstrate compliance with the NSPS Subpart J particulate matter emission limit at Table 106.A by conducting an initial performance test in accordance with NSPS Subpart A, 60.8 and NSPS Subpart J, 60.106(b). The particulate matter stack test shall be repeated on an annual basis, I Navajo comp.lies with the requirements of NSPS Subpart J, Ja, MACT Subpart A, and ll1J1J, (2) The permittee shall comply with all applicable performance testing requirements in accordance with MACT I ! Subp:1rts _A and U~JU, I """""!""""" +~-----------l----- Momtormg: Testmg shall be conducted D Continum:rn I ~ Yes 0Yes in acc?rdance with N~PS Subparts A and ~avajo complies w1,t~ :he rcquircmentvs '.J~ NSPS J, and maccordancev,nthMACT Subparts Subpart J, Ja, MACl Subpart A, and {_;UL. !ZJ Intermittent I D No 0No A and UUlL Record.keeping: The pennittee shall maintain performance test records in accordance with NSPS Subparts A and J, MACT Subparts A and UUU, and in accordance \Vith Section B109. Navajo complies with the requirements of NSPS Subpart J, Ja, MAf'.T Subpart A, and UUU D Continuoni;i , !ZJ Intermittent ! 0Yes 0No OYes rz:iNo Reporting: The permittec shall rc1)ort ! D Continuous !ZJ Yes OYes perfonrnmce test results in accordance ' Navajo complies with the requirements of NSPS I ~ .Inte.rmlttent 0No [gJ No I with NSPS Subparts A and J, JVL'\CT Subpart J, Ja, MACT Subpart A, and UUU. "Tl Subparts A and UUU, and in accordance z with Section B 110, I :r- 0 0 0 0 ACC Fom1 Part I Permit# P051-R2 & R2Ml Page 112 of 144 0 01 Ver 4.1 02/25/2015 N (!) N EPA Inspection Report - Page 832 of 1969 Version 02.25.15 A212 Cooling Towers A, TvfACT Subpart CC, '"Nationai Emission Standards for Hazardous Air Pollutants from Petrolemn Refineries'" (Cooling Towers subject in Tab1e 103.F) Requirement: The pennittee shall comply with all app1icab1c requirements Navajo complies with the applicable requirements for heat exchange systems, except for deviations previously reported or identified at the end of this report of 40 CFR 63, Subpart CC for heat exchange systems for an affected sources shown 111 Table 103.F attached. (63.654(a), 63.640(h)(6)) Monitoring: The pe1n1ittee shall comply I Navajo complies with the applicable requirements with all applicable monitoring and testing for heat exchange systems, except frn deviations requirements of 40 CFR 63, Subpart CC, previously reported or identified at the end of this (63.654(c), (d), (e), (f)} report Recordkeeping: The permittec shaH comr1y with aJ] applicable recordkeeping reqmrements of 40 CFR 63, Subpart CC Records arc maintained by the onsite LDAR contractor and by the Navajo Environmental l (63.654(g), 63,655(i){4J,(i}(S)) R~porting: . Tue permi~cc shall_ comply w1th aU apphcab1e reportmg reqmrements Department Nav~1jo submitte~ MAC'f Subpart CC reports semrn:nnually as follows: of 40 CFR 63, Subpart CC (63.655(), 2/28/2019 (t)(] )(vi), (g)(9), (h)(1 }, (7)) 8/22/2019 AZ U Cooling Towers 1) Navajo operates with less than six (6) recirculating pumps per heat exhange system. B. Cooling Tower Operations (Cooling Towers subject in Table 103,F) 2) The pump capacity is less than 65,500 gpm D Continuous rZJ Intermittent I D Continuous I rgj Intermittent D Continuous rgj intermittent D Continuous rZJ Intermittent D Continuous r8J Intennittent rgj Yes D No rgj Yes 0No rgJyes 0No k$J Yes 0No rgj Yes 0.No 0Yes r2:J No 0Yes [;8J No 0Yes rgj No 0Yes [:gj No uuuu .-.-.-.-.--.-.----- 0Yes r8J No _ , . 3) The Total Dissolved Solids (TDS) is sampled by Requirement: Comphance with !he the Nav.tjo Lab and results maintained in the aHowable emission limits in Table 106.H VortalBUSS system and maintained by the Navajo shall be demonstrated by meeting the Environmental Department following requirements: I "Tl 4) Drift eliminators installed are rated by the z 1) operate a maximum of six (6) manufacturer for 0.001 % or CL003 drift, :r- 0 0 1 recirculating pumps at any one ------------------------------------------------------------------------- ___ ,,,,,,. ,, 0 0 A.CC Form Part 1 Pcnnit # P05 t-R2 & R2M l 0 01 Ver4.l 02/25/2015 N (!) (,) ; I I I I , Page 113 of 144 EPA Inspection Report - Page 833 of 1969 Version 02.25,15 time; 2) ensure that each pump capadty shown in Tab1e 104,A are not exceeded gallons per minute for each cooling tower (65,500 gpm total maximum rate for 6 pumps); 5) Drift eliminators are inspected on an amuial basis. 3) limit the Total Dissolved Solids (TDS) content for the cooling tower recirculating ,vater system to 3500 ppmw, based on a monthly roning 12-month annual average; 4} ensure that the drift eliminator are rated by the manufacturer at OJ)Ol % or 0,003 drift or less as shown in Table 104,.A; and 5) ensure that the drift eHminator is 1 present and in good working order, The permittee shall measure the Total Dissolved Solids (TDS) content of the recirculating water through direct laboratory analysis, or may use a conductivity meter on the recirculating water system for the cooling toweL The correlation between conductivity of the water and the TDS content shall be taken as f>-9 * conductivity frunhos/cm) = TDS (pprnw) unless a new correlation is deterrnined through laboratory analysis I and submitted to the Pennit Program "Tl z , Manager for approvaL :r- 0 0 0 0 ACC Form Part 1 Penn.it # P05 l-R2 & R2M1 0 01 Vcr4J 02/25/2015 N (!) .i:,,. C cccc cccccccccc Page 114 of 144 EPA Inspection Report - Page 834 of 1969 Version 02.25.15 lVfo.nito.riog: The permittee shaH: 1) Monitor the recirculating water TDS content hv~ direct lahorator.v analysis ofthe TDS or through use of conductivity meter values and correlated TDS on a monthly basis; and -~uu. ------- ------------~~~~~~~ D Continuous [gl Yes [gl Intermittent 0No 0Yes [gl No a. Any correlation other than the (l9 value described above shaU be deve1oped by the permittee by independent laboratory 1) The Total Dissolved Solids (TDS) is sampled by measurement of at least 10 water samples with approximately evenly the Navajo Lab and results maintained in the Vorta:lBLISS system and maintained by the Navajo Environmental Department. spaced measured TDS values that bracket the minimum and maximum 2) Drift eliminators are inspected on an annual basis. values expected. The highest laboratory TDS l sample used for the correlation shall be greater I than the max1mum 3) The Cooling Towers are monitored for VOC breakthrough via the El Paso Method described in Appendix?. aHowable TDS of 3500 ppm\V, 2) Perform an annual inspection of the drift eliminator and perform any maintenance necessary to ensure the device operates according to the manufodurer's specifications. I "Tl 3) The pcm1ittee shall monitor the z cooHng water inlet and outlet :r- 0 0 0 0 ACC Form Part l Pennit # P05 l-R2 & R2M1 0 01 Ver 4. 1 02i25/2015 N (!) 01 u -.-. ~~~~~~~~N>"~~N Page 115 of 144 EPA Inspection Report - Page 835 of 1969 Version 02,25,15 streams for hydrocarbons on an annual basis using either EPA Method 8015 \\dth a large enough samp1e to achieve accurate quantification of hydrocarbon content, EPA Method 8260, EPA .l'v1ethod 8270 or a similar method as approved by the Department prior to testing, Recordkeeping: The permittee shall maintain the foHowing records: '"-"""""'" -- D Continuous [8J Intermittent ! [Xi Yes ! D No 0Yes [8J No 1) Manufacturer's speci.fications dmmnstrating maximum capacities of the recirculating water pumps and the manufacturer's specification fbr the drift ehminator specified drift rate; 2) Monthly TDS and monthly rolEng 12~month average; 3) Ifa. conductivity meteris fosta11ed, a record of the correlation between conductiv.it"v and TDS... any laboratory analyses used to determine the correlation, am.I all related calculations; l) Records maintained by the Navajo Inspections Department 2) Records maintained by the Navajo Environmental Department 3) Records maintained by the Navajo Lab. 4) Records maintained by the Navajo Inspections Department 4) Annual drift eliminator inspection and any records of maintenance ' performed, The perrnittee sha11 rnaintafa records m I ! I "Tl accordance with Section B109. z :r- Reporting: The pennittee shall report in ~av~jo submitted MACT Subpart CC reports 0 0 ::;emrnnnually as follows: 0 0 ACC Form Part 1 Pcnnit # P05 l-R2 & R2Ml 0 01 Ver4,1 02/25/2015 N (!) 0) D Continuous I r8J Yes 0Yes Page 116 of 144 EPA Inspection Report - Page 836 of 1969 Version 0225.15 accordance with Section B 110. A213 \Vastewater Syste:rns A. NSPS Subpart QQQ, Standards of Performance for VOC Emissions from Petroleum Refiner.v Waste;vater Sv~ stems (Unit MAIN API) 2/28/2019 8/22/2019 r:8'.l Intermittent ! D No D Continuous r:8'.l Intermittent D Yes r:8'.J No r:8'.]No r:8'.J Yes 0No Requirement: Beginning December 31, Navajo continues to comply with the applicable 2003, a11 remaining and newly installed individual drain systems, oil-vniter separators, and aggregate facilities not previously specified sha11 be affocted facilities, as the term is used in the NSPS, 40 CFR Part 60, Subpart QQQ, and shall requirements ofNSPS Subparts QQQ throughout the refinery, except for deviations previously reported or identifed at the end of this report Oily ,vater sewer drain hubs are inspected at least monthly, Junction boxes, and the oil-water separator arc inspected at least semi-annually. be subject to and comply with the applicable requirements of 40 CFR Part 60, Subpart QQQ. (CD 129) The perrnittee shall comply with all app1kab1e requirements of NSPS Subpart I QQQ for the affected sources in Tables 60 69 1l03.B, C, Go ( ' 0) I Navajo continues to comply with the applicable i D Contin~~:; ----[]-~~~ ----------- r:8'.J Yes Monitoring: The pen:nHtee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart QQQ. (60.695 and 60.696) requirernents ofNSPS Subparts QQQ throughout the refmery, except for deviations previously reported or identifed at the end of this report Oily water sewer drain hubs are inspected at least monthly. Junction boxes, and the oU~water 1 i r:8'.l Intermittent r:8'.l No D No senarntor are insnected at least semi-annually. ;:::~~:--:;~--~~:~t=~::~--~~--~=~=~: I Recordl~~~pi;g;........T~~;........P.~~;~~'itt~~.......;1~~ff" ... E:vironmental comrly with th: apphcablc rccordkecpmg De artment I , D Continuous . , I ~ Yes , D Yes I , ~ ::::;! ci :::::::: ~ :: ci::, ~ comply Na:ajo submi~ NSPS Subpart QQQ reports f I I I w1t111. th. e app11 ca_ble repor.t'mg sern1annua1lv a::; foUmvs. . . "Tl z 1 req1m,reme.nts, of. 40 C,FR 60.1")o.,g r1i/r3o0n/2o0199 ............. ... r:8'.l Intenmttent D No r:8'.J No :0r- ' t,5-,~- 1- ..~....,....~--------------------------------------------------------"---- I 0 0 0 ACC Form Part l Permit # POS 1..R2 & R2M 1 Page 117 of144 0 01 Vcr4.1 02i25/2015 N (!) --.J EPA Inspection Report - Page 837 of 1969 Version 02,25J5 I A213 \Vastewater Systems ' B, ?vfACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" Requirement: The permittee shaH comply with all applicable requirements of MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" for all affected sources shown in Tables 103.B, C, Qattached. (63.49} 1\~o:nito.ring: The permittee shall comply w1th_the applicable monitoring and testing reqwrements of 40 CFR 63,.. Subpart CC. Record.keeping: Tue permittec shall comr1y with the apphcab]e recordkeeping reqmrements of 40 CFR 63 .5,;-;;,:.;,; , Reporting: The pem1ittee shall comply with the applicable reportino , 0 renmremcnts of 40 CFR 63 655 "1 , - A213 Vt'astewater Systems Navajo complies with the requirements of MACT CC, except for deviations noted in semiannual reports, _ _ ~a,vaJo complies with the requirements of MACT CC Records are maintained by Navajo Environmental Department. Nav~jo submitted MACT Subpart CC reports semiannually as follows; 2/29../"0 l 9 u k 8/22/2019 C. Wastewater Treatment System (Units shown in Table 106J) D Coufomom, ~ Intermittent I D Yes I (S'.! No D ContinumIS 1~ ".71 1nternu,tt,mt O ConHnumm r:sJ lnte.rmatimt D , . IS Co:ntmuo1 fX1 lnte:nnitti~nt v::,, D Continuous ~ Intermittent M~~~~~-.-.-. rgj Yes 0No IZl Yes 0No lS] Yes 0.No ! tzl Yes I D No rgj Yes 0No 0Yes IZJ No Requirement: Compliance with the emission Emits in Tab1e 106J shall be Navajo complies with this requirement, except for deviations noted in semiannual reports. demonstrated by properly maintaining and repairing the units, and running the Wastewater Model annually to calculate ' the maximum VOC emissions generated. 1 I "Tl z :r- 0 0 0 0 ACC Fonn Part l Permit# P051-R2 & R2M1 0 01 Ver 4, 1 02125/2015 N (!) OJ uuuuuuuucc:------------------------- . : i : ~ . - n n n ~ - - - - - ' - - - - - - - ' - - - - - - - - - - ' Page 118 of 144 EPA Inspection Report - Page 838 of 1969 Vernion 02.25.J 5 ,------""~""'"~"--"""""""""-u--.-.-.-uu.-.-.- lVfonitoring: (1) Maintenance and repair shaH meet the minimum manufacturer's or -.-.-.-.-.-.-.-.-.-.-r- .-.-.-.-.-.-.--.-------------------- -----------~~~~~----"-"""""" _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _, __ __ D Continuous [8J Intermittent permittee's recommended maintenance I [sl Yes I Dtfo .............,........ ~-D Yes rgJ .No schedule. Activities that involve maintenance, adjustment, replacement, or repair of functional components with the potential to affect the operation of an emission unit shall. be documented as they occur for the following events: I 1) Navajo complies with this requirement, except (a) Routine maintenance that takes a ' for deviations noted in semiannual reports. unit out of service for more than two hours during any twenty-four hour 2) Navajo uses EPA's '>ilatcr 9 waste-water model, period, (b) Unscheduled repairs that require a unit to be taken out of service for more than two hours in any twenty- four hour period. (2) The permittee shall annually nm the Wastc~Watcr Model to determine the hour1y and annual emission rates, based on Toxchem V4 Input Parameters, I Recordkeeping: (1) The pennittee shall maintain records -------------- ...... -----+-- D Continuous rxl Intermittent ~.fv'!"'"'es 0No - , 0Yes [Xl No in accordance with Section Bl09, including records of maintenance and repairs activities and a copy of the manufacturer's or pennittee's 1) Navajo complies with this requirement, except for deviations noted in semiannual reports, recommended maintenance schedule. 2) Navajo uses EPA's Water 9 waste-water modeL (2) The pennittee shall maintain records of the Toxchem V4 Input Parameters and . the emission calculation results compared :1=~~~~~ ~ I I "Tl I permlttee ,ilicll,;;p~~complies with the cequirelllent of section D Continuous-: e~ - I D Yes z :r- i accordance ,...... ..,, with Section B 110, I B 110. - -----------! ------'-------.---'------,,..,_ 0 0 0 0 ACC Form Part 1 Fennit # P051-R2 & R2M1 Page 119 of 144 0 01 Ver 4.1 02/25/2015 N (!) (!) EPA Inspection Report - Page 839 of 1969 Version 02.LU5 ~-~...-~...-................................................................ ~ 1:8'.1 Intermittent 0No i:8'.INo I "Tl z :r- 0 0 0 0 ACC Form Part 1 Pennit # P051-R2 & R2Ml 0 01 Ver4.1 02/25/2015 (,) 0 0 Page 120 of 144 EPA Inspection Report - Page 840 of 1969 PART l B General Conditions i 1. Have these General Conditions been met during this reporting period? I I! Check milr one box per subiect heading. I{the section Heading is marked as NIA ,w remarks are required. II Explain answers in remarks row under subject heading,......... ---,_,,,,,,,......____ ---------- I B100 Introduction II RAE~iARNK/SA: ................................................... ,,,,...................................._____ --------------------------- -------- ---------! 2. Was this facility j in.compl~ance with .. this_reqmrement. l:1Does I not 1 apply I d~ng the reporting ,,,,,,,,,,.,,.1,,.:~y~~~ , ~ es I Explain I Below ro-----N f.,,,,,,;-...:..:....-~; , o I Explain ! Below NIA Explain Below B101 Legal A Permit Terms and Conditions (20.2.70 sections 7, 201.B, 300, 301.B, 302,405 NMAC) r8J Yes Explain Below 0No Explain Below ON/A Explain Below (1) The permittee shall abide by all terms and conditions of this permit, except as allowed under Section 502(b)(l0) of the Federal Act, and 20.2.70.302.H.l NMAC. Any permit noncompliance is grounds for enforcement action, and significant or repetitious noncompliance may result in termination of this permit. Additionally, noncompliance with federally enforceable conditions of this pennit constitutes a violation of the Federal Act (20.2.70.302.A.2.a NMAC) (2) Emissions trading within a facility (20.2.70.302.H.2 NMAC) (a) The Department shall, if an applicant requests it, issue pennits that contain tem1s and conditions allowing for the trading of emissions increases and decreases in the permitted facility solely for the purpose of complying with a federally enforceable emissions cap that is established in the permit in addition to any applicable requirements. Such terms and conditions shalt include all tenns and conditions required under 20.2.70.302 NMAC to determine compliance. If applicable requirements apply to the requested emissions trading, permit conditions shall be issued only to the extent that the applicable requirements provide for trading such increases and decreases without a case-by-case approval. (b) The applicant shall include in the application proposed replicable procedures and permit terms that ensure the emissions trades are quantifiable and enforceable. The Department shall not include in the emissions trading provisions any emissions units for which emissions are not quantifiable or for which there a:re no replicable procedures to enforce the emissions trades. The permit shall require compliance with all applicable requirements. (3) It shall not be a defense for the permittee in an enforcement action to claim that it would have been necessary I to halt or reduce the permitted activity in order to maintain compliance with the conditions of this permit. "Tl z ----------------- (20.2.70.302.A.2.b NMAC) -----------=----.. :r- 0 0 0 0 ACC Form Part 1 B, Deviation Summary permit# P051-R2 Page 121 of 144 0 01 Ver 4.0 01/22/2015 (,) .0.... EPA Inspection Report - Page 841 of 1969 PART 1 B General Conditions {4) If the Department determines that cause exists to modify, reopen and revise, revoke and reissue, or terminate this permit, this shall be done in accordance with 20.2.70.405 NMAC. (20.2.70.302.A.2.c NMAC) (5) The permittee shall furnish any information the Department requests in writi11g to determine if cause exists for reopening and revising, revoking and reissuing, or terminating the permit, or to detennine compliance with the permit. This information shall be furnished within the time period specified by the Department. Additionally, the permittee shall furnish, upon request by the Department, copies of records required by the permit to be maintained by the permittee. (20.2.70.302.A.2.fNMAC) (6) A request by the permittee that this permit be modified, revoked and reissued, or terminated, or a notification by the permittee of planned changes or anticipated noncompliance, shall not stay any conditions of this pennit. (20.2.70.302.A.2.d NMAC) (7) This permit does not convey property rights of any sort, or any exclusive privilege. (20.2.70.302.A.2.e NMAC) (8) In the case where an applicant or permittee has submitted information to the Department under a claim of confidentiality, the Department may also require the applicant or pennittee to submit a copy of such information directly to the Administrator of the EPA (20.2.70.301.B NMAC) (9) The issuance ofthis permit, or the filing or approval of a compliance plan, does not relieve the permittee from civil or criminal liability for failure to comply with the state or Federal Acts, or any applicable state or federal regulation or law. (20.2.70.302.A.6 NMAC and the New Mexico Air Quality Control Act NMSA 1978, Chapter 74, Article 2) (10) If any part ofthis pennit is challenged or held invalid, the remainder of the permit terms and conditions are not affected and the permittee shall continue to abide by them. (20.2.70.302.A.1.d NMAC) (11) A responsible official (as defined in20.2.70.7.AE NMAC) shall certify the accuracy, truth and completeness of every report and compliance certification submitted to the Department as required by this permit. These certifications shall be part of each document. (20.2.70.300.E NMAC) (12) Revocation or tennination of this permit by the Department terminates the pennittee's right to operate this facility. (20.2.70.201.B NMAC) (13) The pennittee shall continue to comply with all applicable requirements. For applicable requirements that will become effective during the term of the permit, the pennittee shall meet such requirements on a timely basis. (Sections 300.D.10.c and 302.G.3 of 20.2.70 NMAC) B. Pennit Shield (20.2.70.302.J NMAC) I "Tl z :r- 0 0 0 0 ACC Form Part 1 B Permit# P051-R2 & R2Ml 0 01 Ver4.1 5/6/2015 (,) 0 N Page 122 of 144 EPA Inspection Report - Page 842 of 1969 PART 1 B General Conditions (1) Compliance with the conditions of this permit shall be deemed to be compliance with any applicable requirements existing as of the date of permit issuance and identified in Table 103,A, The requirements in Table 103,A are applicable to this facility with sped fie requirements :identified for individual emission units_ (2) The Department has detennined that the requirements in Table 103,B as identified in the permit application are not applicable to this source, or they do not impose any conditions in this pennit (3) This pennit shield does not extend to administrative amendments (Subsection A of 20-2,70.404 NMAC), to minor permit modifications (Subscctkm B of 20,2,70.404 N1v1AC), to changes made under Section 502(b)(10), changes under Paragraph 1 of subsection H of20.L70.302 of the Federal Act, or to permit terms for which notice has been given to reopen or revoke all or part under 202,70.405 and 202,7(U02J(6). (4) This pernrit shall, for purposes of the permit shield, identify any requirement specifically identified in the permit application or significant pennit modification that the department has determined is not applicable to the source, and state the basis for any such determination, (20.2.70302,AJSNiviAC) C. The owner or operator of a source having an excess emission shall, to the extent practicable, operate the source, including associated air pollution control equipment, in a manner consistent with good air pollutant control practices for minimizing emissions. (202.7. 109 N1v1AC). The establishment ofallowable malfunction emission limits does not supersede this requirement. i REMARKS: Except for deviations reported on the semi-annual reports and/or referenced in this report I B102 Authoritv A. This permit is issued pursuant to the federal Clean Air Act ("Federal Act''), the New }Aexico Air Quality Control Act ("State Act") and regulations adopted pursuant to the State and Federal Acts, including Title 20, New Mexico Administrative Code, Chap. ter 2, Part 70 (202.70 Nf,,,L\C)~ - Operating. Permits. IZ! Yes Explain Below I ! i . fl This permit authorizes the operation of this facility. This pennit is valid only for the named pem1ittee, owner, i and operator, A permit modification is required to change any of those entities. i i D No i Explain I Below i 1 ! ON/A Explain Below I C, The Department sped.fies \vith this permit, terms and conditions upon the operation of this facility to assure 1 !.. I compliance with all applicable requirements, as defined in 202,70 NlVIAC at the time this pennit is issued. I "Tl z ..__________{.:Z.0.:.?..:.7.9.:?.9?.:f\-1 NMAC) "" ------ ........................... :0r- 0 0 0 ACC Fonn Part 1 B Penn.it# P051-R2 & R2Ml 0 01 Ver 4.1 5!6i2015 (,) 0 (,) i I ff~. -uuu.----------- : Page 123 of l44 EPA Inspection Report - Page 843 of 1969 PART l B General Conditions D, Pursuant to the New Mexico /Jr Quality ControL Act NMSA 1978, Chapter 74, Article 2, all tenns and conditions in this permit, including any provisions designed to limit this facilitis potential to emit, are enforceable by the Department AU terms and conditions arc enforceable by the Administrator of the United States Environmental Protection Agency ("EPA") and citizens under the Federal Act unless the tenn or condition is specifically desissnatcd in this permit as not being enforceable under the Federal Act (20.2-70302-AS NlvfAC) E The Department is foe .Adminisfrator for 40 CFR Parts 60, 61, and 63 pursuant to the Modification and Exceptions of Section 10 of202.77 NMAC (NSPS), 20.2.78 NivIAC (NESRA.:P), and 202,82 NMAC (MACT), REMARKS: R103 Annual Fee The permittee shall pay Title V fees to the Department consistent with the fee schedule in 20.2-71 J\1vIAC - Operadng Permit Emission fees. The foes wiU be assessed and invoiced st1;arately from this permit (202.70.302.ALe N1V[AC) REMARKS: ~Yes Explain Below D Explain Below D N/A Explain Below BHM Appeal Procedures (202,70-403.A NTVIAC) A, Any person who participated in a permitting action before the Department and who is adversely affected by such pcn:nitting action, may file a petition for a hearing before the Environmental Improvement Board ("board'} The petition shall be made in writing to the board within thirty (30) days from the date notice is given ofthe Department's action and shall specify the portions of the permitting action to which the petitioner oL'.iects, certify that a copy of the petition has been mailed or hand-delivered, and attach a copy ofthe pennitting action for which review is sought Unless a timely request for a hearing is made, the decision of the Department shaU be finaL The petition shall be copied simultaneously to the Department upon receipt of the appeal notice. If the petitioner is not the applicant or permittee, the petitioner shall maU or hand-deliver a copy of the petition to the appli.cant or pennittee. The Department shaH certify the administrative record to the board. Petitions for a hearing shall be sent to: Q:::J Yes Explain Below 0No Explain Belmv DN/A Explain Below I "Tl z Secretary, New Mexico Environmental Improvement Board :0r- 1190 St Francis Drive, Runnels Bldg. Rm N2153 0 0 0 ACC Form Part 1 B Pennit # P05 l-R2 & R2Ml 0 01 Ver 4. 1 5/6/2015 (,) 0 ,i:,,. Page 124 of 144 EPA Inspection Report - Page 844 of 1969 Santa Fe, New Mexico 87502 REMARKS: PART 1 B General Conditions ---------------------------cccccccccc--- 1 B105 Submittal of Reports and Certifications A. Stack Test Protocols and Stack Test Reports shall be submitted electronically to as directed by the Department. -~ssssss-~~-----~,. [8l Yes D No Explain Explain Below Below or D NIA Explain Below B. Excess Emission Reports shall be submitted as directed by the Department. (20.2.7.110 NMAC) C. Compliance Certification Reports, Semi-Ammal monitoring reports, compliance schedule progress reports, and any other compliance status infonnation required by this permit shall be certified by the responsible official and submitted to the mailing address below, or as directed by the Department: Manager, Compliance and Enforcement Section New Mexico Enviromnent Department Air Quality Bureau 525 Camino de los Marquez, Suite 1 Santa Fe, NM 87505-1816 D. Compliance Certification Reports shall also be submitted to the Administrator at the address below (20.2.70.302.E.3 NMAC): Chief, Air Enforcement Section US EPARegion-6, 6EN-AA 1445 Ross Avenue, Suite 1200 Dallas, TX 75202-2733 I REMARKS: "Tl Except for deviations reported on the semi-annual reports and/or referenced in this report. z :r- 0 0 0 0 ACC Fonn Part 1 B Permit# P05 l-R2 & R2Ml 0 01 Ver 4.1 5/6/2015 (,) 0 01 Page 125 of 144 EPA Inspection Report - Page 845 of 1969 PART 1 B General Conditions I "Tl z :r- 0 0 0 0 ACC Fonn Part !. B Pennit # I'051-R2 & R2Ml 0 01 Ver4.15/6/2015 (,) 0 0) Page 126 of 144 EPA Inspection Report - Page 846 of 1969 PART 1 B General Conditions B106 NSPS and/or MAC'f Startup, Shutdown. and Ma]ft:rnction Operations A If a facility is subject to a NSPS standard in 40 CFR 60, each owner or operator that instaUs and operates a continuous monitoring device required by a NSPS regulation shall comply with the excess emissions reporting requirements in accordance with 40 CFR 60.7(c} ~Yes Explain Below No Explain Below NIA Explain Below B, If a facility is subject to a NSPS standard in 40 CFR 60, then in accordance with 40 CFR 60.8(c), operations during periods of startup, shutdown, and malfunction shall not constitute representative conditions for the purpose of a performance test nor shall emissions in excess of the level of the applicable emission limit during periods of startup, shutdown, and matfunction be considered a violation of the applicable emission limit unless othenvise specified in the applicable standard" C. 1f a facility is subject to a MACT standard in 40 CFR 63, then the facflity is subject to the requirement for a Startup, Shutdmvn and Malfonction Plan (SSM) under 40 CFR 63Ji(e)(3), unless specifically exempted in the applicable subpart (20,2070.302.A.1 and AA NMAC) REMARKS: Except for deviations reported on the semi-annual reports and/or referenced in this report :8107 Startup, Shutdown, and Maintenance Ope.rations A, The establishment of pem1itted startup, shutdown, and maintenance (SSM) emission limits does not supersede the requirements of 20.2,7J4,A NrvIAC Except :fiJr operations or equipment subject to Condition 8106, the permittee shall establish and implement a plan to minimize emissions during routine or predictable start up, shut down, and scheduled maintenance (SSM work practice plan) and shall operate in accordance with the procedmes set forth in the plan. (202.7.14.A NMAC) . . . . . ., w n . RElU.ARKS: ............................................--............. Except for deviations reported on the semi-annual reports and/or reforenced in this report .. ..................... . Explain Below D No Explain Below ON/A Explain Below I "Tl z :r- 0 0 0 0 ACC Form Part l B Permit# P05 l-R2 & R2Ml 0 01 Ver4.1 5/6/2015 (,) 0 --.J - - - - - - -...., ......................... Page 127 of 144 EPA Inspection Report - Page 847 of 1969 B108 General Monitoring Requirements (20.2.70. 302.A and C NMAC) PART 1 B General Conditions D ----,---------------------------- ------------------------------------ [:8] Yes No I Explain Explain I Below Below ON/Ai Explain Below A These requirements do not supersede or relax requirements of federal regulations. B. The following monitoring and/or testing requirements shall be used to determine compliance with applicable requirements and emission limits. Any sampling, whether by portable analyzer or EPA reference method, that measures an emission rate over the applicable averaging period greater than an emission limit i.i1 this permit constitutes noncompliance with this pennit. The Department may require, at its discretion, additional tests pursuant to EPA Reference Methods at any time, including when sampling by portable analyzer measures ru:1 emission rate greater than an emission limit in this permit; but such requirement shall not be constmed as a determination that the sampling by portable analyzer does not establish noncompliance with this permit and shall not stay enforcement of such noncompliance based on the sampling by pmtable analyzer. C. If the emission unit is shutdown at the time when periodic monitoring is due to be accomplished, the pennittee is not required to restart the unit for the sole purpose of perfonning the monitoring. Using electronic or written mail, the pennittee shall notify the Department's Enforcement Section of a delay in emission tests prior to the deadline for accomplishing the tests. Upon recommencing operation, the permittee shall submit any pertinent pre-test notification requirements set forth in the current version of the Department's Standard Operating Procedures For Use OfPortable Analyzers in Performance Test, and shall accomplish the monitoring. D. The requirement for monitoring during any monitoring period is based on the percentage of time that the unit has operated. However, to invoke monitoring period exemptions at Bl08.D(2), hours of operation shall be monitored and recorded. (1) If the emission unit has operated for more than 25% of a monitoring period, then the permittee shall conduct monitoring during that period. (2) If the emission unit has operated for 25% or less of a monitoring period then the monitoring is not required. After two successive periods without monitoring, the permittee shall conduct monitoring during the next period regardless of the time operated during that period, except that for ru:1y monitoring period in which a unit has operated for less than 10% of the monitoring period, the period will not be considered as one of the I two successive periods. ! (3) If invoking the monitoring period exemption in Bl 08 .D(2), the actual operating time ofa unit shall not exceed I I "Tl z -~~;__;~::i::_::::::~;~::~~~;~h~t~:~r::\~~;~;;i:~::~~;~r:~~~~~~;:J;r:~~~::r:db~.:.;~~.:;;ir.~;;.~~--l--.. :r- 0 0 0 0 ACC Form Part 1 B Permit# P051-R.2 & R.2Ml 0 01 Ver 4J 5/6/2015 (,) 0 OJ -' Page 128 of144 EPA Inspection Report - Page 848 of 1969 PART 1 B General Conditions is conducted. Regardless of the time that a unit actually operates, a minimum of one of each type of monitoring activity shall be conducted during the five year term of this pennit. E. The permittee is not required to report a deviation for any monitoring or testing in a Specific Condition if the deviation was authorized in this General Condition B1 F. For all periodic monitoring events, except when a federal or state regulation is more stringent, three test runs shaH be conducted at 90% or greater of the unit's capacity as stated in this permit, or in the permit application if not in the pennit, and at additional loads when requested by the Department. If the 90% capacity cannot be achieved, the monitoring wiU be conducted at the maximum achievable load under prevailing operating conditions except when a federal or state regulation requires more restrictive test conditions. The load and the parameters used to calculate it shall be recorded to document operating conditions and shall be included with the monitoring report. G. When requested by the Department, the pem1ittee shall provide schedules of testing and monitoring activities. Compliance tests from previous NSR and Title V permits may be re-imposed if it is deemed necessary by the Department to determine whether the source is in compliance with applicable regulations or pem1it conditions. H. If monitoring is new or is in addition to monitoring imposed by an existing applicable requirement, it shall become effective 120 days after the date of permit issuance. For emission units that have not commenced operation, the associated new or additional monitoring shall not apply until 120 days after the units commence operation. All pre-existing monitoring requirements incorporated in this pem1it shall continue to apply from the date of permit issuance. All monitoring periods, unless stated otherwise in the specific pennit condition or federal requirement, shall commence at the beginning of the 12 month reporting period as defined at condition A109.B. REMARKS: Except for deviations reported on the semi-annual reports and/or referenced in this report. nu~ :"""'' ----- < I "Tl z :r- 0 0 0 0 ACC Form Part l B Permit# P05 l-R2 & R2Ml 0 01 Ver 4.1 5/6/2015 (,) 0 (!) Page 129 of 144 EPA Inspection Report - Page 849 of 1969 :8109 General Recordkeeging Requirements (20.2.70.302.D.1 NMAC) PART 1 B General Conditions ['8JYes 0No Explain Explain Below Below A. The permittee shall maintain records to assure and verify compliance with the terms and conditions ofthis permit and any applicable requirements that become effective during the term ofthis permit. The minimum information to be included in these records is (20.2.70.302.D. l NMAC): D I NIA Explain Below (1) Records required for testing and sampling: (a) equipment identification (include make, model and serial number for all tested equipment and , emission controls); (b) date(s) and time(s) of sampling or measurements; (c) date(s) analyses were performed; (d) the company or entity that performed the analyses; (e) analytical or test methods used; (f) results of analyses or tests; and (g) operating conditions existing at the time of sampling or measurement. (2) Records required for equipment inspections and/or maintenance required by this permit: (a) equipment identification number (including make, model and serial number) (b) date(s) and time(s) of inspection, maintenance, and/or repair (c) date(s) any subsequent analyses were performed (if applicable) (d) name of the person or qualified entity conducting the inspection, maintenance, and/or repair (e) copy of the equipment manufacturer's or the owner or operator's maintenance or repair recommendations (if required to demonstrate compliance with a permit condition) (f) description of:maintenance or repair activities conducted i (g) all results of any required parameter readings i (h) a description of the physical condition of the equipment as found during any required inspection \ I "Tl (i) results of required equipment inspections including a description of any condition which required I z ::i4j~1~!~~!1!_ ~'?,J?~iP:8_!1,:l~-~9,,u,!!!1:~nt back into compliance and a description ~I!h~E~I1:1iE~4 ::iqj~1~~~~~~!~J :r- 0 0 0 0 ACC Form Part 1 B Permit# P05 l-R2 & R2Ml 0 01 Ver4.l 5/6/2015 (,) ..... 0 i i ! i I I I L ~ _____- __L____ Page 130 of 144 EPA Inspection Report - Page 850 of 1969 PART 1 B General Conditions B. The permittee shall keep records of aH monitoring data, equipment calibration, maintenance, and inspections, Data Acquisition and Handling System (DAHS) if used, reports, and other supporting information required by this permit for at least five (5) years from the time the data was gathered or the reports written. Each record shall clearly identify the emissions unit and/or monitoring equipment, and the date the data was gathered. (20.2.70.302.D.2 NMAC) C. If the pem1ittee has applied and received approval for an alternative operating scenario, then the pennittee shall maintain a log at the facility, which documents, contemporaneously with any change from one operating scenario to another, the scenario under which the facility is operating. (20.2.70.302.A.3 NMAC) D. The pennittee shall keep a record describing off pennit changes made at this source that result in emissions of a regulated air pollutant subject to an applicable requirement, but not otherwise regulated under this permit, and the emissions resulting from those changes. (20.2.70.302.I.2 NMAC) E. Unless othenvise indicated by Specific Conditions, the pe1mittee shall keep the following records for malfunction emissions and routine and predictable emissions during startup, shutdown, and scheduled maintenance (SSM): (]) The owner or operator of a source subject to a permit, shall establish and implement a plan to minimize emissions during routine or predictable startup, shutdown, and scheduled maintenance through work practice standards and good air pollution control practices. This requirement shaU not apply to any affected facility defined in and subject to an emissions standard and an equivalent plan under 40 CFR Part 60 (NSPS), 40 CFR Part 63 (MACT), or an equivalent plan under 20.2.72 NMAC - Construction Permits, 20.2.70 NMAC Operating Permits, 20.2.74 NMAC - Pennits - Prevention of Significant Deterioration (PSD), or 20.2.79 NMAC - Permits - Nonattainment Areas. (20.2.7.14.A NMAC) The pem1ittee shall keep records ofall sources subject to the plan to minimize emissions during routine or predictable SSM and shall record if the source is subject to an alternative plan and therefore, not subject to the plan requirements under 20.2.7.14.A NMAC. (2) If the facility has allowable SSM emission limits in this permit, the pennittee shall record all SSM events, including the date, the start time, the end time, a description of the event, and a description of the cause of the event. This record also shall include a copy ofthe manufacturer's, or equivalent, documentation showing that any maintenance qualified as scheduled. Scheduled maintenance is an activity that occurs at an established frequency pursuant to a written protocol published by the manufacturer or other reliable source. The I "Tl authorization of allowable SSM emissions does not supersede any applicable federal or state standard. The z most stringent requirement annli"'" :r- 0 0 0 0 ACC Form Part 1 B Permit# P05 l-R2 & R2Ml 0 01 Ver4.1 5/6/2015 (,) ...... ...... Page 131 of 144 EPA Inspection Report - Page 851 of 1969 PART 1 B General Conditions (3) If the facility has allowable malfunction emission limits in this permit, the pennittee shall record all malfunction events to be applied against these limits. The pennittee shall also include the date, the start time, the end time, and a description of the event. Malfunction means any sudden and unavoidable failure of air pollution control equipment or process equipment beyond the control of the owner or operator, including malfunction during startup or shutdown. A failure that is caused entirely or in part by poor maintenance, careless operation, or any other preventable equipment breakdown shall not be considered a malfunction. (20.2.7.7.E NMAC) The authorization of allowable malfunction emissions does not supersede any applicable federal or state standard. The most stringent requirement applies. This authorization only allows the pennittee to avoid submitting reports under 20.2.7 NMAC for total annual emissions that are below the authorized malfunction emission limit. (4) The owner or operator of a source shall meet the operational plan defining the measures to be taken to mitigate source emissions during malfunction, startup or shutdown. (20.2.72.203.A(S) NMAC) REMARKS: Except for deviations reported on the semi-annual reports and/or referenced in this report 8110 General Reporting Requirements (20.2.70.302.E NNIAC) 0Yes i 0No !"ON/A Explain i Explain ! Explain Below ! Below Below A Reports of required monitoring activities for this facility shall be submitted to the Department 011 the schedule in section A] 09. Monitoring and recordkeeping requirements that are not required by a NSPS or MACT shall be maintained on-site or (for umnanned sites) at the nearest company office, and summarized in the semi-an:nual reports, unless alternative reporting requirements are specified in the equipment specific requirements section of this permit. B. Reports shall clearly identify the subject equipment showing the emission unit ID number according to this operating pennit. In addition, all instances of deviations from pem1it requirements, including those that occur during emergencies, shall be clearly identified in the reports required by section Al 09. (20.2.70.302.E.1 NMAC) C. The permittee shall submit reports of all deviations from permit requirements, including those attributable to upset conditions as defined in the permit, the probable cause of such deviations, and any corrective actions or preventive measures taken. These reports shall be submitted as follows: I (1) Deviations resulting in excess em1ss10ns as defined in 20.2.7.7 NMAC (including those classified as "Tl z emergencies as defined in section Bl 14.A) shall be reported in accordance with the timelines specified by :0r- 20.2.7.110 NMAC ai;id_i~Jh~~~:ip.i-ammal reports required in~~g!;2n A109.J20.2.70.302.R?;NM_A_C~,)--~-~ 0 0 0 ACC Form Part l B Permit# P05 i-R2 & R2M1 Page 132 of 144 0 01 Ver4.l 5/6/2015 (,) ...... N EPA Inspection Report - Page 852 of 1969 PART 1 B General Conditions (2) All other deviations shall be reported in the semi-annual reports required in section A109. (20.2.70.302.E.2 NMAC). D. The permittee shaH submit reports of excess emissions in accordance with 20.2.7.110.A NMAC. E. Results ofemission tests and monitoring for each pollutant (except opacity) shall be reported in pounds per hour (unless otherwise specified) and tons per year. Opacity shaH be reported in percent. The number of significant figures corresponding to the full accuracy inherent in the testing instnunent or Method test used to obtain the data shall be used to calculate and report test results in accordance with 20.2.1.116.B and C NMAC. Upon request by the Department, CEMS and other tabular data shall be submitted in editable, MS Excel format F. At such time as new units are installed as authorized by the applicable NSR Permit, the pem1ittee shall fulfill the notification requirements in the NSR permit. G. Periodic Emissions Test Reporting: The pennittee shall report semi-annually a summary of the test results. H. The pennittee shall submit an emissions inventory for this facility annually. The emissions inventory shall be submitted by the later of April l or within 90 days after the Department makes such request. (20.2.73 NMAC and 20.2.70.302.A.1 NMAC) (1) The facility emits, or has the potential to emit, 5 tons per year or more of lead or lead compounds, or 100 tons per year or more of PMlO, PM2.5, sulfur oxides, nitrogen oxides, carbon monoxide, or volatile organic compounds. (2) The facility is defined as a major source of hazardous air pollutants under 20.2.70 NMAC (Operating Permits). (3) The facility is located in an ozone nonattaimnent area and which emits, or has the potential to emit, 25 tons per year or more ofnitrogen oxides or volatile organic compounds. (4) Upon request by the department. (5) The pennittee shall submit the emissions inventory report by April 1 of each year, unless a different deadline is specified by the current operating pem1it. I. Emissions trading within a facility (20.2.70.302.H.2 NMAC) (l) For each such change, the permittee shall provide written notification to the department and the administrator at I "Tl least seven (7) days in advance of the proposed changes. Such notification shall state when the change will occur z and shall describe the changes in emissions that will result and how these increases and decreases in emissions :0r- conditions ofthe 0 0 0 ACC .Form Part l B Perntit #P051-R2 & R2Ml 0 01 Ver4.l 5/6/2015 (,) ..... (,) Page 133 of 144 EPA Inspection Report - Page 853 of 1969 PART 1 B General Conditions (2) The per:mittee and department shall attach each such notice to their copy of the relevant I "Tl z :r- 0 0 0 0 ACC Fonn Part 1 B Pennit # P051-R.2 & R.2Ml 0 01 Ver 4.1 5/6/20] 5 (,) ...... .i:,,. Page 134 of 144 EPA Inspection Report - Page 854 of 1969 PART 1 B General Conditions ..................... REMARKS: Except for deviations reported on the semi-annual reports and/or referenced in this report. B111 GeneralTesting Reg11irements A. Compliance Tests t:?sl Yes Explain Below (1) Compliance test requirements from previous permits (if any) are still in effect, unless the tests have been satisfactorily completed. Compliance tests may be re-imposed if it is deemed necessary by the Department to determine whether the source is in compliance with applicable regulations or permit conditions. (20.2.72 NMAC Sections 210.C and 213) (2) Compliance tests shall be conducted within sixty (60) days after the unit(s) achieve the ma:x.imum nom1al production rate. If the maximum normal production rate does not occur within one hundred twenty (120) days of source startup, then the tests must be conducted no later than one hundred eighty (180) days after initial startup of the source. (3) Unless otherwise indicated by Specific Conditions or regulatory requirements, the default time period for each test run shall be at least 60 minutes and each performance test shall consist of three separate runs using the applicable test method. For the purpose of determining compliance with an applicable emission limit, the arithmetic mean of results of the three runs shall apply. In the event that a sample is accidentally lost or conditions occur in which one of the three runs must be discontinued because of forced shutdown, failure of an irreplaceable portion of the sample train, extreme meteorological conditions, or other circumstances, beyond the owner or operator's control, compliance may, upon the Department approval, be determined using the arithmetic mean of the results of the two other runs. (4) Testing of emissions shall be conducted with the emissions unit operating at 90 to 100 percent of the maximum operating rate allowed by the permit. If it is not possible to test at that rate, the source may test at a lower operating rate, subject to the approval ofthe Department. (5) Testing performed at less than 90 percent of permitted capacity will limit emission unit operation to 110 percent of the tested capacity until a new test is conducted. (6) If conditions change such that unit operation above 110 percent of tested capacity is possible, the source must submit a protocol to the Department within 30 days of such change to conduct a new emissions test. I D No roN1A Explain i Explain Below Below I "Tl z :r- B. EPA Reference Method Tests 0 0 0 0 ACC Form Part 1 B Permit # P05 l -R2 & R2M l 0 01 Ver4.l 5/6/2015 (,) ...... 01 Page 135 ofl44 EPA Inspection Report - Page 855 of 1969 PART 1 B General Conditions (1) All compliance tests required by this permit, unless otherwise specified by Specific Conditions ofthis permit, shall be conducted in accordance with the requirements of 40 CFR 60, Subpart A, General Provisions, and the following EPA Reference Methods as specified by 40 CFR 60, Appendix A: (a) Methods 1 through 4 for stack gas flowrate (b) Method 5 for TSP (c) Method 6C and 19 for S02 (d) Method 7E for NOx (test results shall be expressed as nitrogen dioxide (N02) using a molecular weight of 46 lb/lb-mo1 in all calculations (each ppm of NO/N02 is equivalent to 1.194 x 10-7 lb/SCF) (e) Method 9 for opacity (t) Method 10 for CO (g) Method 19 may be used in lieu of Methods 1-4 for stack gas flowrate upon approval of the Department. A justification for this proposal must be provided along with a contemporaneous fuel gas analysis (preferably on the day of the test) and a recent fuel flow meter calibration certificate (within the most recent quarter). (h) Method 7E or 20 for Turbines per 60.335 or 60.4400 (i) Method 29 for Metals (j) Method 201A for filterable PM10 and PM2.s (k) Method 202 for condensable PM (l) Method 320 for organic Hazardous Air Pollutants (HAPs) (m) Method 25A for VOC reduction efficiency (11) Method 30B for Mercury (2) Alternative test method(s) may be used if the Department approves the change. C. Peliodic Monitming and Portable Analyzer Requirements (1) Periodic emissions tests (periodic monitoring) may be conducted in accordance with EPA Reference Methods or by utilizing a portable analyzer. Peliodic monitoling utilizing a portable analyzer shall be conducted in I "Tl accordance with the requirements of ASTM D 6522-00. However, if a facility has met a previously approved z Department criterion for portable analyzers, the analyzer may be operated in accordance with that criterion :0r- until it is repb~""c1 0 0 0 ACC Fonn Prut 1 B Permit# P051-R2 & R2Ml 0 01 Ver4.l 5/6/2015 (,) ...... 0) Page 136 of 144 EPA Inspection Report - Page 856 of 1969 PART 1 B General Conditions -------------------~-------------------""""""""""""""""""" (2) Unless otherwise indicated by Specific Conditions or regulatory requirements, the default time period for each test run shall be at least 20 minutes. Each performance test shaH consist of three separate nms. The arithmetic mean of results of the three runs shall be used to detennine compliance with the applicable emission limit. (3) Testing of emissions shall be conducted in accordance with the requirements at Section B108.F. (4) During emissions tests, pollutant and diluent concentration shall be monitored and recorded. Fuel flow rate shall be monitored and recorded if stack gas flow rate is determined utilizing Method 19. This information shall be included with the test report furnished to the Department. (5) Stack gas flow rate shall be calculated in accordance with 40 CFR 60, Appendix A, Method 19 utilizing fuel flow rate (sd) determined by a dedicated fuel flow meter and fuel heating value (Btu/scf) detem1ined from a fuel sample obtained preferably during the day of the test, but no earlier than three months p1ior to the test date. Alternatively, stack gas flow rate may be determined by using EPA Methods 1-4. D. Test Procedures: (1) The permittee shall notify the Department's Program Manager, Compliance and Enforcement Section at least thirty (30) days before the test to afford a representative of the Department an opportunity to be present at the test. (40CFR 60.8(d)) (2) Equipment shall be tested in the "as fom1d" condition. Equipment may not be adjusted or tuned prior to any test for the purpose oflowering emissions, and then returned to previous settings or operating conditions after the test is complete. (3) Contents of test notifications, protocols and test reports shall conform to the format specified by the Department's Universal Test Notification, Protocol and Report Form and Instructions. Current forms and instructions are posted to NMED's Air Quality web site under Compliance and Enforcement Testing. (4) The pennittee shall provide (a) sampling ports adequate for the test methods applicable to the facility, (b) safe sampling platfomrn, (c) safe access to sampling platforms and (d) utilities for sampling and testing equipment. (5) The stack shall be of sufficient height and diameter and the sample ports shall be located so that a j representative test of the en1issions can be perfonned in accordance with the requirements of EPA Method l or ASTM D 6522-00 as applicable. (6) Where necessary to prevent cyclonic flow in the stack, flow straighteners shall be installed (7) Unless othenv-ise indicated by Specific Conditions or regulatory requirements, test rep011s shall be submitted L::,~:~_vi3:!~9.~_S.__ ~h~ to the Department no later than 30 days after completion ofthe test. I z"Tl ;.... cc--uu.-.-.-.-.- . . . . - . - . - . - . - . - . - . - . - . - c . s s s s s s s s s ~ - - - - ~ '- - - - - - - - - - - - - - - ' :r- 0 0 !.~P.9.1.!_t?4..<?~.. ..S.~1Pi::l:I:1!1;~a1 reports and/or referenced in t.~"!.~E2!!: ................... ___ __ ___________ ------------------------------- 0 0 ACC Form Part 1 B Pennit # P05 i-R2 & R2MI Page 137 of 144 0 01 Ver 4.1 5/6/2015 (,) ..... -..,J EPA Inspection Report - Page 857 of 1969 PART 1 B General Conditions B112 Compliance A. The Department shall be given the right to enter the facility at all reasonable times to verify the tenns and conditions of this permit Required records shall be organized by date and subject matter and shall at all times be readily available for inspection. The pem1ittee, upon verbal or written request from an authorized representative ofthe Department who appears at the facility, shall immediately produce for inspection or copying any records required to be maintained at the facility. Upon written request at other times, the permittee shall deliver to the Department paper or electronic copies of any and all required records maintained on site or at an off-site location. Requested records shall be copied and delivered at the penniltee's expense within three business days from receipt of request unless the Department aHows additional time. Required records may include records required by permit and other information necessary to demonstrate compliance with terms and conditions of this permit (NMSA 1978, Section 74-2-13) Yes Explain Below No Explain Below N/A Explain Below B. A copy of the most recent pennit(s) issued by the Department shall be kept at the permitted facility or (for unmanned sites) at the nearest company office and shall be made available to Department personnel for inspection upon request (20.2.70.302.G.3 NMAC) C. Emissions linrits associated with the energy input of a Unit, i.e. lb/MMBtu, shall apply at all times unless stated otherwise in a Specific Condition of this pennit. The averaging time for each emissions limit, including those based on energy input of a Unit (i.e. lb/MMBtu) is one (1) hour unless stated otherwise in a Specific Condition of this permit or in the applicable requirement that establishes the linrit. (20.2.70.302.A.I and G.3 NMAC) D. The permittee shall submit compliance certification reports certifying the compliance status of this facility with respect to all pennit te1ms and conditions, including applicable requirements. These repmts shall be made on the pre-populated Compliance Certification Report Form that is provided to the permittee by the Department, and shall be submitted to the Department and to EPA at least every 12 months. For the most current form, please contact the Compliance Reports Group at email:reportsgroup.aqb@state.nm.us. For additional reporting guidance see (20.2.70.302.E.3 NMAC) E. The pem1ittee shall allow representatives of the Department, upon presentation of credentials and other I "Tl documents as maybe required by law, to do the following (20.2.70.302.G.1 NMAC): z :r- 0 0 0 0 ACC Forni Part 1 B Permit# P051-R2 & R2Ml 0 01 Ver 4.1 5/6/2015 (,) ..... OJ Page 138 of I44 EPA Inspection Report - Page 858 of 1969 PART 1 B General Conditions (1) enter the permittee's premises where a source or emission unit is located, or where records that are required by this permit to be maintained are kept; (2) have access to and copy, at reasonable times, any records that are required by this permit to be maintained; (3) inspect any facilities, equipment (including monitoring and air pollution control equipment), work practices or operations regulated or required under this permit; and (4) sample or monitor any substances or parameters for the purpose of assuring compliance with this permit or applicable requirements or as otherwise authorized by the Federal Act. REMARKS: .------~----- ................... Except for deviations reported on the semi-annual reports and/or referenced in this report. ,,,,,,,,,,,....------------ ! BH3 Permit Reopening and Revocation _ _ _ _ _.................................. - - - - - - - - - - - -....-,..., A This pennit will be reopened and revised when any one of the following conditions occurs, and may be revoked and reissued when A(3) or A(4) occms. (20.2.70.405.A.1 NMAC) \ [81 Yes Explain \ Below i \ D No Explain i Below \ D N/A i Explain I Below (1) Additional applicable requirements under the Federal Act become applicable to a major source three (3) or more years before the expiration date of this permit. If the effective date of the requirement is later than the expiration date ofthis permit, then the permit is not required to be reopened unless the original permit or any ofits tenns and conditions has been extended due to the Department's failure to take timely action on a request by the permittee to renew this permit. (2) Additional requirements, including excess emissions requirements, become applicable to this somce under Title IV of the Federal Act (the acid rain program). Upon approval by the Administrator, excess emissions offset plans will be incorporated into this permit. (3) The Department or the Administrator determines that the permit contains a material mistake or that inaccurate statements were made in establishing the terms and conditions of the permit. : (4) The Department or the Administrator detennines that the permit must be revised or revoked and reissued to assure compliance with an applicable requirement. I I "Tl B. Proceedings to reopen or revoke this pe1mit shall affect only those parts of this permit for which cause to reopen z or revoke exists. Emissions units for which permit conditions have been revoked shall not be operated until new :r- 0 0 0 ------p-e1~m-i_t..::g~1!!!9.!!~.!!!Y.~Q~~~J.~.~~~.~..f<?!.JP:~~:...(?9:.?:?9.'.49?.:A}.N:MAG).... ............... ,,. .. .......... --......................L_ 0 ACC Forn1 Part l B Pennit # P051-R2 & R2M1 0 01 Ver4.1 5/6/2015 (,) ..... (!) ............ . Page 139 of ]44 EPA Inspection Report - Page 859 of 1969 PART 1 B General Conditions REMARKS: Except for deviations reported on the semi-annual reports and/or referenced. in this report uuuu.-.- B114 Emergencies (20.2.70.304 NMAC) ~Yes Explain Below 0No Explain Below A An "emergency" means any situation arising from sudden and reasonably unforeseeable events beyond the control of the per:mittee, including acts of God, which situation requires immediate corrective action to restore normal operation, and that causes the source to exceed a technology-based emission limitation under the permit due to unavoidable increases in emissions attributable to the emergency. An emergency shall not include noncompliance to the extent caused by improperly designed equipment, lack of preventive mah1tenance, or careless or improper operation. B. An emergency constitutes an affinnative defense to an action brought for noncompliance with technology-based emission limitations contained in this permit if the per.mittee has demonstrated through properly signed, contemporaneous operating logs, or other relevant evidence that NIA Explain Below (1) An emergency occurred and that the pennittee can identify the cause(s) of the emergency; (2) This facility was at the time being properly operated; (3) During the period of the emergency the pennittee took all reasonable steps to minimize levels of emissions that exceeded the emission standards or other requirements in this permit; and (4) The pem1ittee submitted notice of the emergency to the Department within 2 working days of the time when emission limitations were exceeded due to the emergency. This notice fulfills the requirement of 20.2.70.302.E.2 NMAC. This notice must contain a description of the emergency, any steps taken to mitigate emissions, and corrective actions taken. C. In any enforcement proceeding, the pennittee seeking to establish the occmTence of an emergency has the burden of proof. D. This provision is in addition to any emergency or upset provision contained in any applicable requirement. I "Tl z REMARKS: :r- 0 0 :?S9eptfor deviations reported .on.thesemi-annual_rnports and/or referenced. in this report. ------------ _ 0 0 ACC FonnPart 1 B Permit#P051-R2 & R2M1 0 01 Ver 4.1 5/6/2015 (,) N 0 -----( , ________ __ ...1 Page 140 of 144 EPA Inspection Report - Page 860 of 1969 PiART 1 B General Conditions BU 5 Stratospheric Ozone ---------------- (20.2.70.302.A.1 NMAC) ............................ . A If this facility is subject to 40 CFR 82, Subpart F, the pennittee shall comply with the following standards for recycling and emissions reductions: (1) Persons opening appliances for maintenance, service, repair, or disposal must comply with the required practices, except for motor vehicle air conditioners (MVAC) and MVAC-like appliances. (40 CFR 82.156) (2) Equipment used during the maintenance, service, repair, or disposal of appliances must comply with the standards for recycling and recovery equipment. (40 CFR 82.158) (3) Persons performing maintenance, service, repair, or disposal of appliances must be certified by an approved technician certification program. (40 CFR 82.161) j-cccccccccccccccccccccccccc _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _, REMARKS: Except for deviations reported on the semi-annual reports and/or referenced in this report. ~Yes Explain Below 0No Explain Below D NIA Explain Below B116 Acid Rain Sources (20.2.70.302.A.9 NMAC) I 0Yes j 0No I Explain IExplain I Below Below A If this facility is subject to the federal acid rain program under 40 CFR 72, this section applies. I B. Where an applicable requirement of the Federal Act is more stringent than an applicable requirement of regulations promulgated under Title IV of the Federal Act, both provisions are incorporated into this permit and are federally enforceable. ~ NIA Explain Below C. Emissions exceeding any allowances held by the pennittee tmder Title IV of the Federal Act or the regulations promulgated thereunder are prohibited. D. No modification of this permit is required for increases in emissions that are authorized by allowances acquired pursuant to the acid rain program, provided that such increases do not require a pennit modification under any I other applicable requirement. "Tl z :0r- E. The p~1~~!!_~~--~"1:Y_!1:<?.!__l:1:~-~!!9w_~!1;~S as a defense to noncompliance with any other applicable re<iuu-_~~~~!:________ ,,, ________ 0 0 0 ACC Forni Part 1 B Permit# P051-R2 & R2Ml Page 141 of 144 0 01 Ver4.l 5/6/2015 (,) .N..... EPA Inspection Report - Page 861 of 1969 PART 1 B General Conditions F. No limit is placed on the number of allowances held by the acid rain source. Any such allowance shall be accounted for according to the procedures established in regulations promulgated under Title JV of the Federal Act. G. The acid rain pennit is an enclosure of this operating permit REMARKS: B117 Risk Management Flan (202.70.302.A.1 NMAC) ~Yes Explain Below LJNo Explain Below A. If this facility is subject to the foderal risk management program under 40 CFR 68, this section applies. B. The owner or operator shall certify annually that they have developed and implemented a RL\iP and are in compliance with 40 CFR 68. C. If the owner or operator of the facility has not developed and submitted a risk management plan according to 40 CFR 68.150, the owner or operator shall provide a compliance schedule for the development and implementation of the plan. The plan shall describe, in detail, procedures for assessing the accidental release hazani, preventing accidental releases, and developing an emergency response plan to an accidental release. 'foe plan shall be submitted in a method and format to a central point as specified by EPA prior to the date specified in 40 CFR 68J50.b. REMARKS: Except for deviations reported on the semi-annual reports and/or referenced in this report LJ NIA Explain Below I "Tl z :r- 0 0 0 0 ACC Form Part l B Permit# P051-R2 & R2Ml 0 01 Ver4.1 5/6/2015 (,) N N Page 142 ofl44 EPA Inspection Report - Page 862 of 1969 Part 2 ACC Deviation Summary Report for Permit P051-R2 & R2Ml DNo DYes l&JNo i&JYes DNo I 1Deviation Summary Table for deviations not yet reported. ~o. [~~1l!~~b~u~~e6~:~~:~~t l~~~s~;~ Cause ofDeviation Al06.C, Al07.C, Al07.F !All Flares Flare monitoring implemented to meet NSPS Ja requirements Allowable SSM and Malfunction has resulted in data that has been under evaluation for Emissions potential exceedences ofpennit limits. Thus, any excess tmissions have not been reported to date. Corrective Action Taken Navajo has been working to quantify emissions from its flares, and drafl: permit applications to reflect new permit limits were ,provided to and discussed with the NMED. It is anticipated lthal a final application will be submitted by end of4th quarter !2019. Navajo will subsequently address any reporting of !excess emissions that may be necessary with the NMED. A206.B 2 !40 CFR 63.1 l(b) I !Al 06 and A107 3 FL-0400 FL-0401 FL-0404 IAll Sources Flare gas below 300 btu/scf NHV due to hydrogen venting as Increased H2 consumption and reduced H2 sent to the flare. a result of process upset and hydrogen imbalan,:e. ISeveral excess emission reports required under condition Al 06 and AI07 were not reported within the time required under 20.2.7 NMAC. Navajo currently tracks ernission ~~e~t~ on a daily basis and is in the process of installing a Data Acquisition Systern (DAS) to capture events instantaneously. A.103.A, 202.74 NMAC 4 GOHT, including FL-0404 and H-0601 The draft results of a voluntary, third-party, focused environmental compliance audit received on April 9, 2018, as updated by the auditor on May 29, 2018, indicate that PSD 1for carbon monoxide (CO) and NOx may have been triggered hn connection with the 2001 GO.HT Project if updated FLjo404 emissions data from recent monitoring under NSPS Ja rf.'fe to be applied retroactively. A draft application to revise NSR Pennit No. Ol 95-M37 to reflect increased flare emission limits has been prepared and disctJssed with the NMED, and it is anticipated that a final application will be submitted by end of 4th quarter 2019. The j' GOHT Project lmpact Analysis was submitted to NMED in Dec 2018. Based on current review, BACT for CO and NOx is ! not expected to require any reductions below current emission 'I levels or the installation of any control equipment. I "Tl ' z :r- 0 0 0 0 0 ACC Part 2, Deviation Summary Table Title-V Permit# P051-R2 & R2Ml 01 (,) N (,) I Page 142 ofl44 EPA Inspection Report - Page 863 of 1969 PART 1 B General Conditions Deviation Summa~ Table :for deviati,ons not yet reported, (cont.) '-.~~~~-~-~ ~--:.. Applicable R<::,l'.rns;;ms:,m No. (Include Rule_Citation) 40 CFR Part 60, Subpart.1-,'NN D,.,,.,.,_,.,..,...,,.,..,.,., Emission ,tJnitU)(s) FUG-09- Cause of Deviation IA recrnt third party audit ofNSPS Subparts NNN and RRR 40 CFR Part 60, Subpart RRR N.ALKY applicability to pokntial!y cov,;;red equipment and processes A!ky Flare (FL indicates that the Alky!atirm Unit De_propanizer (W-623) and 1 0403) lrmctor may be subj,;;ct to these rules, respectively. This is under review. 5 , ,,,,,,,,,,,,,,,, ____ _ : !Corrective Action Taken (;,:; -----_---------- ,,.,,.. , < , , - I Correct1ve actions are not ant1c1pateo to mdude msl,ilfation ot iadditkma1 conlrob. This is bcr'.am;e (1) W--623 is already tied into the flare system, and based on current review, should satisfy Subpart NNN control requir<.'lnents, and (2) the reactor vents to W-623 and it would not be suhject to control requirements under Subpart. RRR, p<.'r 40 CFR 60.700(c)(5). Potential n.,'Porting and monitoring corrective actions are under review, and at least NSPS repnrting will be addressed during 4th quarter 2019. I I r-- --------lto-criiii":(;)('.ij--- --- ----- .. -------------------ICEIYIS. 140 CFR 6/L 1J(h)(2); and lcounterpait NESHAP provisions l 6 i l I The results of a rccrnt voluntary third-party en-virornnenta! I Navajo suhmitled a self-disclosure to the NMED on 7fl l ;iiffi}"'l audit of the continuous emissions monitoring syst<.m prq,,'fam addressing these issues. Navajo will perform a review of the i identified potential deviations from provisions governing methodology used to determine valid CEMS data periods and ' CEMS downtime cakulation m,d related excess emissions and monitor downtime and to caku!atc and report excess en1issions monitoring system per1onmmce report,. and assess applicable protocols. The CEMS downtim,;; calculation mdhodology and ddennination of valid CEMS periods have been revised going forward. A20l 20.2. 72.200(A)(3) N?vfAC 7 !Engines Based Oll the re.wlw of a recent voluntary third-party environmental audit, the model number mid manufacture date for a small number of onsite porlahle, diesel-powered air i::ompre8sors do not match those authorized in NSR Pemiit PSD-NM~0195--MJ7. 'Navajo wiH s_:1bmit ayerrnit_ revisi2m application to update the engrne spec1hcat1m1 tor the 1dentlht'd mr compressors. I "Tl z :r- 0 0 ACC Form Part l B Permit # P051-R2 & R2M l 0 0 Ver4.l 5/6/2015 0 01 (,) N .i:,,. Page 143 of 144 EPA Inspection Report - Page 864 of 1969 TDeviation Summarv Table (cont.) ~ ................................................J1.......- .................,,,................................ 1 Deviation Started Deviation Ended No, 1 Date ~ i t I 09/01/2018 !, 2 I NIA NIA ----.- 3 ..-.-------.-.-.-.-.------------- 4 NIA Ti 00:00 NIA N/A N/A 5 09/0li2018 00:00 6 NIA NIA ~..-... ............................................-.-.-...............~ ...___________________.......... 7 09/01/2018 . -..- ...~-~..........~----~...................~, 00:00 l 08131/2019 i NIA l N/A + I N/A j 08/31/2019 I N/A I 08/31/2019 Time !Pollutant 23:59 NIA lNOx, CO, VOC, &802 NIA NIA. Various NIA 23:59 CO,NOx voe NIA NIA ---~---- ----------------- ---------~~------~~~~~~~~~~~~~~~=~~ 23:59 NIA ..............................___ -- lhfonitoring Method ....................-.-.----- CF.\t1S/Pi Data CEMS/Pi Data (Sec Note 2) Pi Data, Calculations Pi Data CEMS/Pi Data uu. ---------- ........;.;-:---w<:--~. CEMS Calculation N/A Did you attach an excess emission form? Amount of Emissions Unkrn),vn l lZJYes DNo ! r.TiA I NIA Under Review NIA T T-n~::o.,-, l i ~..._WJ.....,vV NiA. DYes ________________ _,._ DYcs l2lNo IEJNo DYes ISJNo DYcs l8JNo uuu~ UC - ----------;;;NNN~-- DYes l8lNo DYes lZlNo Note l Consistent with prior reporting and previous discussions with Nrd:ED, this table does not include deviations previously reported to N!viED, including in reports under the NSPS, MACT, or other programs. Note 2 Refer to attached Table of Events Summary. I "Tl z :r- 0 0 0 0 ACC Part 2, Deviuation Summary Tit1e-V Permit# P051-R2 & R2Ml 0 01 (,) N 01 Page 144 of 144 EPA Inspection Report - Page 865 of 1969 Tab!e of Events Summary {<300 BTU) No. 2 {FL-0400} Deviation Started Date/Time 12/10/2018 23:00 02/20/2019 13:00 06/20/2019 16:00 Deviation Ended Date/Time 12/11/2018 11:00 02/20/2019 14:00 06/20/2019 19:00 Pollutant N/A N/A N/A Monitoring Method Pi Data Pi Data Pi Data Amount of Em!ssons N/A N/A N/A Excess Emission Form? No No No 2 12/10/2018 12:00 12/10/2019 13:00 N/A Pi Data N/A No {FL-0401} 2 09/11/2018 16:00 09/11/2018 18:00 N/A Pi Data N/A No (FL-0404) 12/11/2018 11:00 12/11/2018 12:00 N/A Pi Data N/A No 12/27/2018 04:00 12/27/2018 11:00 N/A Pi Data N/A No I "Tl z :r- 0 0 0 0 0 01 (,) N 1 of 1 0) EPA Inspection Report - Page 866 of 1969 New Mexico Environment Department - Air Quality Bureau Compliance and Enforcement Section 525 Camino de Los Marquez - Suite 1 - Santa Fe, NM 87505 Phone (505) 476-4300 - Email: nmenv-aqbeer@state.nm.us Excess Emissions Reporting Form Al Number: Activity Number: Facility Name: Company Name: Source ls: Portable Location: Title V Permit No.: NSR Permit No.: 198 000198-09292016-01 Navajo Refining Company LLC Navajo Refining - Artesia Refinery Stationary Source? Yes Portable Source? No UTM: Lat: Long: P051-R2M1 PSD0195-M37 Firstname I Lastname: E-mail Address: Raymond Smalts ray.smalts@ho!!yfrontier.com Emission Unit No.; Emission Unit Desc: Unit 55 General Plant, Racks, and Flares Release Point No.: Fl-0400 Release Point Desc.: North Plant Flare Discovery Date/Time: 11/01/2015 00:00 Start Date/Time: 11/01/2015 00:00 End Date/Time: 1st Business Day after Discovery: Submission Status: 11/02/2015 initial EER ..,_ ..... ...,.,.,.,.,.~--- Office Phone: 575-746-5490 iExl.n.: Cell Phone: Reporting Requirement wf 20.2.7 NMAC wf 20.2.70 NMAC (Title V) 0 40 CFR 60 (NSPS) 0 40 CFR 63 (MACT) 'If Malfunction D Startup 0 Shutdown D Emergency tJ Schedule Maintenance 'If Title V Deviation SS or SM Notification: Date: Explain: Affirmative Defense Claim: Yes Page 1 of 2 HFNA-000005327 EPA Inspection Report - Page 867 of 1969 Detailed Description: It was discovered that on approximately 11/01/2015, Navajo had potentially exceeded the permitted TPY limits for NOx, so2, co, and voe. Detailed Description: Detailed Description: tJ Compliance Testing D Continuous Emission Monitor D Calculation D Operating Log(s) tJ other: By clicking on the Certify button, I agree to the following: After reasonable inquiry, I certify this report as true, accurate and complete, Reporting Official: Raymond Smalts Title: Date: Environmental Specialist 09/29/2016 Page 2 of 2 HFNA-000005328 EPA Inspection Report - Page 868 of 1969 New Mexico Environment Department - Air Quality Bureau Compliance and Enforcement Section 525 Camino de Los Marquez - Suite 1 - Santa Fe, NM 87505 Phone (505) 476-4300 - Email: nmenv-aqbeer@state.nm.us Excess Emissions Reporting Form A! Number: Activity Number: Facility Name: Company Name: Source Is: Portable location: Title V Permit No.: NSR Permit No.: 198 000198-09292016-02 Navajo Refining Company LLC Navajo Refining - Artesia Refinery Stationary Source? Yes Portable Source? No UTM: Lat long: P051-R2M1 PSD0195-M37 Emission Unit No.: Emission Unit Desc: Unit 55 General Plant, Racks, and Flares Release Point No.: FL-0401 Release Point Desc.: South Plant Flare Discovery Date/Time: 11/01/2015 00:00 Start Date/Time: 11/01/2015 00:00 End Date/Time: 1st Business Day after Discovery: Submission Status: 11/02/2015 Initial EER Firstname I Lastname: Raymond Sma!ts E-mail Address: ray.smalts@hollyfrontier.com Office Phone: 575-746-5490 iExtn.: Cell Phone: Reporting Requirement: d' 20.2.7 NMAC d' 20.2.70 NMAC (Title V) D 40 CFR 60 (NSPS) 0 40 CFR 63 (MACT) ti Malfunction 0 Startup [j Shutdown D Emergency D Schedule Maintenance fl Title V Deviation SS or SM Notification: Date: Explain: Affirmative Defense Claim: Yes Page 1 of 2 HFNA-000005329 EPA Inspection Report - Page 869 of 1969 Detailed Description: It was discovered that on approximately 11/01/2015, Navajo had potentially exceeded the permitted TPY limits for NOx:, so2, co, and voe. Detailed Description: Detailed Description: O Compliance Testing ID Continuous Emission Monitor D Calculation D Operating Log(s} O Other: By clicking on the Certify button, I agree to the following: After reasonable inquiry, I certify this report as true, accurate and complete. Reporting Official: Raymond Smalls Title: Date: Environmental Specialist 09/29/2016 Page 2 of 2 HFNA-000005330 EPA Inspection Report - Page 870 of 1969 New Mexico Environment Department - Air Quality Bureau Compliance and Enforcement Section 525 Camino de Los Marquez - Suite 1 - Santa Fe, NM 87505 Phone (505) 476-4300 - Email: nmenv-aqbeer@state.nm.us Excess Emissions Reporting Form Al Number: Activity Number: Facility Name: Company Name: Source Is: Portable Location: Title V Permit No.: NSR Permit No.: 198 000198-09292016-03 Navajo Refining Company LLC Navajo Refining - Artesia Refinery Stationary Source? Yes Portable Source? No UTM: Lat Long: P051-R2M1 PSD0195-M37 Emission Unit No.: Emission Unit Desc: 'Unit 55 General Plant, Racks, and Flares Release Point No.: Fl-0402 Release Point Desc.: FCC Flare Discovery Date/Time: 11/01/2015 00:00 Start Date/Time: 11/01/2015 00:00 End Date/Time: 1st Business Day after Discovery: Submission Status: 11/02/2015 Initial EER Firstname / Lastname: E-mail Address: Raymond Smalts ray.smalts@hollyfrontier.com Office Phone: 575-746-5490 :Extn.: Cell Phone: Reporting Requirement: r! 20.2.7 NMAC r! 20.2.70 NMAC (Title V) 0 40 CFR 60 (NSPS) 0 40 CFR 63 (MACT) d Malfunction u Startup a Shutdown D Emergency [j Schedule Maintenance fl Title V Deviation SS or SM Notification: Date: Explain: Affirmative Defense Claim: Yes Page 1 of 2 HFNA-000005331 EPA Inspection Report - Page 871 of 1969 Detailed Description: !twas discovered that on approximately 11/01/2015, Navajo had potentially exceeded the permitted TPY limits for NOx, so2., co, and voe. Detailed Description: Detailed Description: [jj Compliance Testing D Continuous Emission Monitor D Calculation D Operating Log(s) [) Other; By clicking on the Certify button, I agree to the following: After reasonable inquiry, I certify this report as true, accurate and complete. Reporting Official: Raymond Smalts Title: Date: Environmental Specialist 09/29/2016 Page2of2 HFNA-000005332 EPA Inspection Report - Page 872 of 1969 New Mexico Environment Department - Air Quality Bureau Compliance and Enforcement Section 525 Camino de Los Marquez - Suite 1 - Santa Fe, NM 87505 Phone {505) 476-4300 - Email: nmenv-aqbeer@state.nm.us Excess Emissions Reporting Form Al Number: Activity Number: Facility Name: Company Name: Source Is: Portable Location: Title V Permit No.: NSR Permit No.: 198 000198-09292016-04 Navajo Refining Company lLC Navajo Refining - Artesia Refinery Stationary Source? Yes Portable Source? No UTM: lat: Long: P051-R2M1 PSD0195-M37 Emission Unit No.: Emission Unit Desc: Unit 55 General Plant, Racks, and Flares Release Point No.: Fl-0403 Release Point Desc.: Alky Flare Discovery Date/Time: 11/01/2015 00:00 Start Date/Time: 11/01/2015 00:00 End Date/Time: 1st Business Day after Discovery: Submission Status: 11/02/2015 Initial EER W"'-----------------~------------------~----- - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ -...""- Firstname I Lastname: Raymond Sma!ts Office Phone: 575-746-5490 !Extn.: E-mail Address: ray.smalts@hollyfrontier.com Cell Phone: Reporting Requirement: d 20.2.7 NMAC d 20.2.70 NMAC (Title V) D 40 CFR 60 (NSPS) D 40 CFR 63 (MACT} 1 Malfunction [J Startup [j Shutdown Cl Emergency D Schedule Maintenance ft Title V Deviation SS or SM Notification: Date: Explain: Affirmative Defense Claim: Yes Page 1 of 2 HFNA-000005333 EPA Inspection Report - Page 873 of 1969 Detailed Description: It was discovered that on approximately 11/01/2015, Navajo had potentially exceeded the permitted TPY limits for NOx, 802, co, and voe. Detailed Description: Detailed Description: D Compliance Testing D Continuous Emission Monitor D Calculation D Operating Log(s) D Other: By clicking on the Certify button, I agree to the following: After reasonable inquiry, I certify this report as true, accurate and complete. Reporting Official: Raymond Smalts Title: Date: Environmental Specialist 09/29/2016 Page 2 of 2 HFNA-000005334 EPA Inspection Report - Page 874 of 1969 New Mexico Environment Department - Air Quality Bureau Compliance and Enforcement Section 525 Camino de Los Marquez - Suite 1 - Santa Fe, NM 87505 Phone (505) 476-4300 - Email: nmenv-aqbeer@state.nm.us Excess Emissions Reporting Form Al Number: Activity Number: Facility Name: Company Name: Source Is: Portable Location: Title V Permit No.: NSR Permit No.: 198 000198-09292016-05 Navajo Refining Company LLC Navajo Refining - Artesia Refinery Stationary Source? Yes Portable Source? No UTM: Lat Long: P051-R2M1 PSD0195-M37 .-~~~~~~~~~~~~~~~~===~ Firstname I Lastname: Raymond Smalts E-mail Address: ray.smalts@hoilyfrontier.com Emission Unit No.: Emission Unit Desc: Unit 55 General Plant, Racks, and Flares Release Point No.: FL-0404 Release Point Desc.: GOHT Flare Discovery Date/Time: 11/01/2015 00:00 Start Date/Time: 11/01/2015 00:00 End Date/Time: 1st Business Day after Discovery: Submission Status: 11/02/2015 Initial EER ,.,.,,..,.,,..,.,.,.,,..,.,.,.,.,.,.,.,.,.,.,.,.,, Office Phone: 575-746-5490 -----=~................................................ Extn.: Cell Phone: Reporting Requirement: ~ 20.2.7 NMAC ~ 20.2.70 NMAC (Title V) 0 40 CFR 60 (NSPS) 0 40 CFR 63 (MACT) r,t Malfunction a Startup D Shutdown D Emergency D Schedule Maintenance tf Title V Deviation SS or SM Notification: Date: Explain: Affirmative Defense Claim: Yes Page 1 of 2 HFNA-000005335 EPA Inspection Report - Page 875 of 1969 Detailed Description: It was discovered that on approximately i 1/01/2015, Navajo had potentially exceeded the permitted TPY !imits for NOx, so2, co, and voe. Detailed Description: Detailed Description: D Compliance Testing 0 Continuous Emission Monitor 0 Calculation CJ Operating Log(s) Cl other: By clicking on the Certify button, I agree to the following: After reasonable inquiry, I certify this report as true, accurate and complete. Reporting Official: Raymond Smalts Title: Date: Environmental Specialist 09/29/2016 Page 2 of 2 HFNA-000005336 EPA Inspection Report - Page 876 of 1969 New Mexico Envkonment Department - Air Quality Bureau Compliance and Enforcement Section 525 Camino de Los Marquez - Suite 1 - Santa Fe, NM 87505 Phone (505} 476-4300 - Email: nrnenv-aqbeer@state.nm.us Excess Emissions Reporting Form Al Number: Activity Number: Facility Name: Company Name: Source Is: Portable Location: Title V Permit No.: NSR Permit No.: 198 000198-09292016-06 Navajo Refining Company LLC Navajo Refining - Artesia Refinery Stationary Source? Yes Portable Source? No UTM: Lat: Long: P051-R2M1 PS00195-M37 Emission Unit No.: Unit 55 Emission Unit Desc: Genera! Plant, Racks, and Flares Release Point No.: Flare Malt Cap Release Point Desc.: Upset and Malfunction Emissions Discovery Date/Time: 11/01/2015 00:00 Start Date!Time: 11/01/2015 00:00 End Date!Time: 1st Business Day after Discovery: Submission Status: 11/02/2015 Initial EER Firstname I Lastname: E-mail Address: Raymond Smalts ray.sma!ts@ho!!yfrontier.com Office Phone: 575-746-5490 JExtn.: Cell Phone: Reporting Requirement d 20.2.7 NMAC tf 20.2.70 NMAC (Title V) 0 40 CFR 60 (NSPS) D 40 CFR 63 (MACT) d Malfunction [J Startup D Shutdown [j Emergency D Schedule Maintenance fll Title V Deviation SS or SM Notification: Date: Explain: Affirmative Defense Claim: Yes Page 1 of 2 HFNA-000005337 EPA Inspection Report - Page 877 of 1969 Detailed Description: lt was discovered that on approximately 11/01/2015, Navajo had potentially exceeded the permitted TPY limits for NOx, so2, co, and voe. Detailed Description: Detailed Description: D Compliance Testing 0 Continuous Emission Monitor D Calculation D Operating Log(s) Other: By clicking on the Certify button, I agree lo the following: After reasonable inquiry, I certify !his report as true, accurate and complete. Reporting Official: Raymond Smalts Trtle: Date: Environmental Specialist 09/29/2016 Page 2 of 2 HFNA-000005338 EPA Inspection Report - Page 878 of 1969 EPA Inspection Report - Page 879 of 1969 Air Quality Bureau NEW SOURCE REVIEW PERMIT Issued under 20.2.72 NMAC Certified Mail No: 7013 2630 0000 9073 8649 Return Receipt Requested NSR Permit No: Facility Name: PSD-NM-0195-M37 Artesia Refinery Facility Owner: Operator/Permittee Name: Mailing Address: Robert O'Brien HollyFrontier Navajo Refining LLC P.O. Box 159 Artesia, New Mexico 88211-0159 TEMPO/IDEA ID No: AIRS No: 198 - PRN20160002 35-015-0010 Permitting Action: Source Category: PSD Minor Modification Major-TV and PSD with BACT Facility Location: County: UTMH 557021 m, UTMV 3633819 m, UTMZ 13 Eddy, Datum: NAD27 Air Quality Bureau Contact Main AQB Phone No. Joseph Kimbrell (505) 476-4300 Richard L. Goodyear, PE Date Bureau Chief Air Quality Bureau EPA Inspection Report - Page 880 of 1969 TABLE OF CONTENTS Part A FACILITY SPECIFIC REQUIREMENTS ................................................................. A3 A100 Introduction.............................................................................................................. A3 A101 Permit Duration (expiration).................................................................................... A5 A102 Facility: Description................................................................................................. A5 A103 Facility: Applicable Regulations.............................................................................. A7 A104 Facility: Regulated Sources ................................................................................... A10 A105 Facility: Control Methods ...................................................................................... A10 A106 Facility: Allowable Emissions ............................................................................... A13 A107 Facility: Allowable Startup, Shutdown, & Maintenance (SSM) and Malfunction Emissions ............................................................................................................................... A14 A108 Facility: Allowable Operations .............................................................................. A17 A109 Facility: Reporting Schedules ................................................................................ A17 A110 Facility: Fuel and Fuel Requirements .................................................................... A18 A111 Facility: 20.2.36 NMAC - repealed 1/29/2016 ..................................................... A19 A112 Facility: 20.2.37 NMAC ........................................................................................ A19 A113 Facility: 20.2.38 NMAC ........................................................................................ A21 A114 Facility: Relocation Requirements - Not Required ............................................... A22 A115 Alternative Operating Scenario - Not Required .................................................... A22 A116 Compliance Plan - Not Required .......................................................................... A22 A117 Reducing Facility Emissions.................................................................................. A22 A118 Facility: MACT Subpart UUU............................................................................... A22 A119 40 CFR 61 Subpart FF, National Emission Standard for Benzene Waste Operations A23 EQUIPMENT SPECIFIC REQUIREMENTS .......................................................................... A23 Oil and Gas Industry .................................................................................................................. A23 A200 Oil and Gas Industry .............................................................................................. A23 A201 Engines................................................................................................................... A23 A202 Glycol Dehydrators - Not Required ...................................................................... A24 A203 Tanks...................................................................................................................... A24 A204 Heaters/Boilers....................................................................................................... A26 A205 Turbines not required ............................................................................................. A36 A206 Flares...................................................................................................................... A36 A207 Sulfur Recovery Plant (SRP), Tail Gas Incinerator (TGI)..................................... A37 A208 Amine Unit - Not Required ................................................................................... A40 A209 Fugitives................................................................................................................. A40 A210 Loading Racks ....................................................................................................... A41 A211 Fluid Catalytic Cracking Unit (FCC)..................................................................... A41 A212 Cooling Towers...................................................................................................... A44 A213 Wastewater Systems .............................................................................................. A45 Part D ATTACHMENTS...................................................................................................... A46 PART B GENERAL CONDITIONS (Attached) EPA Inspection Report - Page 881 of 1969 PART C MISCELLANEOUS: Supporting On-Line Documents; Definitions; Acronyms (Attached) PART A FACILITY SPECIFIC REQUIREMENTS A100 Introduction A. This permit PSD-NM-0195-M37 supersedes all portions of Air Quality Permit PSD-NM0195-M36, issued January 27, 2016, except the portion requiring compliance tests. Compliance test conditions from previous permits, if not completed, are still in effect, in addition to compliance test requirements contained in this permit. B. The permit limits and control methods below are BACT, and any change or revision of these limits or control methods must be applied for in accordance with PSD, 20.2.74 NMAC, including the public notice. (1) NOx - The steam-methane reformer furnace (H-9851) shall be equipped with a selective catalytic reduction (SCR) control system to reduce NOx emissions to 0.0125 lb per MM Btu (LHV basis) on a hourly rolling 3-hour average basis at 3% excess oxygen. The SCR exhaust is limited to 7 ppmv ammonia slip, measured on a wet basis. During startup, shutdown, schedule maintenance or malfunction of the SCR control system, BACT for H-9851 shall be ultra low NOx burners emitting no more than 0.03 lb per MMBtu (LHV) on a hourly rolling 3-hour average basis at 3% excess oxygen. Pound per hour and tons per year limits are based on the lb/MMBtu limits and were used to demonstrate compliance with the lb/MMBtu limits and the Ambient Air Quality Standards (AAQS). (2) NOx - The remaining process heaters H-2501, H-3402, and H-3101 shall be equipped with Next Generation Ultra-Low NOx Burners (NGULNBs) emitting no more than 0.03 lb NOx per MM Btu (LHV basis) on a hourly rolling 3-hour average basis at 3% excess oxygen. Pound per hour and tons per year limits are based on the lb/MMBtu limits and were used to demonstrate compliance with the lb/MMBtu limits and the (AAQS). (3) CO - The steam-methane reformer furnace H-9851 and the ROSE-2 hot oil heater H-2501 are each limited to 0.06 lb CO per MM Btu (LHV basis) on a hourly rolling 3-hour average basis. Pound per hour and tons per year limits are based on the lb/MMBtu limits and were used to demonstrate compliance with the lb/MMBtu limits and the (AAQS). (4) CO - The other proposed process heaters H-3402, and H-3101 are each limited to 0.09 lb CO per MM Btu (LHV basis) on a hourly rolling 3-hour average basis. Pound per hour and tons per year limits were based on the lb/MMBtu limits and are used to demonstrate compliance with the lb/MMBtu limits and the (AAQS). EPA Inspection Report - Page 882 of 1969 (5) VOC - The combustion sources proposed in Permit 195-M25 (Units SRU-TGI, H2501, H-3101, and H-3402,) shall exclusively combust gaseous fuels. Gaseous fuels is defined as purchased natural gas, refinery gas or a combination of natural and refinery gas but does not include liquid or solid fuel. (6) PM10 - The combustion sources proposed in Permit 195-M25 (Units SRU-TGI, H-2501, H-3101, and H-3402,) shall exclusively combust gaseous fuels. (7) SO2 - Fuel sulfur limit Refinery-Wide for all units burning refinery fuel gas (excluding units H-8801, H-8802 and H-9851 which burn only natural gas) shall not exceed 60 ppmv H2S on a daily rolling 365-day average. The ton/yr emission rates for SO2 in Table 106.A of this permit are based on this daily rolling 365-day average 60 ppmv H2S limit. Compliance with this limit shall be demonstrated per the methods described in Condition A110.A. (8) SO2 - The Sulfur Recovery Unit No. 3 Tail Gas Incinerator (SRU3-TGI) is limited to 192 ppmvd SO2 at zero percent oxygen on a hourly rolling 12-hour average basis. In addition, SRU3-TGI is limited to 192 ppmvd SO2 at zero percent oxygen on a daily rolling 365-day average basis. (9) VOC - The naphtha storage tank T-1225 and sour water storage tank T-0737 shall be equipped with an external floating roof using double seals to reduce VOC emissions to the atmosphere. The maximum true vapor pressure of any volatile organic liquid stored in either tank shall not exceed 11.0 psia. Demonstration of compliance is through the NSPS Kb and MACT emission limits. (10) VOC - All fugitive piping components in VOC service associated with the process units proposed in Permit 195-M25 (Units FUG-25-ROSE-2, FUG-31SRU3/TGI3/TGI3, and FUG-34-Hydorcracker)shall be monitored under the MACT subpart CC leak detection and repair program, or an approved equivalent program, to reduce VOC emissions. (11) VOC - Consistent with MACT Subpart CC, the gasoline truck loading rack (TLO4) shall be limited to 10 mg of VOC emissions per liter of gasoline loaded. (12) PM10 - Cooling towers, Units Y-0011 and Y-0012, shall be equipped with highefficiency drift eliminators to reduce PM10 emissions. Demonstration of compliance is through annual inspection in accordance with in Condition A212.A. (13) For Boiler Unit B-0009: BACT NOx limit of 0.02 lb/MM Btu, CO2 limit of 112.1 lb/MM Btu. The unit shall be designed and equipped with control devices and enhancements to effect reduction of Green House Gases through improved process controls. BACT has been determined and includes the use of the following energy efficiency control methods which would be the most feasible GHG BACT options based on energy, economic, and environmental aspects: Operation and Maintenance (BACT #6): Periodic Boiler Tuning - The boilers are tuned periodically to maintain optimal thermal efficiency. EPA Inspection Report - Page 883 of 1969 Periodic Boiler Inspection and Repair for air leakage - The boilers are inspected periodically to maintain optimal thermal efficiency. Periodic Boiler Inspection and Cleaning for tube fouling. Condensate recovery through periodic steam trap inspections and repairs. Next Generation Ultra-low-NOx high efficiency burners (NGULNB) (#5) Flue gas economizer (#2) - Use of a heat exchanger to recover heat from the exhaust gas to preheat incoming boiler feedwater to attain industry standard performance (IMO) for thermal efficiency. Boiler insulation (#4). Oxygen Trim Control (#7) - Monitoring of oxygen concentration in the flue gas is conducted, and the inlet air flow is adjusted to maximize thermal efficiency. Boiler blowdown minimization using manual analysis (#3) - Minimize blowdowns from the boiler to keep emissions at a minimum. Condensate recovery (#8). C. The permittee is under a Consent Decree CIV-01 1422LH Lodged 12/20/2001, Entered 3/5/2002 and referenced throughout this document as the "Consent Decree" or "CD" with reference numbers from that document. A101 Permit Duration (expiration) A. The term of this permit is permanent unless withdrawn or cancelled by the Department. A102 Facility: Description A. The function of the facility is to process crude oil and petroleum distillates into petroleum products such as diesel, gasoline and asphalt. B. This facility is located in the city limits of Artesia, NM. C. The modification and permit revisions consist of: (1) Authorizing process equipment modifications to increase production at the following units: (a) Unit FUG-06-NHDU - Naphtha Hydrodesulfurization Unit (b) Unit FUG-13-NHDU - Naphtha Hydrodesulfurization Unit (c) Unit FUG-20-ISOM - BenFree Unit (previously identified as Isom Unit) (d) Unit FUG-33-DIST HDU - Diesel Hydrodesulfurization Unit, and (e) Additionally, a stream from Unit 44 (Gas Oil Hydrotreater) will be routed to Unit 33. (2) Remove the following storage tanks that are out of service: T-0013, T-0058, T-0404, T-0405, T-0409, T-0810, and T-0078 which was never constructed. EPA Inspection Report - Page 884 of 1969 (3) TK-NEWETHANOL and TK-BIODIESEL were originally permitted as an external floating roof tank and fixed roof tank; however, both were constructed as internal floating roof tanks. Permit representations for these tanks are being updated with the as constructed information and tank ID Numbers: T-0451 and T-0452. (4) SSM T-0078, SSM T-0079, and SSM T-1225 are being removed from the permit. SSM tank emissions are included under ID "SSM Tanks" which is being updated as part of the project. (5) SSM Misc 1 for catalyst handling emissions is being removed from Table 2A and is exempted on Table 2B. Emissions associated with changing catalyst at the refinery meet exemption criteria in 20.2.72.202.B.5. The description of this modification is for informational purposes only and is not enforceable. D. Table 102.A and Table 102.B show the total potential emissions from this facility for information only, not an enforceable condition, excluding exempt sources or activities. Table 102.A: Total Potential Pollutant Emissions from Entire Facility Pollutant Emissions (tons per year) Nitrogen Oxides (NOx) 729.6 Carbon Monoxide (CO) 1281.9 Volatile Organic Compounds (VOC) 1531.0 Sulfur Dioxide (SO2) 374.1 Total Suspended Particulates (TSP) 207.1 Particulate Matter less than 10 microns (PM10) 207.1 Particulate Matter less than 2.5 microns (PM2.5) 207.1 Hydrogen Sulfide (H2S) 4.7 Greenhouse Gas (GHG) (CO2e) >100,000 Note: Total Potential Pollutant Emissions in Table 102.A,may include fugitive emissions; routine or predictable, startup, shutdown, and maintenance emissions (SSM); and permitted malfunction allowances if these are a sources of regulated air pollutants from this facility. Table 102.B: Total Potential Hazardous Air Pollutants (HAPs)* and State Toxic Air Pollutants (TAPs) Pollutant Emissions (tons per year) Ammonia Benzene 6.1 36.26 Ethylbenzene 16.39 Toluene; (Methyl benzene) 27.63 Xylenes (total); (Xylol) 14.03 EPA Inspection Report - Page 885 of 1969 Table 102.B: Total Potential Hazardous Air Pollutants (HAPs)* and State Toxic Air Pollutants (TAPs) Pollutant Hexane Emissions (tons per year) 144.71 Total HAPs** 239.04 * HAP emissions are included in the Table 102.A VOC emissions total. ** Total HAP emissions may not agree with the sum of individual HAPs because only individual HAPs emitted at a rate greater than 1.0 ton per year are listed in Table 102.B. A103 Facility: Applicable Regulations A. The permittee shall comply with all applicable sections of the requirements listed in Table 103.A. Table 103.A: Applicable Requirements Applicable Requirements 20.2.1 NMAC General Provisions 20.2.3 NMAC Ambient Air Quality Standards 20.2.7 NMAC Excess Emissions 20.2.33 NMAC Gas Burning Equipment -- Nitrogen Dioxide 20.2.37 NMAC Petroleum Processing Facilities 20.2.38 NMAC Hydrocarbon Storage Facilities 20.2.61 NMAC Opacity 20.2.70 NMAC Operating Permits 20.2.71 NMAC Operating Permit Emission Fees 20.2.72 NMAC Construction Permit 20.2.73 NMAC Notice of Intent and Emissions Inventory Requirements 20.2.74 NMAC Prevention of Significant Deterioration 20.2.75 NMAC Construction Permit Fees 20.2.77 NMAC New Source Performance 20.2.78 NMAC Emission Standards for Hazardous Air Pollutants (HAPs) 20.2.82 NMAC MACT Standards for Source Categories of HAPS 40 CFR 50 National Ambient Air Quality Standards Federally Enforceable X X X X X X X X X X X X X X X X X Unit No. Entire Facility Entire Facility Entire Facility Affected sources in Table 103.E Entire Facility unless repealed Entire Facility Combustion sources if 20.2.37 NMAC is repealed. Entire Facility Entire Facility Entire Facility Entire Facility Entire Facility Entire Facility Units subject to 40 CFR 60 Units subject to 40 CFR 61 Units subject to 40 CFR 63 Entire Facility EPA Inspection Report - Page 886 of 1969 Table 103.A: Applicable Requirements Applicable Requirements 40 CFR 60, Subpart A, General Provisions 40 CFR 60, Subpart Db "Standards of Performance for Industrial-Commercial-Institutional Steam Generating Units" 40 CFR 60, Subpart Dc "Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units, Which Construction, Reconstruction, or Modification Commenced After June 9, 1989" 40 CFR 60, Subpart J, "Standards of Performance for Petroleum Refineries" 40 CFR 60, Subpart Ja, "Standards of Performance for Petroleum Refineries for which Construction, Reconstruction, or Modification Commenced After May 14, 2007" 40 CFR 60, Subpart K, "Standards of Performance for Storage Vessels for Petroleum Liquids for Which Construction, Reconstruction, or Modification Commenced After June 11, 1973, and Prior to May 19, 1978" 40 CFR 60, Subpart Ka, "Standards of Performance for Storage Vessels for Petroleum Liquids for Which Construction, Reconstruction, or Modification Commenced After May 18, 1978, and Prior to July 23, 1984" 40 CFR 60, Subpart Kb, "Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification Commenced After January 23, 1984" 40 CFR 60, Subpart GGG, Standards of Performance for Equipment Leaks of VOC in Petroleum Refineries for which construction, reconstruction, or modification commenced after January 4, 1983, and on or before November 7, 2006. 40 CFR 60, Subpart GGGa, Standards of Performance for Equipment Leaks of VOC in Petroleum Refineries for which construction, reconstruction, or modification commenced after November 7, 2006. Federally Enforceable X X X X X X X X X X Unit No. See Tables 103.B to 103.K See Tables 103.B to 103.J H-0464; H-3101 See Tables 103.B to 103.J See Tables 103.B to 103.J See Tables 103.B to 103.J See Tables 103.B to 103.J See Tables 103.B to 103.K See Tables 103.B to 103.K See Tables 103.B to 103.K EPA Inspection Report - Page 887 of 1969 Table 103.A: Applicable Requirements Applicable Requirements 40 CFR 60, Subpart QQQ, Standards of Performance for VOC Emissions From Petroleum Refinery Wastewater Systems 40 CFR 60, Subpart IIII, Standards of Performance for Stationary Compression Ignition Internal Combustion Engines 40 CFR 61, Subpart A, General Provisions 40 CFR 61, Subpart FF, National Emission Standards for Benzene Waste Operations 40 CFR 63, Subpart A, General Provisions 40 CFR 63, Subpart CC Federally Enforceable X X X X X X 40 CFR 63 Subpart DDDDD X 40 CFR 63 Subpart UUU, Petroleum Refineries: Catalytic Cracking Units, Catalytic Reforming Units, and Sulfur X Recovery Units 40 CFR 63, Subpart ZZZZ, National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating X Internal Combustion Engines 40 CFR 68, (RMP), Section 112(r) Accidental Release X Consent Decree CIV-01 1422LH Lodged 12/20/2001, Entered 3/5/2002 X Note: Tables 103.B through 103.K are located in Attachment D. Unit No. See Tables 103.B to 103.K See Tables 103.B to 103.K Entire Facility Benzene Waste Operations Entire Facility See Tables 103.B to 103.K See Tables 103.B to 103.K See Tables 103.B to 103.K See Tables 103.B to 103.K Entire Facility Entire Facility Table 103.B, Summary Applicability - Fugitives Table 103.C, Summary Applicability - Tanks Table 103.D, Summary Applicability - Loading Table 103.E, Summary Applicability - Heaters and Boilers Table 103.F, Summary Applicability - Cooling Towers Table 103.G, Summary Applicability - Wastewater Table 103.H, Summary Applicability - FCC-CCR Table 103.I, Summary Applicability - SRU EPA Inspection Report - Page 888 of 1969 Table 103.J, Summary Applicability - Engines Table 103.K, Summary Applicability - Flares A104 Facility: Regulated Sources A. Table 104.A (attached) lists the emission units authorized for this facility. Emission units that were identified as NSR exempt or Title V Insignificant activities and/or equipment not regulated pursuant to the Act are not included. A105 Facility: Control Methods A. Table 105.A lists all the pollution control equipment required for this facility. Each emission point is identified by the same number that was assigned to it in the permit application. Table 105.A: Control Methods: Control Equipment Unit Control Description No. Fluid Catalytic FCC Regenerator Cracking Unit Scrubber Regenerator Cyclones + Wet Gas Scrubber CHLOR SORB CCR Regenerator Vent Control BACT Yes or No NO NO Pollutant being controlled PM & SO2 Chloride FL-0400 North Plant Flare NO VOC & H2S FL-0401 South Plant Flare NO VOC & H2S FL-0402 FCC Flare NO VOC & H2S FL-0403 Alky Flare NO VOC FL-0404 FL-HEP-PORT H-0473 GOH Flare Portable Flare for Holly Energy Partners (HEP) Pipeline Pigging Operations Sulfur Recovery Units No. 1 & 2 Tail Gas Incinerator NO VOC & H2S NO VOC NO Sulfur Control for Unit Number(s)1 FCC Regenerator CCR Regenerator Vent Refinery process units Refinery process units Refinery process units Refinery process units Refinery process units Pipeline Pigging Operations SRU1 and SRU2 EPA Inspection Report - Page 889 of 1969 Table 105.A: Control Methods: Control Equipment Unit No. Control Description BACT Pollutant being Yes or No controlled Control for Unit Number(s)1 Selective Catalytic SCR Reduction + ultra-low YES NOx H-9851 NOx burners Sulfur Recovery Unit SRU3-TGI No. 3 Tail Gas YES Sulfur SRU3 Incinerator SRU3/TGTU3/TGI3 Best Work Practices, A207.B (BACT) YES SO2 SRU3 D-0829/0830 Main API Carbon Canisters NO VOC MAIN API Y-0011, Y-0012 Drift Eliminators on Cooling Towers (BACT) YES PM Y-0011, Y0012 T-0737, T-1225 External Floating Roofs (BACT) YES VOC T-0737, T1225 See Tables 106.B(1) and (2) External and Internal Floating Roofs (None-BACT) NO VOC See Tables 106.B(1) and (2) B-0009 Energy Efficiency, A204.N (BACT) Yes Greenhouse Gases B-0009 H-2501, H-3402, H- ultra-low NOx 3101 burners (BACT) Yes NOx H-2501, H3402, H-3101 SRU-TGI, H-2501, H-3402, H-3101 Combust gaseous fuels only Yes VOC, PM SRU-TGI, H2501, H-3402, H-3101 1 Control for unit number refers to a unit number from the Regulated Source List B. In accordance with the requirement that Navajo Refining prevent exceedances of the 24hour and 3-hour National Ambient Air Quality Standards (NAAQS) for SO2 during major refinery malfunctions, Navajo Refining shall only flare acid gas from existing Flare FL-0403 according to Navajo Refining's "Phase Two" plan dated January 5, 1996 and received by the Department on January 8, 1996, or from Flare FL-0400. Navajo shall undertake the following measures for acid gas flaring from FL-0400 and FL-0403. EPA Inspection Report - Page 890 of 1969 (1) Existing Flare FL-0400 shall be equipped with a flare tip or burners to supply supplemental fuel gas to CHART NO. 1 SUPP FUEL FOR SO2 NAAQS COMPLIANCE, FL-400 provide enough heat to supplement the 90.0 heat released by combustion of the acid 80.0 Acid Gas FLow (Mscfh) gas itself and the heat provided by 70.0 60.0 smoke-suppressing steam. The 50.0 minimum flow rate of supplemental 40.0 fuel gas to be supplied during acid gas 30.0 flaring such that compliance with the 20.0 10.0 NAAQS for SO2 is assured shall be 0.0 determined using Chart No. 1. The 0 10 20 30 40 50 60 70 fuel gas used for this purpose shall be Supp Fuel Gas Flow (Mscfh) sweetened fuel gas or sweet natural gas (see definition at C101.E). (2) Existing Flare FL-0403 shall be equipped with a flare tip or burners to CHART NO. 2 supply supplemental fuel gas to SUPP. FUEL FOR SO2 NAAQS COMPLIANCE, FL-403 provide enough supplemental heat. 40 The volume of supplemental fuel gas 35 30 to be provided to generate enough 25 supplemental heat to ensure 20 Supp. Fuel Gas compliance with NAAQS for SO2 15 shall be determined using Chart No. 2. 10 The supplemental heat to be provided 5 when flaring the maximum quantity of 0 0 20 40 60 80 100 acid gas has been determined to be Supp. Fuel Gas (Thousand SCFH) 52.9 million BTU per hour which is generated by burning 96,200 SCFH of supplemental fuel gas. This assumption has been made to ensure compliance with the NAAQS for SO2. The fuel gas used for this purpose shall be sweetened fuel gas or sweet natural gas. C. Beginning December 20, 2001 no fuel oil shall be burned in combustion units except as follows: (CD 17.C) (1) Torch Oil may be burned in the FCC Regenerator during FCC start-ups; and. (2) Fuel Oil may be burned in combustion units after the establishment of FCC NOx emissions limits pursuant to permit condition A110.A, provided that emissions from any such combustion units are routed through the FCC Wet Gas Scrubber and Navajo demonstrates, with the approval of EPA, that the NOx emissions limits contained therein and the SO2 emissions limits stated in A106.A will continue to be met. EPA Inspection Report - Page 891 of 1969 D. The Artesia Refinery FCC was initially limited to less than 20,000 BPD capacity. Following the December 2003 expansion of the Artesia refinery's FCC as authorized by permit 195M15, the catalyst regenerator for the FCC is subject to the minimum requirements for continuous emission monitoring and recording set forth in Appendix P to 40 CFR Part 51. Consent Decree Paragraph 15 required the FCC to be subject to NSPS Subpart J for opacity as of December 31, 2003. A wet gas scrubber was installed in 2003. An Alternative Monitoring Plan (AMP) request was submitted to EPA on December 31, 2003 because a continuous opacity monitoring system (COMS) will not work on a wet gas scrubber exhaust because of the interference from the water vapor. The AMP satisfies the requirements for both NSPS Subpart J and 40 CFR Part 51 Appendix P. A106 Facility: Allowable Emissions A. The following Section list the emission units and their allowable emission limits. (See Table 103.A for all applicable regulations) Table 106.A: Allowable Emissions (attached) B. The permitted emission sources at the refinery shall consist only of the sources listed in Table 106.A and Tables 106.B through 106.I and 107.A of this permit. C. Compliance with Allowable Emission Limits Requirement: The allowable mmBtu/hr, lb/mmBtu, lb/hr, and tpy emission limits for equipment listed in Table 106.A construction are based on an hourly rolling 3-hour average. Monitoring: For units with lb/mmBtu emission limits in Table 106.A, the Permittee shall monitor the lb/mmBtu to demonstrate compliance with the mmBtu/hr, lb/hr, and tpy emission limits. Recordkeeping: To demonstrate compliance, records shall be kept on a monthly basis showing the correlation between lb/mmBtu and hourly and 12-month rolling yearly totals. The records shall also document any non-compliance with emission limits. For each unit, a summary of the method used to determine compliance shall be recorded. The permittee shall maintain records in accordance with Section B109. Reporting: The permittee shall report in accordance with Section B110. D. BACT SO2 Limit - Fuel sulfur limit Refinery-Wide for all units burning refinery fuel gas (excluding units H-8801, H-8802 and H-9851 which burn only natural gas) shall not exceed 60 ppmv H2S on a daily rolling 365-day average. The ton/yr emission rates for SO2 in Table 106.A of this permit are based on this daily rolling 365-day average 60 ppmv H2S limit. Compliance with this limit shall be demonstrated per the methods described in Condition A110.A. EPA Inspection Report - Page 892 of 1969 E. BACT NOx Limit - In addition to the emission limits shown in Table 106.A, Boiler Unit B0009 has a BACT NOx limit of 0.02 lb/MM Btu, and CO2 limit of 112.1 lb/MM Btu. F. BACT SO2 Limit - The Sulfur Recovery Unit No. 3 Tail Gas Incinerator (SRU3-TGI) is limited to 192 ppmvd SO2 at zero percent oxygen on a hourly rolling 12-hour average basis. In addition, SRU3-TGI is limited to 192 ppmvd SO2 at zero percent oxygen on a daily rolling 365-day average basis. G. BACT VOC Limit - The naphtha storage tank T-1225 and sour water storage tank T-0737 shall be equipped with an external floating roof using double seals to reduce VOC emissions to the atmosphere. The maximum true vapor pressure of any volatile organic liquid stored in either tank shall not exceed 11.0 psia. Demonstration of compliance is through the NSPS Kb and MACT emission limits. H. VOC - All fugitive piping components in VOC service associated with the process units proposed in Permit 195-M25 (Units FUG-25-ROSE-2, FUG-31-SRU3/TGI3/TGI3, and FUG-34-Hydorcracker) shall be monitored under the MACT subpart CC leak detection and repair program, or an approved equivalent program, to reduce VOC emissions. I. VOC - Consistent with MACT Subpart CC, the gasoline truck loading rack (TLO-4) shall be limited to 10 mg of VOC emissions per liter of gasoline loaded. J. PM10 - Cooling towers, Units Y-0011 and Y-0012, shall be equipped with high-efficiency drift eliminators to reduce PM10 emissions. Demonstration of compliance is through annual inspection in accordance with in Condition A212.B. A107 Facility: Allowable Startup, Shutdown, & Maintenance (SSM) and Malfunction Emissions A. The maximum allowable SSM emission limits for specific units are listed in Table 107.A and were relied upon by the Department to determine compliance with applicable regulations. Table 107.A: Allowable SSM and Malfunction Emissions Units, Activities, and Emission Limits (attached) B. The authorization of emission limits for startup, shutdown, maintenance, (SSM) and malfunction does not supersede the requirements to minimize emissions according to Conditions B101.C and B107.A. C. SSM Flaring and combustion Emissions Requirement: The permittee shall comply with the flaring and combustion SSM NOx, CO, VOC, SO2, TSP, PM10, PM2.5, and H2S emission limits at Table 107.A for the following SSM events: 1) SSM H-9851, Emissions during SCR downtime EPA Inspection Report - Page 893 of 1969 2) SSM SRU-TGI, Emissions from SRU3 startup and shutdown 3) SSM FL-HEP-PORT, Temporary, portable flare for natural gas pipeline maintenance 4) SSM SRU2-TGI (H-0473), Emissions from SRU2 startup and shutdown 5) SSM Flare Cap, Emissions from venting SSM activity gases to FL-400, FL-401, FL-402, FL-403, or FL-404 6) SSM Misc 2, Low-Emitting Maintenance Activities such as de-inventorying small equipment, clearing piping associated with emission units, and routine maintenance activities such as heat exchanger repair. Monitoring: The permittee shall monitor all flaring and combustion due to routine and predictable startups, shutdowns, and scheduled maintenance events. This shall be accomplished by collecting all the SSM flaring and combustion information specified in A107C. Recordkeeping. Recordkeeping: The permittee shall record the date, start and end times, and duration of every SSM flaring or combustion event. The NOx, CO, VOC, SO2, TSP, PM10, and H2S emissions shall be calculated for each event based on the volume of gas sent to the flare and the total sulfur content of the flared gas. Compliance with the hourly emission rates shall be demonstrated by calculating the hourly emission rates for each event and comparing the results to the hourly emission rate at Table 107.A. The annual emission rate shall be calculated as follows: 1) To demonstrate compliance during the first 12-months of monitoring, the permittee shall calculate and sum the monthly cumulative total of NOx, CO, VOC, SO2, TSP, PM10, PM2.5, and H2S emissions; and 2) After the first 12-months of monitoring, the permittee shall calculate and sum the total of NOx, CO, VOC, SO2, TSP, PM10, PM2.5, and H2S emissions on a monthly rolling 12-month basis. 3) The permittee shall maintain all records in accordance with Section B109. Reporting: The permittee shall report in accordance with Section B110. D. SSM VOC Emissions (Facility-Wide, Non-Combustion Sources) Requirement: The permittee shall comply with the SSM VOC emission limit at Table 107.A. Monitoring: The permittee shall monitor all VOC emission activities due to routine and predictable startups, shutdowns, and scheduled maintenance events. This shall be accomplished by collecting VOC emission calculation information for the following SSM VOC emission activities: 1) SSM T-0737, Emissions from roof landing 2) SSM Tanks Miscellaneous Recordkeeping: The annual SSM VOC emission rate shall be calculated as follows: 1) To demonstrate compliance during the first 12-months of monitoring the permittee shall calculate and sum the monthly cumulative total of VOC emissions; and 2) After the first 12-months of monitoring the permittee shall calculate and sum the total of VOC emissions on a monthly rolling 12-month basis, including the methodology and/or assumptions used in the calculation(s). The permittee shall keep records to demonstrate compliance in accordance with Condition B109C, except the requirement in B109.C(2) to EPA Inspection Report - Page 894 of 1969 record the start and end times of SSM events shall not apply to known quantities of VOC emissions. 3) The permittee shall maintain all records in accordance with Section B109. Reporting: The permittee shall report in accordance with Section B110. E. SSM and Malfunction Flaring Emissions (SSM Flare Cap and Flares Malfunction Cap) Requirement: The permittee shall not exceed the pound per hour (pph) and ton per year (tpy) emission limits in Table A107.A and shall demonstrate compliance with these limits by calculating and summarizing these emission rates as required in recordkeeping. Monitoring: A gas flowmeter and flow totalizer, equipped with a chart recorder or electronic data logger, shall be installed in the flare line to measure and record the total standard cubic feet (scf) of all gas (process gas, purge gas, pilot gas, and supplemental fuel gas) sent to the flare during each hour and each month. The permittee shall measure the H2S content, the total sulfur content, the VOC content, and the heating value (Btu/scf) of the gas sent to the flare for combustion during SSM and malfunction events. H2S shall be measured on each of the inlet gas types/streams using a stain tube of the appropriate size range or an inline H2S monitor. The flow meter and flow totalizer shall be operated, calibrated, and maintained as specified by the manufacturer and as necessary to ensure correct and accurate readings. If used, the inline monitor shall be operated, calibrated, and maintained as specified by the manufacturer and as necessary to ensure correct and accurate readings. Recordkeeping: The following records shall be kept: stain tube and/or inline H2S measurements annual gas analysis both the hourly and monthly volume (scf) of gas sent to the flare for SSM or malfunction events. Each event, the permittee shall record and summarize in a table format the following. H2S and the total sulfur content percent VOC content gas heating value (Btu/scf) the maximum hourly gas flow rate (scf/hr) that occurred each hourly gas flow rate (scf/hr) for any hour(s) that exceeded any pph emission limit the total scf of gas sent to the flare the monthly rolling 12-month total of gas sent to each flare (scf/yr) Each month, the permittee shall record all routine and predictable startups, shutdowns, and scheduled maintenance events and shall also meet the recordkeeping requirements in General Condition B109 of this permit, except the requirement to record the start and end times of SSM events shall not apply. Records of flowmeter, totalizer, and inline monitor certifications, calibrations, documentation of the manufacturer's recommended calibration / maintenance schedule, breakdowns, reasons for the EPA Inspection Report - Page 895 of 1969 breakdown, and corrective actions taken shall be maintained. Each month, to demonstrate compliance with both the SSM and malfunction emission limits, the permittee shall calculate and summarize the maximum pph emission rate, any pph emission rate exceeding the permitted limits, and the monthly rolling 12-month total ton per year emission rates of NOx, CO, VOC, SO2, and H2S for both SSM and malfunction events, using the following information: the H2S content, total sulfur content, VOC content, and the gas heating value (MMBtu/scf) from the most recent H2S measurements and gas analyses the emission factors used to calculate NOx and CO the maximum hourly gas flow rate (scf/hr) each hourly gas flow rate (scf/hr) for any hour(s) that exceeded any pph emission limit during the month, including the dates and times of these occurrences the monthly rolling 12-month total of gas sent to the flare (scf/yr) For each event, the permittee shall record whether the emissions are due to SSM and/or malfunction. If the emissions are due to malfunction, the permittee shall indicate whether the emissions resulting from the event are included in the amount allowed by this permit's malfunction limit or whether the event is reported under 20.2.7 NMAC. Reporting: The permittee shall report according to Condition B110. A108 Facility: Allowable Operations A. This facility is authorized for continuous operation. Monitoring, recordkeeping, and reporting are not required to demonstrate compliance with continuous hours of operation. A109 Facility: Reporting Schedules A. The permittee shall report according to the Specific Conditions and General Conditions of this permit. B. In addition to the reports required by the applicable NSPS, NESHAP and MACT Subparts (including any voluntary programs referencing NSPS, NESHAP, or MACT Subparts) and by the applicable parts of 20.2 NMAC, the following information shall be submitted to the Department. The reports shall be submitted to the Air Quality Bureau within forty five (45) days of the end of each calendar quarter. If any reports indicate potential non-compliance with the terms of this permit, the Bureau may impose a more frequent reporting time-frame. The Department shall handle any confidential information in accordance with the provisions of 20.2.1.115 NMAC. C. Reporting required by the Consent Decree (not an exhaustive listing) (1) The permittee shall notify the Department's Enforcement Section, Air Quality Bureau in writing of the annual progress of installation of NOx Control Technology required by Paragraph 16 of the Consent Decree. The report shall be submitted to the EPA and EPA Inspection Report - Page 896 of 1969 the NMED on or before December 31st of each calendar year commencing with the year 2002. (CD 16.E) (2) No later than forty-five (45) days following the end of an AG Flaring or TG Incident, the permittee shall submit to EPA and the NMED a report that sets forth the items detailed in the Consent Decree. (CD 20, CD21) A110 Facility: Fuel and Fuel Requirements A. Fuel, Fuel Sulfur, and NSPS J, Ja Sulfur Requirements (See Tables 103.E, H, I, & K, Summary of Applicable Requirements) Requirement: (1) To comply with NSPS Subpart J, NSPS Subpart Ja, and the PSD BACT requirements in A100.B(7), the permittee shall install, calibrate and maintain a continuous monitoring system (CMS) to continuously measure and record either the hydrogen sulfide (H2S) in the refinery fuel gas streams being burned in the Heaters and Boilers or the concentration of sulfur dioxide emissions to the atmosphere. (2) All stationary combustion equipment shall be fired with NSPS quality fuel gas with a maximum H2S content of 0.1 grains/dscf (approx. 162 ppmv), based on an hourly rolling 3-hour average. (3) All stationary combustion equipment shall not combust gas with an annual average sulfur content exceeding 0.037 grains/dscf (approx. 60 ppmv) as a daily rolling 365-day average. (4) All stationary combustion equipment shall be affected facilities, as defined in NSPS 40 CFR Part 60, Subparts A and J or Ja, if refinery-produced fuel gas is combusted in the heaters and boilers, and shall comply with all applicable requirements of NSPS Subparts A and J or Ja. (See Table 103.E, Summary of Applicable Requirements) Monitoring: (1) The permittee shall install, certify, calibrate, maintain and operate a fuel gas continuous monitoring system (CMS) at the fuel gas mix drum outlet in accordance with the requirements of 40 CFR 60.11, 60.13, and Part 60 Appendix A, and the applicable performance specification of 40 CFR Part 60 Appendices B and F. (2) The following CMS shall be certified initially and recertified annually: D-0019 Low Pressure Fuel Gas H2S CMS D-0770 High Pressure Fuel Gas H2S CMS (3) As required by the EPA-approvable alternative monitoring procedure (AMP), CCR off-gas streams that enter the refinery fuel gas system downstream of the H2S CMS shall be monitored quarterly for H2S using gas detector tubes or an equivalent method as follows: (a) CCR stabilizer off gas stream, (b) H2 recycle gas stream, and c) CCR feed stream. EPA Inspection Report - Page 897 of 1969 Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60, Subparts A, J, and Ja. (1) Records of the quantity of the refinery fuel gas and the monthly average heating value of the refinery fuel gas. This is used to demonstrate compliance with lb/mmBTU limits and lb/hr limits shown in Table 106.A. (permit limit) (2) Records of repairs, maintenance, and calibrations performed for the instruments that measure flow or concentration for an applicable permit limit shall be kept. Examples include, but are not limited to, CMS, acid gas flow meters, and fuel gas flow meters. (40 CFR 60, Appendix F) (3) Records shall be kept of Alternative Monitoring Plan (AMP) H2S analyses of the CCR offgas streams that enter the refinery fuel gas system downstream of the fuel gas H2S CMS. (NSPS J or Ja) Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subparts A, J, and Ja, and Section B110. A111 Facility: 20.2.36 NMAC - repealed 1/29/2016 A. Facility: 20.2.36 NMAC was repealed by EIB in Fall of 2015 and the effective date is 1/29/2016. A112 Facility: 20.2.37 NMAC A. 20.2.37 NMAC Requirement: If this regulation is repealed, then this regulation shall no longer apply as of the effective date of the repeal. (1) Section 200.A (Mercaptans) and section 200.B (Hydrogen Sulfide) apply to mercaptan and H2S emissions from the refinery. Section 200.C applies to FL-0400, FL-0401, FL-0402, FL-0403, and FL-0404, and requires an alarm in good working order to signal non-combustion of the gas. (2) Section 201.A (CO), applies to the refinery's FCC regenerator stack. The owner or operator of an existing petroleum processing facility shall not permit, cause, suffer or allow carbon monoxide emissions to the atmosphere from a catalyst cracking recirculation or regeneration unit in excess of 20,000 ppm by volume in the undiluted effluent gas stream or streams. (3) Section 202.C(1) (PM), The owner or operator of a new petroleum processing facility shall not permit, cause, suffer or allow particulate matter emissions to the atmosphere from the catalytic cracking regenerator vessel in excess of 1.0 Kg/1000 Kg (1.0 lb/1000 lb) of coke burnoff or visible emissions of thirty percent (30%) opacity or greater except for one six-minute average opacity reading in any one-hour period. (4) Section 203 (Ammonia, undiluted emissions 25 ppmv) applies to all emission points of the refinery. The owner or operator of a petroleum processing facility shall not permit, cause, suffer or allow ammonia emissions to the atmosphere in excess of 25 ppm by volume in the undiluted EPA Inspection Report - Page 898 of 1969 effluent gas stream or streams. (5) Section 204 (Hydrocarbon Separation Facility) applies to all oil/water separators at the refinery. Compliance with this condition is met by complying with the applicable NSPS Subpart QQQ requirements. (6) Section 205 (Facilities - Storage - Handling - Pumping - Blowdown System) applies to certain of the following: storage tanks for organic compounds, loading and unloading of organic compounds, seals on pumps and compressors, and disposal (flaring) of hydrocarbon gases. The permittee shall not permit, cause, suffer or allow the operation of a blowdown system without disposing of the gases in a manner which will minimize hydrocarbon emission to the atmosphere. If combustion is the means of disposal, it shall be by: smokeless flare; or any other method that is equally effective to achieve complete combustion. (20.2.37.205.E NMAC) Monitoring: (1) For Units FL-0400, FL-0401, FL-0402, FL-0403, and FL-0404: The permittee shall install and maintain a flare pilot flame monitoring system. (20.2.37.200.A.2 NMAC) (2) A CO CMS has been installed to monitor the emissions from the FCC. (3) The annual Stack test on Unit FCC (lb/hr PM emissions) and the calculated Coke burn rate will be used for the annual determination of pounds of PM per 1000 pounds of Coke burned. (4) None (5) No additional monitoring since compliance is met by complying with the applicable NSPS Subpart QQQ requirements. See other conditions of this permit for applicable NSPS or MACT requirements. (6) Compliance is demonstrated through NSPS K, NSPS Ka, NSPS Kb, or MACT CC for Tanks; through MACT CC for Loading Racks; through NSPS GGG, NSPS GGGa or MACT CC for Pumps and Compressors; and through NSPS Subpart A for Blowdowns. Recordkeeping: (1) Pilot flame monitoring records (2) CO CMS measurements (3) Copy of annual coke burn rate determination and stack test report (4) None (5) Applicable NSPS Subpart QQQ requirements (6) Applicable NSPS K, NSPS Ka, NSPS Kb, or MACT CC for Tanks; through MACT CC for Loading Racks; through NSPS GGG, NSPS GGGa or MACT CC for Pumps and Compressors; and through NSPS Subpart A for Blowdowns requirements Reporting: The permittee shall report in accordance with applicable NSPS or MACT requirements and Section B110. B. 20.2.61 NMAC Opacity Limit (Combustion Units) EPA Inspection Report - Page 899 of 1969 Requirement: Visible emissions from all stationary combustion emission stacks shall not equal or exceed an opacity of 20 percent in accordance with the requirements at 20.2.61.109 NMAC. This regulation does not apply as long as 20.3.37 NMAC is still in effect per 20.2.61.109 NMAC. If 20.2.37 NMAC is repealed, 20.2.61 NMAC will apply to these units within 120 days of the effective date of the 20.2.37 NMAC repeal. Monitoring: Use of natural gas fuel constitutes compliance with 20.2.61 NMAC unless opacity equals or exceeds 20% averaged over a 10-minute period. When any visible emissions are observed during operation other than during startup mode, opacity shall be measured over a 10minute period, in accordance with the procedures at 40 CFR 60, Appendix A, Reference Method 9 (EPA Method 9) as required by 20.2.61.114 NMAC, or the operator will be allowed to shut down the equipment to perform maintenance/repair to eliminate the visible emissions. Following completion of equipment maintenance/repair, the operator shall conduct visible emission observations following startup in accordance with the following procedures: Visible emissions observations shall be conducted over a 10-minute period during operation after completion of startup mode in accordance with the procedures at 40 CFR 60, Appendix A, Reference Method 22 (EPA Method 22). If no visible emissions are observed, no further action is required. If any visible emissions are observed during completion of the EPA Method 22 observation, subsequent opacity observations shall be conducted over a 10-minute period, in accordance with the procedures at EPA Method 9 as required by 20.2.61.114 NMAC. For the purposes of this condition, Startup mode is defined as the startup period that is described in the facility's startup plan. Recordkeeping: If no visible emissions were observed, none. If any visible emissions observations were conducted, the permittee shall keep records in accordance with the requirements of Section B109 and as follows: For any visible emissions observations conducted in accordance with EPA Method 22, record the information on the form referenced in EPA Method 22, Section 11.2. For any opacity observations conducted in accordance with the requirements of EPA Method 9, record the information on the form referenced in EPA Method 9, Sections 2.2 and 2.4. Reporting: The permittee shall report in accordance with Section B110. A113 Facility: 20.2.38 NMAC A. 20.2.38 NMAC Requirement: 20.2.38 NMAC (Hydrocarbon Storage Facilities, 11/30/95) applies to the refinery as follows: 1. Section 109 (Tank Storage Associated with Petroleum Production or Processing Facility [Sour Hydrocarbon Liquids]) applies to the loading of hydrocarbons containing H2S. 2. Section 110 (Tank Battery or Storage Facility - Within Municipality [Sour Hydrocarbon Liquids]) applies to certain tanks storing sour hydrocarbon liquids whose vapors contain >24 ppm EPA Inspection Report - Page 900 of 1969 H2S. 3. Section 113 (New Tank Battery and the Pecos-Permian Interstate Air Quality Control Region [Sour Hydrocarbon Liquids]) applies to certain tanks storing sour hydrocarbon liquids whose vapors contain >24 ppm H2S. Monitoring: 1. None 2. and 3. Demonstrated through NSPS K, Ka, Kb, and MACT CC floating roof seal inspection. Recordkeeping: 1. Records of Tank design showing inlet piping connections. 2. and 3. No additional requirements other than applicable requirements of NSPS and MACT. Reporting: The permittee shall report in accordance with Section B110. A114 Facility: Relocation Requirements - Not Required A115 Alternative Operating Scenario - Not Required A116 Compliance Plan - Not Required A117 Reducing Facility Emissions A. Upon the issuance of this permit, the following Units removed from this permit shall not be authorized to operate whether installed or never constructed: T-0013, T-0058, T-0404, T0405, T-0409, T-0810, and T-0078. A118 Facility: MACT Subpart UUU A. 40 CFR 63, Subpart UUU FCC, FUG-70-CCR, SRUs 1, 2, and 3 Requirement: The permittee shall comply with all applicable requirements of 40 CFR 63, Subpart UUU, National Emission Standards for Hazardous Air Pollutants for Petroleum Refineries: Catalytic Cracking Units, Catalytic Reforming Units, and Sulfur Recovery Units, for all affected sources shown in Tables 103H&I attached. (63.1560 and 63.1570). Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 63, Subpart UUU. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 63, Subpart UUU. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 63, Subpart UUU. EPA Inspection Report - Page 901 of 1969 A119 40 CFR 61 Subpart FF, National Emission Standard for Benzene Waste Operations A. 40 CFR 61 Subpart FF, National Emission Standard for Benzene Waste Operations (Units subject in Table 103.C & G) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 61, Subpart FF, National Emission Standard for Benzene Waste Operations for the affected sources in Tables 103.C, G. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 61, Subpart FF. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 61.356. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 61.357. EQUIPMENT SPECIFIC REQUIREMENTS OIL AND GAS INDUSTRY A200 Oil and Gas Industry A. This section has common equipment related to most Oil and Gas Operations. A201 Engines A. Maintenance and Repair Monitoring (Units G-0100, G-0101, V-0543, V-0545, V-0546, E8010, E-0600W, E-0601M, E-0602E, E-0603, and E-0901; Units G-0100, G-0101, V-0543, V-0545, V-0546, E-8010, E-0600W, E-0601M, E-0602E, E-0603, and E-0901) Requirement: These units are subject to Title V since they are subject to NSPS and/or MACT requirements. No emission limits were established since their emissions are small. The permittee shall ensure these units are properly maintained and repaired. Monitoring: Maintenance and repair shall meet the minimum manufacturer's or permittee's recommended maintenance schedule. Activities that involve maintenance, adjustment, replacement, or repair of functional components with the potential to affect the operation of an emission unit shall be documented as they occur for the following events: (1) Routine maintenance that takes a unit out of service for more than two hours during any twenty-four hour period. (2) Unscheduled repairs that require a unit to be taken out of service for more than two hours in any twenty-four hour period. EPA Inspection Report - Page 902 of 1969 Recordkeeping: The permittee shall maintain records in accordance with Section B109, including records of maintenance and repairs activities and a copy of the manufacturer's or permittee's recommended maintenance schedule. Reporting: The permittee shall report in accordance with Section B110. B. 40 CFR 63, Subpart ZZZZ (Units G-0100, G-0101, V-0543, V-0545, V-0546, E-8010, E0600W, E-0601M, E-0602E, E-0603, and E-0901) (Units subject in Table 103.J) Requirement: The units listed as subject in Table 103.J are subject to 40 CFR 63, Subpart ZZZZ and the permittee shall comply with all applicable requirements of Subpart A and Subpart ZZZZ. Monitoring: The permittee shall comply with all applicable monitoring requirements of 40 CFR 63, Subpart A and Subpart ZZZZ. Recordkeeping: The permittee shall comply with all applicable recordkeeping requirements of 40 CFR 63, Subpart A and Subpart ZZZZ, including but not limited to 63.6655 and 63.10. Reporting: The permittee shall comply with all applicable reporting requirements of 40 CFR 63, Subpart A and ZZZZ, including but not limited to 63.6645, 63.6650, 63.9, and 63.10. C. 40 CFR 60, Subpart IIII (Diesel Engines subject in Table 103.J) Requirement: The units listed as subject in Table 103.J are subject to 40 CFR 60, Subparts A and IIII and shall comply with the notification requirements in Subpart A and the specific requirements of Subpart IIII. Monitoring: The permittee shall comply with all applicable monitoring requirements in 40 CFR 60, Subpart A and Subpart IIII, including but not limited to 60.4211. Recordkeeping: The permittee shall comply with all applicable recordkeeping requirements in 40 CFR 60, Subpart A and Subpart IIII, including but not limited to 60.4214. Reporting: The permittee shall comply with all applicable reporting requirements in 40 CFR 60, Subpart A and Subpart IIII, including but not limited to 60.4214. A202 Glycol Dehydrators - Not Required A203 Tanks A. NSPS Subpart K, Standards of Performance for Storage Vessels for Petroleum Liquids for Which Construction, Reconstruction, or Modification Commenced After June 11, 1973, and Prior to May 19, 1978 (Tanks subject in Table 103.C) Requirement: The permittee shall comply with all applicable requirements of NSPS Subparts A & K for the affected sources in Table 103.C. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart K. EPA Inspection Report - Page 903 of 1969 Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60, Subpart K. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart K. B. NSPS Subpart Ka, Standards of Performance for Storage Vessels for Petroleum Liquids for Which Construction, Reconstruction, or Modification Commenced After May 18, 1978, and Prior to July 23, 1984 (Tanks subject in Table 103.C) Requirement: The permittee shall comply with all applicable requirements of NSPS Subpart Ka for the affected sources in Table 103.C. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart Ka. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60, Subpart Ka. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart Ka. C. NSPS Subpart Kb, "Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification Commenced After January 23, 1984" (Tanks subject in Table 103.C) Requirement: The permittee shall comply with all applicable requirements of NSPS Subpart Kb for the affected sources in Table 103.C. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart Kb. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60, Subpart Kb. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart Kb. D. MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" (Tanks subject in Table 103.C) Requirement: The permittee shall comply with all applicable requirements of MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" for all affected sources shown in Tables 103B, C, D, G attached. (63.640). Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 63, Subpart CC. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 63.655. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 63.655. EPA Inspection Report - Page 904 of 1969 E. Tank Throughput, Temperature, and VOC and H2S Limits (Units shown in Tables 106.B & C) Requirement: Compliance with the allowable throughput limits and emission limits in Table 106.D & E shall be demonstrated by not exceeding the monthly rolling 12-month total throughput to the unit(s) of gallons per year (barrels/year) shown in Table 106.D and not exceeding the allowable vapor pressure listed in Tables 106.B & C. Monitoring: The permittee shall monitor the monthly total throughput, maximum temperature once per month and the vapor pressure of each tank. Recordkeeping: The permittee shall record the monthly total throughput of liquids and the vapor pressure of each tank. Each month, during the first 12-months of monitoring, the permittee shall record the cumulative total liquid throughput and vapor pressure and after the first 12months of monitoring, the permittee shall calculate and record a monthly rolling 12-month total liquid throughput and the vapor pressure of each tank. The permittee has calculated the VOCs and H2S annually based on the 12-month total. Tank breathing and working emissions were calculated using the USEPA AP-42 Section 7.1 calculation methods. Emission rates computed using the same parameters, but with a different Department approved algorithm that exceed these values will not be deemed non-compliance with this permit. Records shall also be maintained in accordance with Section B109. Reporting: The permittee shall report in accordance with Section B110. A204 Heaters/Boilers A. Operational Inspection (All heaters/boilers in Tables 103.E & 104.A) Requirement: Compliance with the allowable emission limits in Table 106.A shall be demonstrated by performing periodic inspections to ensure proper operations. Monitoring: The permittee shall conduct annual operational inspections to determine that the heater(s)/boiler(s) are operating properly. The operational inspections shall include operational checks for indications of insufficient excess air, or too much excess combustion air. These operational checks shall include observation of common physical indications of improper combustion, including indications specified by the heater/boiler manufacturer, and indications based on operational experience with the/these unit(s). Recordkeeping: The permittee shall maintain records of operational inspections, describing the results of all operational inspections noting chronologically any adjustments needed to bring the heater(s)/boiler(s) into compliance. The permittee shall maintain records in accordance with Section B109. Reporting: The permittee shall report in accordance with Section B110. Within ninety (90) days of permit issuance, the permittee shall submit for Department approval EPA Inspection Report - Page 905 of 1969 a procedure which the permittee will use to carry out the operational inspections. The permittee may at any time submit revisions for Department approval. B. Periodic Emissions Tests (Units Heaters H-0019, H-0020, H-0362, H-0363, H-0364, H2421, H-3402, H-3403, and H-5401) Requirement: Compliance with allowable emission limits in Table 106.A shall be demonstrated by performing periodic emissions tests. Monitoring: The permittee shall conduct annual periodic portable analyzer emission tests or EPA Reference Method Tests for NOx and CO. Test results that demonstrate compliance with the CO emission limits shall also be considered to demonstrate compliance with the VOC emission limits. Section B108 General Monitoring Requirements apply to this condition. The permittee shall meet the testing requirements in Section B111. Recordkeeping: Records of periodic emission tests shall include the flow rate and the stack gas exhaust temperature. If a combustion analyzer is used to measure NOx, CO, and/or excess air in the flue gas, records shall be kept of the make and model of the instrument and instrument calibration data. If an ORSAT apparatus or other gas absorption analyzer is used, the permittee shall record all calibration results. Records shall be kept of all raw data used to determine flue gas flow and of all calculations used to determine flow rates and emission rates. The permittee shall maintain records in accordance with Section B109, B110, and B111. Reporting: The permittee shall summarize in tabular form the results of the initial or subsequent periodic emissions tests for NOx and CO, specifying the mass emissions rates in pounds per hour. The table shall include the average concentration of all relevant pollutant species. The permittee shall report in accordance with Section B109, B110, and B111. C. Summary of Compliance Methods for Heaters and Boilers for Table 106.A, 20.2.33 NMAC, 20.2.37 NMAC (Boilers and Heaters in Tables 103.E and 104.A) Requirement: (1) Demonstrate compliance with Table 106.A Allowable Emissions. (2) 20.2.33 NMAC (Gas Burning Equipment - Nitrogen Dioxide, 10/31/02) applies to existing and new gas burning equipment having a heat input of greater than 1,000,000 million British Thermal Units per year. It applies to process heaters identified in Tables 103.E and 104.A. These units shall be equipped with burners emitting less than 0.2 lb NOx per MM Btu. Compliance with 20.2.33 NMAC is demonstrated by compliance with the NOx lb per MM Btu limits in Table A106.A. (3) Compliance with the particulate emission limitation set forth in 20.2.37.202.A NMAC. If 20.2.37 NMAC is repealed by the NM Environmental Improvement Board, then this requirement is not effective after the repeal dated. EPA Inspection Report - Page 906 of 1969 Monitoring: (1) The permittee shall monitor the fuel usage of the all boilers and heaters. The fuel usage shall be monitored for specific heaters and boilers subject to 20.2.33 NMAC. (2) For specific heaters and boilers subject to 20.2.33 NMAC, the permittee shall collect and analyze samples of the refinery fuel gas at least once per week. The refinery fuel gas analysis shall include the composition of the refinery fuel gas, the gross heating value, and the net heating value. (3) See Condition A110.A for H2S monitoring requirements. (4) All process heaters and boilers shall fire only refinery gas in accordance with Application, Section 2, Table 2-J. (5) For those combustion sources required to have a continuous monitoring system (CMS) (listed in (a) below), the permittee shall install, certify, calibrate, maintain, and operate the CMS for each required pollutant in accordance with the applicable requirements of 40 CFR 60 or 63. The hourly average CMS data, the refinery fuel gas usage data, and the refinery fuel gas composition data shall be used to estimate the actual emission rates. The following CMS shall be recertified annually: Boiler B-0007 NOx and O2 CMS Boiler B-0008 NOx and O2 CMS Boiler B-0009 NOx and O2 and CO2 CMS H-9851 NOx O2 CMS H-2501 NOx O2 CMS (6) For those combustion sources required to conduct periodic stack exhaust testing as stated in Condition A204.B, the test reports shall be used to demonstrate compliance with the NOx, CO, and VOC limits in Table 106.A. (7) For those units and pollutants that are not required to have a CMS or a periodic stack test, (Units H-009, H-0011, H-0018, H-0028, H-0030, H-0040, H-0303, H-0312, H-0352, H-0353, H-0354, H-0355, H-0421, H-0464, H-0473, H-0600, H-0601, H-8801, H-8802, and H-3101) the permit application emission factor, the fuel usage, and the refinery fuel gas analysis shall be used to calculate the emission rates of NOx, CO, VOC, and PM. (8) If 20.2.37 NMAC is repealed by the NM Environmental Improvement Board, then this requirement is not effective after the repeal dated. Compliance with the particulate emission limitation set forth in 20.2.37.202.A NMAC shall be determined as specified in 20.2.37.202.D(3) NMAC. Combustion of only gaseous fuel has been approved by the Department as the compliance method under 20.2.37.202.D(3) NMAC. Recordkeeping: The permittee shall maintain the following records: (1) By March 31, the annual fuel usage for all boilers and heaters for the previous calendar year. (2) By March 31, the average fuel composition and heating value for all boilers and heaters for the previous calendar year. EPA Inspection Report - Page 907 of 1969 (3) For those units required to have a CMS (B-0007, B-0008, B-0009, H-9851 and H-2501), the CMS hourly average data. (4) For those units required to conduct periodic stack exhaust testing, the periodic test report. (5) For all boilers and heaters, a summary spreadsheet shall be maintained comparing the actual annual emissions with the allowable emission limits expressed in tons per year and lb/MMBtu using the appropriate method of compliance demonstration. This spreadsheet shall be updated by March 31 of each year for the previous calendar year. Reporting: The permittee shall report in accordance with Sections B110. D. Consent Decree NOx Emission Limits for Boilers B-0007 and B-0008 Requirement: (1) In accordance with the Consent Decree lodged December 20, 2001, NOx emissions from boilers B-0007 (no later than December 31, 2002) and B-0008 (no later than December 31, 2003) shall be less than 0.06 lb/MMBtu during any hourly rolling 3-hour period. Demonstration of compliance with the NOx limit for B-0007 and B-0008 shall be established by averaging the CMS Data over any 3-hour period and comparing the average concentration to the parametric limit of 42.1 ppm NOx, corrected to 6.1% O2 as determined by the CMS. (CD16.D) This also satisfies the requirement in 20.2.33.108.A NMAC that NOx emissions shall not exceed 0.2 lb/MMBTU. (2) Navajo is authorized to operate all three boilers (B-0007 and B-0008) simultaneously as needed. Monitoring: For the Controlled Boilers (B-0007, B-0008) as listed in the Consent Decree , continuous compliance with their respective NOx permit emissions limits shall be demonstrated by monitoring as follows: (CD16.C) (1) For boilers (B-0007 and B-0008) with a heat input capacity greater than 150 MMBTU/hr of HHV, the permittee shall install or continue to operate CMS to measure NOx and O2. Each CMS shall be installed, certified, calibrated, maintained, and operated in accordance with the requirements of 40 CFR 60.11, 60.13, and Part 60 Appendix A and the applicable performance specification test of 40 CFR Part 60 Appendices B and F. These CMS shall be used to demonstrate compliance with emission limits. The permittee shall make CMS and process data available to the applicable Federal and State Agencies upon demand as soon as practicable; (CD16.C.i) Recordkeeping: The permittee shall keep records of the CMS recertification's monitored in Condition A204.B, Summary of Compliance. Reporting: The permittee shall report in accordance with Section B110. E. NOx Monitoring and Testing for Controlled Heaters Subject to the Consent Decree (Units H-0020, H-0352, H-0353, H-0354, H-0600, and H-0601) EPA Inspection Report - Page 908 of 1969 Requirement: For the Controlled Heaters as listed in the Consent Decree, continuous compliance with all NOx emissions limits shall be demonstrated by monitoring as follows. (CD16.C) Monitoring: (1) For heaters with a heat input capacity of equal to or less than 150 MMBTU/hr (HHV) but greater than 100 MMBTU/hr (HHV), Navajo shall (a) install or continue to operate CMS to measure NOx and O2 by no later than the date of the installation of the applicable NOx Control Technology on the heater or boiler; or (b) submit for EPA approval, by no later than 60 days after the date of installation of the applicable NOx Control Technology on the heater or boiler, a proposal for monitoring based on operating parameters, including but not limited to, firebox temperature, air preheat temperature, heat input rate, and combustion O2. Navajo shall evaluate the necessity of using firebox or bridgewall temperatures and additional operating parameters and agrees to use such parameters as a means of monitoring performance where Navajo and EPA mutually-agree to their effectiveness. (CD16.C.ii). As of January 23, 2014 (notarized date of application), there are no heaters or boilers at the Artesia Refinery with a capacity of equal to or less than 150 MMBTU/hr (HHV) but greater than 100 MMBTU/hr (HHV) subject to Monitoring requirement (1). (2) For heaters with a heat input capacity of equal to or less than 100 MMBTU/hr of HHV, the permittee shall conduct an initial performance tests for NOx. The results of these tests shall be reported based upon an average of three (3) one-hour testing periods and shall be used to develop representative operating parameters for each unit, which will be used as indicators of compliance. (CD16.C.iii). This condition applies to the following heaters: Heaters H-0352, H-0353, and H-0354 Heater H-0020 Heaters H-0600 and H-0601 The permittee has completed all of the initial performance tests. (3) For heater H-0601 compliance shall be demonstrated by continuously monitoring stack oxygen (O2) to maintain a 3-hour average below 6.0 vol%. As a further check of compliance, Navajo shall monitor stack NOx at least twice a month using a portable analyzer to assure that the measured NOx value does not exceed the compliance threshold of 38 ppmv NOx. (CD16.C.iii) Recordkeeping: (1) The permittee shall keep records of the Fuel firing rates and Sulfur limits monitored for Condition A110.A. (2) The permittee shall keep records of the initial performance tests. (3) The permittee shall keep records of the stack oxygen monitoring and the portable analyzer tests. EPA Inspection Report - Page 909 of 1969 Reporting: The permittee shall report in accordance with Section B110. Condition B.111.D(7) does not apply to portable analyzer tests. F. NOx Monitoring and Testing for Heaters and Boilers permitted after the Consent Decree (Units Heaters H-0019, H-0362, H-0363, H-0364, H-2421, H-3402, H-2501, H-8801/8802, H-9851, and B-0009) Requirement: For the Heaters permitted after the Consent Decree, continuous compliance with their respective NOx permit emissions limits in Table 106.A shall be demonstrated by monitoring as follows. Monitoring: (1) For heaters with a heat input capacity greater than 150 MM Btu/hr (LHV Basis), the permittee shall install and operate CMS to measure NOx and O2 by the startup date of each heater or boiler. Each CMS shall be installed, certified, calibrated, maintained, and operated in accordance with the requirements of 40 CFR 60.11, 60.13, and Part 60 Appendix A and the applicable performance specifications of 40 CFR Part 60 Appendices B and F. These CMS shall be used to demonstrate compliance with emission limits. The permittee shall make CMS and process data available to the applicable Federal and State Agencies upon demand as soon as practicable. Condition A204.E(1) currently includes heater H-9851 and boiler B-0009. (2) For heaters with a heat input capacity of equal to or less than 150 MM Btu/hr (LHV) but greater than 100 MM Btu/hr (LHV), Navajo shall: (a) install and operate CMS to measure NOx and O2 by the startup date of each heater; or (b) submit to the Permit Program Manager for NMED approval, by no later than 90 days after the startup date of each heater, a proposal for monitoring based on operating parameters. Operating parameters to consider include, but are not limited to, firebox temperature, air pre-heat temperature, heat input rate, and combustion O2. Navajo agrees to use such parameters as a means of monitoring performance. Condition A204.F(2) applies to heaters H-2501 and H-8801/8802 (3) For heaters with a heat input capacity of equal to or less than 100 MM Btu/hr (LHV basis), the permittee shall conduct an initial performance test by no later than 180 days after the startup date. The results of this test shall be reported based upon an average of three (3) one-hour testing periods and shall be used to develop representative operating parameters for each unit, which will be used as indicators of compliance. This condition applies to the following heaters: Heaters H-0362, H-0363, H-0364, and H-2421 Heater H-0019 Heaters H-3402 (AMP approved by EPA, see (4)) , initial performance test completed on July 10, 2013 Heater H-3403, initial performance test completed on April 30, 2013 (4) US EPA has approved an Alternative Monitoring Plan (AMP) for Unit H-3402 for utilizing the oxygen monitor on the H-3402 Unit 34 Hydrocracker Reboiler 1 as a parametric means for EPA Inspection Report - Page 910 of 1969 demonstrating compliance with NSPS Ja, NOx monitoring via a CMS. In accordance with the AMP, the permittee shall accomplish the following: (a) Install flow indication on the fuel line to provide historical data of the fuel to the Mild Hydrocracker (Unit 34) by January 1st, 2015. (b) Monitor the process historical data of the HEP purchased natural gas pressure, and the high pressure fuel balance drum (D-0770). (c) Upgrade the existing the Mild Hydrocracker (Unit 34) Reboiler Heater (H-3402) oxygen monitor to perform daily calibrations as required in 40 CFR60.13(d)(1). (Note that the sample placement does not conform to CMS requirements for process reasons). (d) Conduct biennial performance tests according to the requirements in 40CFR 60.104a(i). (e) Establish a maximum or curve excess O2 operating limit - (MOPV) as required under 40 CFR60.107a(c)(6) utilizing the existing monitor. (f) Include Reboiler Heater (H-3402) hours of refinery fuel gas usage and any deviations during such time as required by 40 CFR 60.7 for periodic reporting. Recordkeeping: (1) The permittee shall keep records of the fuel firing rates and sulfur limits monitored for Condition A110.A. (2) The permittee shall keep records of the CMS recertification's monitored in Condition A204.B, Summary of Compliance. (3) The permittee shall keep records of the performance tests. (4) The permittee shall keep records of the implementation of the AMP and all required monitoring specified in the AMP. Reporting: The permittee shall report in accordance with Section B110. G. NSPS Subpart Db, Standards of Performance for Industrial-Commercial-Institutional Steam Generating Units (Boilers and heater subject in Table 103.E) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 60, Subparts A & Db (NOx-60.44b, SO2-60.42b, & PM-60.43b) for the affected sources in Table 103.E. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60.48b, Subpart Db. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60.49b, Subpart Db. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60.49b, Subpart Db. Compliance Test: The permittee shall comply with the methods and procedures stipulated in 40 CFR 60, Section 60.45b and 60.46b. EPA Inspection Report - Page 911 of 1969 H. NSPS Subpart Dc, Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units (Boilers and heater subject in Table 103.E) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 60, Subparts A & Dc (NOx-60.44c, SO2-60.42c, & PM-60.43c) for the affected sources in Table 103.E. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60.47c, Subpart Dc. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60.48c, Subpart Dc. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60.48c, Subpart Dc. Compliance Test: The permittee shall comply with the methods and procedures stipulated in 40 CFR 60, Section 60.44c and 60.45c. I. NSPS Subpart J, Standards of Performance for Petroleum Refineries (Boilers and heater subject in Table 103.E) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 60, Subparts A & J for the affected sources in Table 103.E. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart J. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60, Subpart J. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart J. J. NSPS Subpart Ja, Standards of Performance for Petroleum Refineries for which Construction, Reconstruction, or Modification Commenced After May 14, 2007 (Boilers and heater subject in Table 103.E) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 60, Subparts A & Ja for the affected sources in Table 103.E. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart Ja. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60, Subpart Ja. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart Ja. K. BACT NOx Limit, Continuous Monitoring System (CMS) (Unit B-0009) Requirement: The permittee shall comply with the allowable emission limits in Table 106.A and Condition A106.E that represent NOx BACT limits for the BACT requirements. EPA Inspection Report - Page 912 of 1969 Monitoring: (1) The Permittee shall comply with the CMS monitoring as detailed in Condition A204.D. (2) The permittee shall conduct an EPA Method test within six (6) months of startup using EPA reference test methods in 40 CFR 60 for NOx and O2 and CO2. Data from the CMS RATA testing may be used to satisfy this testing requirement. Recordkeeping: (1) The permittee shall keep records of the CMS initial calibration and recertification monitored in Condition A204.B, Summary of Compliance. (2) Records of EPA Methods tests shall be maintained for the Boiler. Reporting: (1) The permittee shall report in accordance with Section B110, to include the CMS initial calibration and recertification. (2) The permittee shall summarize in tabular form the results of the EPA Methods tests for NOx and O2 and CO2, specifying the emissions rates in pounds per hour and lb/MMBtu. The table shall include the average concentration of all relevant pollutant species. L. MACT Subpart DDDDD, Industrial, Commercial, and Institutional Boilers and Process Heaters (Boilers and heater subject in Table 103.E) Requirement: The units are subject to 40 CFR 63, Subpart DDDDD and the permittee shall comply with the applicable requirements of 40 CFR 63, Subpart A and Subpart DDDDD. Monitoring: The permittee shall comply with all applicable monitoring and testing requirements of 40 CFR 63, Subpart A and Subpart DDDDD. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 63, Subpart A and Subpart DDDDD. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 63, Subpart A and Subpart DDDDD. M. EPA Methods Test (Unit B-0009) Requirement: Compliance with CO BACT Limit and allowable emission limits in Table 106.A shall be demonstrated by emissions tests ensuring the unit is operating correctly and within desired parameters. Monitoring: The permittee shall conduct an EPA Method test no later than 180 days after startup using EPA reference test methods in 40 CFR 60. Emission testing is required for CO. Test results that demonstrate compliance with the CO emission limits shall also be considered to demonstrate compliance with the VOC emission limits. Recordkeeping: Records of EPA Methods tests shall be maintained for the Boiler. EPA Inspection Report - Page 913 of 1969 Reporting: The permittee shall report in accordance with the requirements of Section B111.D and summarize in tabular form the results of the EPA Methods test for CO, specifying the emissions rates in pounds per hour. The table shall include the average concentration of all relevant pollutant species. N. Verification of Energy Efficiency BACT Control Requirements (Unit B-0009) Requirement: The permittee shall comply with the allowable emission limits and the following BACT requirements. 1. Operation and Maintenance (BACT #6): a. Periodic Boiler Tuning - The boiler shall be tuned annually to maintain optimal thermal efficiency. b. Periodic Boiler Inspection and Repair for air leakage - The boiler shall be inspected annually to maintain optimal thermal efficiency. c. Periodic Boiler Inspection and Cleaning for tube fouling - The boiler shall be inspected annually and necessary cleaning performed to prevent tube fouling. 2. Next Generation Ultra-low-NOx high efficiency burners (NGULNB) (#5) shall be installed in the boiler design. 3. Flue gas economizer (BACT #2) - A heat exchanger shall be installed to recover heat from the exhaust gas to preheat incoming boiler feedwater to attain industry standard performance (IMO) for thermal efficiency. 4. Boiler insulation (BACT #4) - The boiler shall be designed and installed with boiler insulation to an optimum insulation thickness and material to achieve maximum energy efficiency. The OMP shall include the insulation design and maintenance schedule. 5. Oxygen Trim Control (BACT #7) - An Oxygen Trim Control system shall be designed and installed on the boiler to monitor oxygen concentration in the flue gas, and the inlet air flow is adjusted to maximize thermal efficiency. 6. Boiler blowdown minimization using manual analysis (BACT #3) - The Operation and Maintenance Plan (OMP) shall include methods and procedures to minimize blowdowns from the boiler to keep emissions at a minimum. 7. Condensate recovery (BACT #8): Condensate shall be recovered as represented in the application to achieve maximum energy efficiency. Condensate recovery shall be maximized through annual steam trap inspections and repairs. Monitoring: The Permittee shall develop an Operation and Maintenance Plan (OMP) to include at least the requirements listed above within 12-months of commencement of operations. The Permittee shall review the OMP annually to ensure it's effectiveness in meeting the requirements above and recommend changes. Recordkeeping: (1) Records demonstrating compliance with the energy efficiency requirement shall be recorded EPA Inspection Report - Page 914 of 1969 and summarized in the OMP. (2) The Permittee shall maintain a copy of the OMP onsite and available for inspection. Reporting: (1) The permittee shall notify the Department when the OMP has been prepared and available for review. (2) The permittee shall report in the semi-annual report a summary of actions covered in accordance with the OMP, and in accordance with Section B110. O. Periodic Emissions Tests (Unit B-009, CO BACT Limit) Requirement: Compliance with the CO BACT Limit and allowable emission limits in Table 106.A shall be demonstrated by performing periodic emissions tests. Monitoring: The permittee shall conduct periodic portable analyzer emission tests or EPA Reference Method Tests for CO at the intervals in the following schedule: First Test --- in accordance with the schedule in Section B111.A(2). Second Test --six (6) months after the first test is completed. All subsequent testing shall be done annually. Section B108 General Monitoring Requirements apply to this condition. The permittee shall meet the testing requirements in Section B111. Recordkeeping: Records of periodic emission tests shall include the boiler fuel flow rate and the stack gas exhaust temperature. If a combustion analyzer is used to measure CO, and/or excess air in the flue gas, records shall be kept of the make and model of the instrument and instrument calibration data. If an ORSAT apparatus or other gas absorption analyzer is used, the permittee shall record all calibration results. Records shall be kept of all raw data used to determine flue gas flow and of all calculations used to determine flow rates and emission rates. The permittee shall maintain records in accordance with Section B109, B110, and B111. Reporting: The permittee shall summarize in tabular form the results of the initial or subsequent periodic emissions tests for CO, specifying the mass emissions rates in pounds per hour. The table shall include the average concentration of all relevant pollutant species. The permittee shall report in accordance with Section B109, B110, and B111. A205 Turbines not required A206 Flares A. FL-0400, FL-0403 Requirement: (1) An alarm system in good working order shall be connected to Flare FL-0403 which will signal non-combustion of the gas. EPA Inspection Report - Page 915 of 1969 (2) The acid gas flow meter for flare FL-0400 or FL-0403 shall be operated and calibrated at a frequency and by the procedure specified by the manufacturer. A chart recorder or data logger (electronic storage) shall continuously record the amount of gas measured by the flow meter. Monitoring: (1) The fuel gas required to provide supplemental heat to either Flare FL-0400 or FL-0403 as required under A105.B shall be monitored during flaring by a flow meter. (2) The flow meter shall be operated continuously 24 hours per day, 365 days per year except for periods of flow meter maintenance or repair. (3) The flow meter and flow totalizer shall be operated, calibrated, and maintained as specified by the manufacturer and as necessary to ensure correct and accurate readings. If used, the inline monitor shall be operated, calibrated, and maintained as specified by the manufacturer and as necessary to ensure correct and accurate readings. The upper range of the flow meter shall be sufficient to record the highest expected flow rate of fuel gas sent to flare. (4) The reading of this flow meter and the flow meter to measure acid gas flow as required under Condition A105.B shall be used to determine compliance with emission limits at A106.C. Recordkeeping: (1) Records of all periods of operation during which the flare pilot flame is absent as included in the MACT subpart CC semi-annual reports. (2) Records of the quantity of supplemental fuel used during each acid gas flaring incident to provide supplemental heat to flare FL-0400 or flare FL-0403. (3) The permittee shall maintain records from the flow meter of the amount of gas sent to the flare. Reporting: The permittee shall report in accordance with Section B110. B. NSPS Subpart Ja (Flares listed in Table 103.K) Requirement: The permittee shall comply with all applicable requirements of NSPS Subpart Ja. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart Ja. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60, Subpart Ja. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart Ja. A207 Sulfur Recovery Plant (SRP), Tail Gas Incinerator (TGI) A. Consent Decree Requirements for SRP and TGI Requirement: In addition to the applicable requirements of NSPS, 40 CFR 60, Subparts J and Ja, the permittee shall accomplish the following: EPA Inspection Report - Page 916 of 1969 1. Navajo shall route all Sulfur Recovery Plant (SRP) sulfur pit emissions from the SRP so that sulfur pit emissions to the atmosphere either are eliminated or are included and monitored as part of the applicable Sulfur Recovery Plant's tail gas emissions that meet the NSPS Subpart J or Ja limit for SO2. (CD 18.C.ii) 2. The SRP and TGI (and any supplemental control devices) shall be operated and maintained, to the extent practicable, in accordance with the obligation to minimize SRP emissions through implementation of good air pollution control practices required by 40 CFR 60.11(d), at all times, including periods of start-up, shutdown, and malfunction. (CD 18.C.iii) Monitoring: The permittee shall comply with the applicable monitoring requirements of NSPS Subpart J or Ja. Recordkeeping: The permittee shall maintain records in accordance with the applicable requirements of NSPS Subparts J and Ja. Reporting: The permittee shall report in accordance with the applicable requirements of NSPS Subparts J and Ja. B. The following BACT SO2 work practices and equipment shall apply to the SRP (SRU3/TGTU3/TGI3): (1) Maintain at least 98% SRP on-stream operations. This includes curtailing refinery operations as necessary when SRU capacity is limited during planned startup, shutdown, and maintenance events. (2) Maintain adequate SRP excess capacity to reduce the frequency and quantity of refinery excess SO2 emissions. After the refinery expansion project proposed units are constructed, the proposed SRU3 will provide at least 25% excess capacity. (3) Continue to maintain and use a sulfur shedding plan to prevent or reduce acid gas flaring events from refinery upsets. An acid gas flaring event is defined as excess SO2 emissions greater than 500 pounds in a 24-hour period. The plan shall state specific actions that may be taken to reduce or prevent acid gas flaring. The actions taken during any event will be based on the refinery operators' discretion, considering safety and other factors related to prudent operation. This plan is subject to review by NMED or EPA, and shall be amended upon written request by NMED or EPA. The sulfur shedding plan may include, but is not limited to the following options: (a) Store sour water to reduce acid gas generation from the sour water strippers (b) Reduce the operating rate of one or more amine strippers to lower the acid gas generation rate (c) Reduce one or more hydrotreating unit throughput rates to lower acid gas generation rate (4) Use hydrogen, when available, as SRU fuel during startup and hot standby to minimize carbon deposits on the SRU catalysts. EPA Inspection Report - Page 917 of 1969 (5) During startup and shutdown and to the extent practicable, process vessels shall be depressurized into other process equipment rather than venting to a flare. The permittee shall document instances when this is not practicable. C. SRU1, SRU2, and SRU3 Requirement: The permittee shall demonstrate compliance with the H2S, SO2, lb/hr, tpy emission limits by completing the following requirements, monitoring, recordkeeping and reporting: (1) A flow meter shall be installed, operated, calibrated, and maintained on the sour water stripper streams that go to the SRUs. (2) An SO2 CEMS and flow meter shall be installed on the SRU1/SRU2 and SRU3 incinerator stacks. In addition, these units shall be equipped with instruments to measure and record sulfur concentration and flow rates of the gas streams into SRU1, SRU2, and SRU3. The CEMS, flow meters, and data loggers shall be calibrated and maintained. In addition, the calibration of the SO2 CEMS shall follow the quality assurance and quality control procedures in 40 CFR 60 Subpart J or Ja and Appendix F. (3) The minimum acceptable level of data capture for all instruments measuring flow of sulfur streams into the SRU1, SRU2, and SRU3, as well as the CEMS and flow meters on the incinerator stacks, shall be at least 90% for each semi-annual period. The 10% lost data will include all periods when the concentration and corresponding flow are not being measured as a result of calibrations or breakdowns. Monitoring: The gas stream feeding SRU1, SRU2, and SRU3 from the amine regeneration units and the sour water stripper shall be tested at least monthly for H2S concentration. The permittee shall monitor the following: (1) Flow rate of sour water stream to SRUs, (2) SO2 concentration in SRU incinerator stacks and (3) Flow rate of the SRU incinerator stacks. Recordkeeping: The permittee shall maintain records in accordance with the applicable requirements of NSPS Subparts J or Ja and MACT Subpart UUU. The permittee shall also keep records of the following: (1) Flow rate of sour water stream to SRUs, (2) SO2 concentration in SRU incinerator stacks and (3) Flow rate of the SRU incinerator stacks. Reporting: The permittee shall report in accordance with the applicable requirements of NSPS Subparts J or Ja, MACT Subpart UUU, and Section B110. D. 40 CFR 60, Subpart J (Unit(s) SRU1 and SRU2) Requirement: The permittee shall comply with the applicable requirements of 40 CFR 60, Subpart J. Monitoring: The permittee shall install a continuous monitoring device to monitor compliance with the H2S limit. (40 CFR 60.105(a)(3-4)) EPA Inspection Report - Page 918 of 1969 Recordkeeping: The permittee shall maintain the continuous emission records. Reporting: The permittee shall comply with the reporting requirements of 40 CFR 60, Subpart J. E. 40 CFR 60, Subpart Ja (Unit SRU3) Requirement: The permittee shall comply with the applicable requirements of 40 CFR 60, Subpart Ja. Monitoring: The permittee shall install a continuous monitoring device to monitor compliance with the H2S limit. (40 CFR 60.105a(a)(3-4)) Recordkeeping: The permittee shall maintain the continuous emission records. Reporting: The permittee shall comply with the reporting requirements of 40 CFR 60, Subpart Ja. A208 Amine Unit - Not Required A209 Fugitives A. NSPS Subpart GGGa, Standards of Performance for Equipment Leaks of VOC in Petroleum Refineries for which Construction, Reconstruction, or Modification Commenced After November 7, 2006 (Fugitives subject in Table 103.B) Requirement: The permittee shall comply with all applicable requirements of NSPS Subpart GGGa for all sources in Table 103.B (affected units and voluntarily units). This table also includes areas that are voluntarily following the NSPS Subpart GGGa monitoring requirements. Monitoring: The permittee shall comply with all applicable monitoring requirements of 40 CFR 60, Subpart GGGa. Recordkeeping: The permittee shall comply with all applicable recordkeeping requirements of 40 CFR 60, Subpart GGGa. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60, Subpart GGGa. B. NSPS Subpart QQQ, Standards of Performance for VOC Emissions from Petroleum Refinery Wastewater Systems (Fugitives subject in Table 103.B) Requirement The permittee shall comply with all applicable requirements of NSPS, 40 CFR Part 60.690, Subpart QQQ. Per the Consent Decree CIV-01 1422LH Lodged 12/20/2001, Entered 3/5/2002, the permittee agreed that this regulation would apply to the entire facility not just those source applicable due to construction dates. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart QQQ. (60.695) Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60.696. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR EPA Inspection Report - Page 919 of 1969 60.697. C. Minor changes within the facility to piping and components that affect fugitive VOC emission source shall be updated and added during the next available Significant permit revision in accordance with 20.2.72 NMAC. The facility wide fugitive VOC emission limit shown above and in Table 106.A of this permit. A210 Loading Racks A. Truck and Rail Loading (Unit shown in Table 106.G) Requirement: Compliance with the allowable emission limits in Table 106.G shall be demonstrated by not exceeding the monthly rolling 12-month total throughput for each loading rack for each different product in barrels/year. Monitoring: The permittee shall monitor the throughput volumes on a monthly basis. Recordkeeping: The permittee shall record the monthly throughput volume for each loading rack for each different product. Each month during the first 12-months of monitoring the permittee shall record the cumulative condensate loadout volume and after the first 12-months of monitoring, the permittee shall calculate and record a monthly rolling 12-month total loadout volume. Records shall also be maintained in accordance with Section B109. Reporting: The permittee shall report in accordance with Section B110. B. Fuel Truck Loading Rack (Units subject in Table 103.D) (40 CFR 63, Subpart CC) Requirement: The permittee shall comply with all applicable requirements of MACT Subpart CC, National Emission Standards for Hazardous Air Pollutants From Petroleum Refineries. Specially, the truck loading rack shall be equipped with a carbon adsorption system for compliance with the MACT requirements. Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 63, Subpart CC. Specifically 63.427(a)(2), where a carbon adsorption system is used, a continuous emission monitoring system (CEMS) capable of measuring organic compound concentration shall be installed in the exhaust air stream. Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 63, Subpart CC. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 63, Subpart CC. A211 Fluid Catalytic Cracking Unit (FCC) A. Continuous Monitor System (CMS) (Unit FCC REGEN) Requirement: (1) Consent Decree Limits on PM and SO2 emissions from the FCC: By no later than December EPA Inspection Report - Page 920 of 1969 31, 2003, the Wet Gas Scrubber (WGS) on the FCC Regenerator shall comply with the following limits: (CD 12.B & 13.B) (a) SO2 concentration not to exceed 25 ppmvd on a daily rolling 365-day average basis and 50 ppmvd on a daily rolling 7-day average basis, each corrected to 0% oxygen. Compliance with this emissions limit shall be demonstrated on an ongoing basis through the use of CMS; and (b) A particulate matter (PM) emission limit of 1.0 pound of PM per 1000 pounds of coke burned on a 3-hour average basis (CD 13.B). To demonstrate compliance with this requirement, the Permittee shall conduct an annual EPA Method 5 Test for PM and weekly EPA Method 9, Opacity Test in accordance with their approved Alternative Monitoring Plan (AMP). (c) As the FCC Regenerator is subject to the provisions of 40 CFR 60.102 (NSPS Subpart J), it shall not discharge to the atmosphere gases exhibiting greater than 30 percent opacity, except for one six-minute average opacity reading in any one-hour period. (2) Consent Decree Limits on NOx and CO emissions from the FCC: The FCC shall comply with NOx and CO emission limits as follows: (a) The concentration-based (ppmvd) NOx emission limit based on daily rolling 7-day and daily rolling 365-day averages, corrected to 0% oxygen as established pursuant to the Consent Decree, unless EPA rejects the proposed limit and establishes a different NOx emission limit, in which case the FCC shall comply with EPA's established limit. Under no circumstances shall this emission limit be greater than a concentration-based limit that would be equivalent to 34.9 lbs/hr. The 7-day FCC NOx emission limits, shall not apply during periods of Hydrotreater Outage provided that the FCC (including associated air pollution control equipment) is maintained and operated in a manner that minimizes emissions in accordance with an EPA-approved good air pollution control practices plan. Navajo shall comply with the plan at all times, including periods of startup, shutdown, and malfunction of the hydrotreater. The daily rolling 365-day average NOx emissions limit shall apply during periods of hydrotreater outages. The NOx limits are: (1) 87.3 ppmvd NOx, corrected to 0% O2 on a daily rolling 7-day average, and (2) 58.1 ppmvd NOx, corrected to 0% O2 on a daily rolling 365-day average (b) The NSPS Subpart J emission limit of 500 ppmvd CO corrected to 0% O2 on a 1-hour average basis and 100 ppmvd CO corrected to 0% O2 on a daily rolling 365-day average basis, by no later than December 31, 2003. Monitoring: (1) A continuous monitor system (CMS) for CO, O2, SO2 and NOx shall be installed, calibrated, maintained, and operated on the FCC Catalyst Regenerator vent stack(s) downstream of the scrubber in accordance with 40 CFR Part 60, 60.13, Appendix A, and the applicable performance specifications of Appendices B (Specifications 2 and 3) and F. The CMS shall be used to demonstrate compliance with CO, SO2 and NOx emissions limits and to report compliance with the terms and conditions of the Consent Decree. The CMS and process data shall be made available, by permittee, to applicable Federal and State EPA Inspection Report - Page 921 of 1969 Agencies (NMED) upon demand as soon as practicable. (CD 11.F, 12 D, and 14.C) (2) The FCC Regenerator Scrubber NOx, SO2, CO and O2 CMS shall be recertified annually. (3) The CMS data shall be monitored to ensure the CO, SO2 and NOx emission limits for the FCC are met. (4) The Permittee shall conduct an annual EPA Method 5 Test for PM and weekly EPA Method 9 Opacity test to demonstrate compliance with the particulate matter (PM) emission limit of 1.0 pound of PM per 1000 pounds of coke burned on a 3-hour average basis and opacity limit of 30%. Permittee shall meet testing requirements of B111. Recordkeeping: The permittee shall maintain the records of: (1) The certification and re-certification of the CMS. (2) Modifications to the FCC's good air pollution control practice plan to minimize NOx emissions shall be summarized on an annual basis if any changes were made. ( CD 11.G) (3) The permittee shall keep records of CMS data monitoring NO2, SO2, PM10 and CO emissions from the FCC. (CD 11.F, CD 12.D & CD 14.C) (4) Records of NOx, CO, SO2 ppmvd, lb/hr, tpy; PM lb/hr, tpy and opacity. TPY shall be based on a monthly rolling 12-month total. (5) The permittee shall keep records of annual PM stack tests and weekly Method 9 observations conducted on the FCC. For any opacity observations conducted in accordance with the requirements of EPA Method 9, record the information on the form referenced in EPA Method 9, Sections 2.2 and 2.4. Reporting: The permittee shall report in accordance with Section B110 and testing requirements of B111. B. Performance Testing (Unit FCC REGEN) Requirements: (1) The permittee shall demonstrate compliance with the NSPS Subpart J particulate matter emission limit at Table 106.A by conducting an initial performance test in accordance with NSPS Subpart A, 60.8 and NSPS Subpart J, 60.106(b). The particulate matter stack test shall be repeated on an annual basis. (2) The permittee shall comply with all applicable performance testing requirements in accordance with MACT Subparts A and UUU. Monitoring: Testing shall be conducted in accordance with NSPS Subparts A and J, and in accordance with MACT Subparts A and UUU. Recordkeeping: The permittee shall maintain performance test records in accordance with NSPS Subparts A and J, MACT Subparts A and UUU, and in accordance with Section B109. Reporting: The permittee shall report performance test results in accordance with NSPS Subparts A and J, MACT Subparts A and UUU, and in accordance with Section B110. EPA Inspection Report - Page 922 of 1969 A212 Cooling Towers A. MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" (Cooling Towers subject in Table 103.F) Requirement: The permittee shall comply with all applicable requirements of 40 CFR 63, Subpart CC for heat exchange systems for all affected sources shown in Table 103.F attached. (63.654(a), 63.640(h)(6)) Monitoring: The permittee shall comply with all applicable monitoring and testing requirements of 40 CFR 63, Subpart CC. (63.654(c), (d), (e), (f)) Recordkeeping: The permittee shall comply with all applicable recordkeeping requirements of 40 CFR 63, Subpart CC. (63.654(g), 63.655(i)(4), (i)(5)) Reporting: The permittee shall comply with all applicable reporting requirements of 40 CFR 63, Subpart CC. (63.655(f), (f)(1)(vi), (g)(9), (h)(1), (7)) B. Cooling Tower Operations (Cooling Towers subject in Table 103.F) Requirement: Compliance with the allowable emission limits in Table 106.H shall be demonstrated by meeting the following requirements: 1) operate a maximum of six (6) recirculating pumps at any one time; 2) ensure that each pump capacity shown in Table 104.A are not exceeded gallons per minute for each cooling tower (65,500 gpm total maximum rate for 6 pumps); 3) limit the Total Dissolved Solids (TDS) content for the cooling tower recirculating water system to 3500 ppmw, based on a monthly rolling 12-month annual average; 4) ensure that the drift eliminator are rated by the manufacturer at 0.001% or 0.003 drift or less as shown in Table 104.A; and 5) ensure that the drift eliminator is present and in good working order. The permittee shall measure the Total Dissolved Solids (TDS) content of the recirculating water through direct laboratory analysis, or may use a conductivity meter on the recirculating water system for the cooling tower. The correlation between conductivity of the water and the TDS content shall be taken as 0.9 * conductivity (mhos/cm) = TDS (ppmw) unless a new correlation is determined through laboratory analysis and submitted to the Permit Program Manager for approval. Monitoring: The permittee shall: 1) Monitor the recirculating water TDS content by direct laboratory analysis of the TDS or through use of conductivity meter values and correlated TDS on a monthly basis; and a. Any correlation other than the 0.9 value described above shall be developed by the permittee by independent laboratory measurement of at least 10 water samples with approximately evenly spaced measured TDS values that bracket the minimum and maximum values expected. The highest laboratory TDS sample used for the correlation shall be greater than the maximum allowable TDS of 3500 ppmw. 2) Perform an annual inspection of the drift eliminator and perform any maintenance EPA Inspection Report - Page 923 of 1969 necessary to ensure the device operates according to the manufacturer's specifications. 3) The permittee shall monitor the cooling water inlet and outlet streams for hydrocarbons on an annual basis using either EPA Method 8015 with a large enough sample to achieve accurate quantification of hydrocarbon content, EPA Method 8260, EPA Method 8270 or a similar method as approved by the Department prior to testing. Recordkeeping: The permittee shall maintain the following records: 1) Manufacturer's specifications demonstrating maximum capacities of the recirculating water pumps and the manufacturer's specification for the drift eliminator specified drift rate; 2) Monthly TDS and monthly rolling 12-month average; 3) If a conductivity meter is installed, a record of the correlation between conductivity and TDS, any laboratory analyses used to determine the correlation, and all related calculations; 4) Annual drift eliminator inspection and any records of maintenance performed. The permittee shall maintain records in accordance with Section B109. Reporting: The permittee shall report in accordance with Section B110. A213 Wastewater Systems A. NSPS Subpart QQQ, Standards of Performance for VOC Emissions from Petroleum Refinery Wastewater Systems Requirement: Beginning December 31, 2003, all remaining and newly installed individual drain systems, oil-water separators, and aggregate facilities not previously specified shall be affected facilities, as the term is used in the NSPS, 40 CFR Part 60, Subpart QQQ, and shall be subject to and comply with the applicable requirements of 40 CFR Part 60, Subpart QQQ. (CD 29) The permittee shall comply with all applicable requirements of NSPS Subpart QQQ for the affected sources in Tables 103.B, C, G. (60.690) Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 60, Subpart QQQ. (60.695 and 60.696) Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 60.697. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 60.698. B. MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" Requirement: The permittee shall comply with all applicable requirements of MACT Subpart CC, "National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries" for all affected sources shown in Tables 103.B, C, G attached. (63.640). Monitoring: The permittee shall comply with the applicable monitoring and testing requirements of 40 CFR 63, Subpart CC. EPA Inspection Report - Page 924 of 1969 Recordkeeping: The permittee shall comply with the applicable recordkeeping requirements of 40 CFR 63.655. Reporting: The permittee shall comply with the applicable reporting requirements of 40 CFR 63.655. C. Wastewater Treatment System (Units shown in Table 106.I) Requirement: Compliance with the emission limits in Table 106.I shall be demonstrated by properly maintaining and repairing the units, and running the Wastewater Model annually to calculate the maximum VOC emissions generated. Monitoring: (1) Maintenance and repair shall meet the minimum manufacturer's or permittee's recommended maintenance schedule. Activities that involve maintenance, adjustment, replacement, or repair of functional components with the potential to affect the operation of an emission unit shall be documented as they occur for the following events: (a) Routine maintenance that takes a unit out of service for more than two hours during any twenty-four hour period. (b) Unscheduled repairs that require a unit to be taken out of service for more than two hours in any twenty-four hour period. (2) The permittee shall annually run the Waste-Water Model to determine the hourly and annual emission rates, based on EPA's WATER9, the wastewater treatment model. Recordkeeping: (1) The permittee shall maintain records in accordance with Section B109, including records of maintenance and repairs activities and a copy of the manufacturer's or permittee's recommended maintenance schedule. (2) The permittee shall maintain records of the EPA's WATER9, the wastewater treatment model Input Parameters and the emission calculation results compared to permit limits. Reporting: The permittee shall report in accordance with Section B110. PART B GENERAL CONDITIONS (Attached) PART C MISCELLANEOUS: Supporting On-Line Documents; Definitions; Acronyms (Attached) PART D ATTACHMENTS EPA Inspection Report - Page 925 of 1969 Title V Permit Unit ID FUG-02-SP CRUDE FUG-05-KERO FUG-06-NHDU FUG-07-N AMINE FUG-07-SWS1 FUG-08-TRUCK RK FUG-09-N ALKY FUG-10-FCC FUG-13-NHDU FUG-18-LSR MEROX TRT FUG-20-ISOM FUG-21-SP VACUUM FUG-25-ROSE-2 FUG-29-BLENDER/TK FARM FUG-31SRU3/TGTU3/TGI3 FUG-33-DIST HDU FUG-34HYDROCRACKER FUG-35-SAT GAS FUG-41-PBC FUG-43-S ALKY FUG-44-DIST-HDU FUG-45-DIST-HDU FUG-54-PRIMEG Table 103.B, Summary Applicability - Fugitives [return] Description South Division Crude Unit Kerosene HDS Unit Naphtha HDS Unit 06 Amine Unit-Treating/Regen. Sour Water Stripper Loading Racks North Alkylation Unit (New-Inside battery limits) FCC w/CVS Naphtha HDS Unit 13 Merox/Merichem Treating Units BenFree Unit Flasher/Vacuum Unit ROSE Unit Light Oil Tankage 20.2.37 YES NO NO YES YES NO YES YES YES NO NO NO YES NO MACT CC NO NO NO NO NO NO NO NO NO NO NO NO NO NO NSPS GGG NO NO NO NO NO NO NO NO NO NO NO NO NO NO NSPS GGGa YES YES YES YES YES YES YES YES YES YES YES YES YES YES SRU3 Unit Relocated Diesel HDS Unit w/CVS WX Hydrocracker Saturates Gas Plant PBC Unit South Alky Unit (W-76) Gas Oil Hydrotreater (incl. CVS) Gas Oil Hydrotreater (incl. CVS) Prime G Unit YES NO YES NO YES NO NO NO NO NO YES NO NO NO NO NO YES NO NO YES NO YES NO YES NO YES NO YES NO YES NO YES NO YES NO YES NSPS QQQa YES YES YES YES YES YES YES YES YES YES YES YES YES YES NESHAP Jb NO NO NO NO NO NO NO NO NO NO NO NO NO NO NESHAP Vc NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES NO NO YES NO NO YES NO NO YES NO NO YES NO NO YES NO NO YES NO NO YES NO NO YES NO NO EPA Inspection Report - Page 926 of 1969 Title V Permit Unit ID Description FUG-63-H2 PLANT-1 Hydrogen Plant FUG-64-H2 PLANT-2 Hydrogen Plant FUG-70-CCR CCR Reformer (w/in battery limits) FUG-73-SP UTIL Utilities FUG-80-WWTP CVS Oil/Water Separator FUG-ASPHALT STG Asphalt/Heavy Oil Storage FUG-FUEL GAS Fuel Gas Distribution System FUG-LPG LPG Storage System FUG-RLO-ASPHALT Asphalt/Pitch Loading Rack FUGSRU1/SRU2/TGTU SRU1/SRU2/SWS w/CVS FUG-RRTOTRUCK Crude oil unloading system, closed loop system between railcars and trucks. a. All wastewater sources subject to NSPS QQQ per consent decree Section 29B. b. No refinery streams contain benzene at concentrations of 10 wt% or greater. c. NESHAP V is only applicable if subject to NESHAP J. 20.2.37 NO NO YES NO YES NO NO NO NO YES NO MACT CC NO NO NO NO NO NO YES NO NO NO NO NSPS GGG NO NO NO NO NO NO NO NO NO NO NO NSPS GGGa NO NO YES NO YES NO YES YES NO YES NSPS QQQa YES YES YES YES YES YES YES YES YES YES NESHAP Jb NO NO NO NO NO NO NO NO NO NO NESHAP Vc NO NO NO NO NO NO NO NO NO NO NO YES NO NO EPA Inspection Report - Page 927 of 1969 Tank No. RW-4 RW-5 RW-6 T-0001 T-0002 T-0003 T-0004 T-0011 T-0012 T-0026 T-0028 T-0031 T-0040 T-0041 T-0042 T-0045 T-0046 T-0049 T-0055 T-0056 T-0057 T-0059 T-0061 T-0063 T-0064 T-0065 T-0071 T-0072 T-0073 T-0074 T-0075 T-0076 T-0079 T-0081 T-0082 T-0106 T-0107 T-0108 T-0109 NSPS K NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NSPS Ka NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NSPS Kb NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES NO NO NO NO YES NO YES YES YES NO NO NO NO Table 103.C, Summary Applicability - Tanks MACT CC Storage NO NO NO NO NO NO NO YES YES NO NO NO YES YES NO NO NO YES YES YES YES YES YES YES NO YES NO NO NO NO YES NO YES YES YES YES YES YES YES MACT CC Wastewater N/A N/A N/A YES YES YES YES N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A NESHAP FF N/A N/A N/A YES YES YES NO N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A YES N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A NSPS QQQ N/A N/A N/A NO NO NO NO N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A YES N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 20.2.37.205 NMAC NO NO NO NO NO NO NO YES YES NO NO NO NO NO YES YES YES NO YES YES YES NO NO NO NO YES YES YES YES YES YES YES YES YES YES YES YES YES YES 20.2.38.109 NMAC NO NO NO NO NO NO NO YES YES NO NO NO NO NO YES NO NO NO NO YES YES NO NO NO NO NO NO NO NO NO NO NO YES NO NO YES YES YES YES 20.2.38.110 NMAC YES YES YES NO NO NO NO YES YES NO NO NO NO NO YES NO NO NO NO YES YES NO NO NO NO NO NO NO NO NO NO NO YES NO NO YES YES YES YES 20.2.38.112 NMAC NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES YES YES NO YES NO YES NO NO NO NO YES YES YES YES YES YES YES YES YES YES NO NO NO NO 20.2.38.113 NMAC YES NO YES NO NO NO NO NO NO NO NO NO NO NO YES NO NO NO NO NO YES NO NO NO NO NO NO NO NO NO NO NO YES NO NO NO NO NO NO CAM NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO EPA Inspection Report - Page 928 of 1969 Tank No. T-0110 T-0111 T-0112 T-0114 T-0115 T-0116 T-0117 T-0119 T-0124 T-0400 T-0401 T-0402 T-0410 T-0411 T-0412 T-0413 T-0415 T-0417 T-0418 T-0419 T-0420 T-0422 T-0423 T-0431 T-0432 T-0433 T-0434 T-0435 T-0437 T-0438 T-0439 T-0446 T-0447 T-0448 T-0449 T-0450 T-0451 T-0452 T-0453 T-0460 NSPS K NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES NO NO NO NO NO NO NO NO NO NO NO NSPS Ka NO NO NO NO NO NO NO NO YES NO YES YES NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES NO NO NO NO NO NO NO NO NO NSPS Kb NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES NO NO NO NO NO NO NO YES NO YES NO NO MACT CC Storage YES YES YES NO NO NO YES NO YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES NO NO NO NO YES YES NO NO NO MACT CC Wastewater N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A NESHAP FF N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A NSPS QQQ N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 20.2.37.205 NMAC NO YES YES YES YES YES YES YES YES YES YES YES NO YES YES YES YES YES NO NO NO NO NO NO NO NO YES YES YES YES YES NO NO NO NO YES YES YES NO NO 20.2.38.109 NMAC NO YES YES NO NO NO YES NO YES NO YES YES NO YES YES YES YES YES NO NO NO NO NO NO NO NO NO YES YES NO YES NO NO NO NO YES NO NO NO NO 20.2.38.110 NMAC NO YES YES NO NO NO YES NO YES NO YES YES NO YES YES YES YES YES NO NO NO NO NO NO NO NO NO YES YES NO YES NO NO NO NO YES NO NO NO NO 20.2.38.112 NMAC NO NO NO YES YES YES NO YES YES YES YES YES NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES YES YES YES YES NO NO NO NO YES NO NO NO NO 20.2.38.113 NMAC NO NO NO NO NO NO NO NO YES NO YES YES NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES YES NO YES NO NO NO NO YES NO NO NO NO CAM NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO EPA Inspection Report - Page 929 of 1969 Tank No. T-0465 T-0466 T-0467 T-0468 T-0600 T-0737 T-0802 T-0803 T-0804 T-0807 T-0809 T-0814 T-0815 T-0816 T-0830 T-0834 T-0835 T-0838 T-0839 T-0840 T-0841 T-0891 T-0892 T-1221 T-1222 T-1223 T-1224 T-1225 T-1227 T-5401 T-0829 NSPS K NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NSPS Ka NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NSPS Kb NO NO NO NO NO YES YES NO NO NO NO YES YES NO YES NO NO NO NO NO NO NO NO NO NO NO NO YES YES YES NO MACT CC Storage NO NO NO NO NO YES YES NO NO NO NO YES YES NO NO YES YES YES NO NO NO NO NO NO NO NO NO YES YES YES NO MACT CC Wastewater N/A N/A N/A N/A N/A N/A N/A YES YES N/A YES N/A N/A N/A YES N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A YES N/A N/A N/A YES NESHAP FF N/A N/A N/A N/A N/A N/A N/A YES YES N/A YES N/A N/A N/A YES N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A YES N/A N/A N/A YES NSPS QQQ N/A N/A N/A N/A N/A N/A N/A NO NO N/A NO N/A N/A N/A YES N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A NO N/A N/A N/A NO 20.2.37.205 NMAC NO NO NO NO NO YES YES NO NO NO NO YES YES YES YES NO YES YES NO NO NO NO NO NO NO NO NO YES YES YES NO 20.2.38.109 NMAC NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES NO NO NO NO NO NO NO NO NO NO YES NO YES NO 20.2.38.110 NMAC NO NO NO NO NO YES YES NO NO NO NO NO NO NO NO NO YES NO NO NO NO NO NO NO NO NO NO YES NO YES NO 20.2.38.112 NMAC NO NO NO NO NO YES YES NO NO NO NO YES YES NO YES NO NO NO NO NO NO NO NO NO NO NO NO YES YES YES NO 20.2.38.113 NMAC NO NO NO NO NO YES YES NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES NO YES NO CAM NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO EPA Inspection Report - Page 930 of 1969 Unit ID TLO-1 TL-2 TL-4 TL-7 RLO-8 RLO-19 TLO-20 Table 103.D, Summary Applicability - Loading Description Asphalt Truck Loading and OffLoading Rack #1 Asphalt Truck Loading Rack #2 Fuels Truck Loading Rack CBO/LCO Truck Loading Rack Railcar Loading & Off-Loading Rack Railcar Loading & Off-Loading Rack Asphalt/Pitch Truck Loading Rack MACT CC NO NO YES NO NO NO NO 20.2.37.205.C NO NO NO NO NO NO NO MACT BBBBBB NO NO NO NO NO NO NO MACT CCCCCC NO NO NO NO NO NO NO CAM NO NO NO NO NO NO NO EPA Inspection Report - Page 931 of 1969 Unit ID B-0007 B-0008 B-0009 H-0009 H-0011 H-0018 H-0019 H-0020 H-0028 H-0030 H-0040 H-0303 H-0312 H-0352 H-0353 H-0354 H-0355 H-0362 H-0363 Table 103.E, Summary Applicability - Heaters and Boilers Description Boiler 7 Boiler 8 Boiler 9 Unit 13 Naphtha Splitter Reboiler Unit 21 Vacuum Unit Heater Unit 06 HDS Reboiler South Crude Charge Heater South Crude Charge Heater NSPS D NO NO NO NO NO NO NO NO NSPS Db YES YES YES NO NO NO NO NO NSPS Dc NO NO NO NO NO NO NO NO NSPS J YES YES NO YES YES YES YES YES NSPS Ja NO NO Yes NO NO NO NO NO MACT DDDDD YES YES YES YES YES YES YES YES Unit 21 Heater H-28 NO NO NO YES NO YES Unit 06 Charge Heater NO NO NO YES NO YES Unit 13 Charge Heater NO NO NO YES NO YES Unit 05 Charge Heater NO NO NO YES NO YES Unit 10 FCC Feed Heater NO NO NO YES NO YES Unit 70 CCR Reformer Heater NO NO NO YES NO YES Unit 70 CCR Reformer Heater NO NO NO YES NO YES Unit 70 CCR Reformer Heater NO NO NO YES NO YES Unit 70 Stabilizer Reboiler Heater NO NO NO YES NO YES Unit 70 CCR Heater NO NO NO YES NO YES 20.2.33.108 NMAC YES YES YES NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO Unit 70 CCR Heater NO NO NO YES NO YES NO 20.2.37 NMAC YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES YES CAM NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO EPA Inspection Report - Page 932 of 1969 Unit ID H-0364 H-0421 H-0464 H-0473 H-0600 H-0601 H-2421 H-8801/ H-8802 H-3402 H-3403 H-5401 H-9851 H-2501 H-3101 (formerly SRU3-HOH) SRU3-TGI Description Unit 70 CCR Heater NSPS D NO NSPS Db NO Unit 44 Charge Heater NO NO SRU Hot Oil Heater NO NO SRU1 and SRU2 Tail Gas Incinerator NO NO Unit 09 Depropanizer Reboiler Heater NO NO Unit 33 Charge Heater NO NO Unit 45 Charge Heater NO NO Unit 63 Hydrogen Plant Reformer NO NO Unit 34 Hydrocracker Reboiler 1 NO NO Hydrocracker Reactor Charge Heater NO NO Unit 54 HDS Reactor Heater NO NO Unit 64 Hydrogen Plant Reformer NO NO Unit 25 ROSE Unit NO YES No.2 Hot Oil Heater SRU3 Hot Oil Heater NO NO SRU3 Tail Gas Incinerator NO NO NSPS Dc NO NO YES NO NO NO NO NO NO NO NO NO NO NO NO NSPS J YES YES YES YES YES YES YES YES NO NO NO NO NO NO NO NSPS Ja NO NO NO NO NO NO NO NO YES YES YES YES YES YES YES MACT DDDDD YES 20.2.33.108 NMAC NO YES NO NO NO NO NO YES NO YES NO YES NO YES YES YES NO YES NO YES NO YES YES YES YES 20.2.37 NMAC YES YES YES YES YES YES YES YES YES YES YES YES YES CAM NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO YES NO NO NO YES NO EPA Inspection Report - Page 933 of 1969 Table 103.F, Summary Applicability - Cooling Towers Cooling Tower Y-0001 Y-0002 Y-0008 Y-0011 Y-0012 CT TT-0006 Description TCC Cooling Tower S. Alky Cooling Tower (Marley Cooling Tower) North Alky Cooling Tower FCC & NP Cooling Tower Hydrogen Plants Cooling Tower Unit 07 Amine W-0745 Cooling Tower MACT Q NO NO NO NO NO NO MACT CC YES YES YES YES YES NO Table 103.G, Summary Applicability - Wastewater [return] Equipment ID MAIN API DAF-0896 DAF-0806 T-0801 T-0805 T-0829 T-0836 T-0897 Emission Point ID D-0829/0830 DAF-0896 DAF-0806 MACT CC Wastewater YES YES YES YES YES YES YES YES NESHAP FF YES YES YES YES YES YES YES YES NSPS QQQ YES NO NO NO NO NO NO NO CAM NO NO NO NO NO NO CAM NO NO NO NO NO NO NO NO EPA Inspection Report - Page 934 of 1969 Table 103.H, Summary Applicability - FCC-CCR Unit ID FCCREGEN NSPS J YES NSPS Ja NO MACT UUU YES 20.2.37 NMAC YES CCR N/A N/A YES N/A CAM YES Satisfied by MACT UUU NO Table 103.I, Summary Applicability - SRU Source ID SRU1 Emission Point ID H-0473 SRU2 H-0473 SRU3 SRU3TGI Description SRU1 and SRU2 Tail Gas Incinerator SRU1 and SRU2 Tail Gas Incinerator SRU3 Tail Gas Incinerator NSPS J YES YES NO NSPS Ja NO NO YES MACT UUU YES YES YES 20.2.37.200B 20.2.37.202.A 20.2.39 YES YES NO YES YES NO YES YES NO CAM YESSatisfied by MACT UUU YESSatisfied by MACT UUU YESSatisfied by MACT UUU EPA Inspection Report - Page 935 of 1969 Table 103.J, Summary Applicability - Engines [return] Source ID E-0600W E-0601M E-0602E E-0603 E-0901 G-0100 G-0101 V-0543 V-0545 V-0546 E-8010 Description Fire Water Pump Engine Fire Water Pump Engine Fire Water Pump Engine Fire Water Pump Engine Fire Water Pump Engine UPS backup generator UPS backup generator Portable Air Compressor Portable Air Compressor Portable Air Compressor WWTP Emergency Engine NSPS IIII YES YES YES YES YES NO NO YES YES YES YES MACT ZZZZ YES YES YES YES YES YES YES YES YES YES YES 20.2.61.109 NMAC YES YES YES YES YES YES YES YES YES YES YES CAM NO NO NO NO NO NO NO NO NO NO NO Table 103.K, Summary Applicability - FLARES [return] Unit ID Description NSPS A NSPS J NSPS Ja NESHAP A FL-400 North Plant Flare YES NO YES NO FL-401 South Plant Flare YES NO YES NO FL-402 FCCU Flare YES NO YES NO FL-403 Alky Flare YES NO YES NO FL-404 GOHT Flare YES NO YES NO All flares are steam assisted. State of New Mexico requires that an exit gas velocity of 65 ft/sec for modeling. The heating value of the gas for all flares is < 1000 BTU/scf. MACT A YES YES YES YES YES 20.2.37.201B NMAC YES YES YES YES YES EPA Inspection Report - Page 936 of 1969 Unit No. B-0007 B-0008 B-0009 E-8010 E-0600W E-0601M E-0602E E-0603 E-0901 G-0100 G-0101 V-0543 V-0545 V-0546 H-0009 H-0011 H-0018 Table 104.A: Regulated Sources List [return to A104] Unit Type Manufacturer Model No. Boiler 7 Todd/John Zink burners Unknown Boiler 8 Todd/John Zink burners Unknown Boiler 9 WWTP Diesel Pump Engine Fire Water Pump Engine Fire Water Pump Engine Fire Water Pump Engine Fire Water Pump Engine Fire Water Pump Engine UPS backup generator UPS backup generator Portable Air Compressor Portable Air Compressor Portable Air Compressor Babcock & Wilcox John Deere Clarke Diesel Deere) Clarke Diesel Deere) Clarke Diesel Deere) Clarke Diesel Deere) Clarke Diesel Deere) (John (John (John (John (John Deutz Deutz Cummings, Inc. Cummings, Inc. Cummings, Inc. TBD 6090HF485/ RG6090L101484 JW6H-UFAD70/ RG6090L113548 JW6H-UFAD70/ RG6090L113561 JW6H-UFAD70/ RG6090L113574 JU6H-UFADX8/ PE6068L228486 JX6H-UF30' RG6125A016118 F4L912GEN/ Engine Family WDZXL05.7010 F4L 1011 F/ EI97- 68CA00-000-0053 QSC, 73104611 QSC, 73142120 QSC, 46917364 Unit 13 Naphtha Splitter Reboiler Zeeco burners GSFW-12 burners Unit 21 Vacuum Flasher Heater John Zink burners HEVD-14 Naphtha HDS Reboiler Zeeco burners GSFW-8 burners Manufacture Date 10/8/2001 * 2003 * TBD 2/2011 7/2012 7/2012 7/2012 2012 10/2007 1998 1999 8/30/2010 4/8/2011 11/19/2008 Unknown 9/26/2014 Unknown Capacity 215 MMBtu/hr (LHV Basis) 215 MMBtu/hr (LHV Basis) 220 MMBtu/hr (LHV Basis) 400 hp 376 hp 376 hp 376 hp 305 hp 430 hp 52 hp 54 hp 260 hp 260 hp 240 hp 44 MMBtu/hr Basis) 38 MMBtu/hr Basis) 32 MMBtu/hr Basis) (LHV (LHV (LHV EPA Inspection Report - Page 937 of 1969 Unit No. H-0019 H-0020 H-0028 H-0030 H-0040 H-0303 H-0312 H-0352 H-0353 H-0354 H-0355 H-0362 H-0363 H-0364 H-0421 H-0464 H-0600 Unit Type South Crude Charge Heater South Crude Charge Heater Unit 21 Heater H-28 (previously H-10) Unit 06 Charge Heater Unit 13 Charge Heater Unit 05 Charge Heater Unit 10 FCC Feed Heater Unit 70 CCR Heater (previously 70-H1) Unit 70 CCR Heater (previously 70-H2) Unit 70 CCR Heater (previously 70-H3) Unit 70 Stabilizer Reboiler Heater H-355 (previously 70H-4) Unit 70 CCR Heater Unit 70 CCR Heater Unit 70 CCR Heater Unit 44 Charge Heater (previously H-21) SRU Hot Oil Heater Depropanizer Reboiler (previously 3F-1) Heater Manufacturer Callidus Technologies, LLC burners Callidus Technologies, LLC burners John Zink burners John Zink burners John Zink burners John Zink burners John Zink burners Callidus Technologies, LLC burners Callidus Technologies, LLC burners Callidus Technologies, LLC burners John Zink burners Callidus Technologies, LLC burners Callidus Technologies, LLC burners Callidus Technologies, LLC burners John Zink burners Callidus Technologies, LLC burners Callidus Technologies, LLC burners Model No. CUBL-8W burners CUBL-12W burners PSFG-12 burners PSFG-16R burners PSFG-16 burners HEVD-Q-18 burners VYD-18 burners CUBL-10W burners CUBL-10W burners CUBL-10W burners Unknown CUBL-8W burners CUBL-8W burners CUBL-6W burners LNC-PC-18 burners LE-CSG-4W burners CUBL-12W burners Manufacture Date New burners in 2005 New burners in 2005 Unknown 2000* 1990* 1982* 1990* New burners in 2006 New burners in 2006 New burners in 2006 1991* New burners in 2006 New burners in 2006 New burners in 2006 1981* 2003* 1991*, New burners in 2009 Capacity 54 MMBtu/hr Basis) 78 MMBtu/hr Basis) 12.3 MMBtu/hr Basis) 42 MMBtu/hr Basis) 42 MMBtu/hr Basis) 11 MMBtu/hr Basis) 35 MMBtu/hr Basis) 63 MMBtu/hr Basis) 81 MMBtu/hr Basis) 56 MMBtu/hr Basis) 24 MMBtu/hr Basis) 40 MMBtu/hr Basis) 50 MMBtu/hr Basis) 35 MMBtu/hr Basis) 27 MMBtu/hr Basis) 9.6 MMBtu/hr Basis) 84 MMBtu/hr Basis) (LHV (LHV (LHV (LHV (LHV (LHV (LHV (LHV (LHV (LHV (LHV (LHV (LHV (LHV (LHV (LHV (LHV EPA Inspection Report - Page 938 of 1969 Unit No. H-0601 H-2421 H-8801 H-8802 H-2501 H-3403 H-3402 H-5401 H-9851 H-3101 H-0473 (SRU1/SRU2 TGI) SRU3-TGI FCC Regenerator FL-0400, North Plant Flare FL-0401, South Plant Flare FL-0402, FCC Flare FL-0403, Alky Flare FL-0404, GOHT Flare Y-0001 Unit Type Unit 33 Charge Heater Unit 45 Charge Heater Unit 63 Hydrogen Plant Reformer Furnace Unit 63 Hydrogen Plant Reformer Furnace ROSE2 Hot Oil Heater Hydrocracker Reactor Charge Heater Hydrocracker Fractionator Reboiler 1 Unit 54 HDS Reactor Heater Unit 64 Hydrogen Plant Reformer SRU3 Hot Oil Heater SRU1 and SRU2 Tail Gas Incinerator SRU3 Tail Gas Incinerator FCC Regenerator Scrubber North Plant Flare South Plant Flare FCC Flare Alky Flare GOHT Flare TCC Cooling Tower Manufacturer Callidus Technologies, LLC burners Zeeco, Inc. burners Callidus Technologies, LLC burners Callidus Technologies, LLC burners John Zink Company, LLC burners Callidus Technologies, LLC burners Callidus Technologies, LLC burners Tulsa Heaters Inc. Callidus Technologies, LLC burners Callidus Technologies, LLC burner Unknown Callidus Technologies, LLC burners Unknown Unknown Unknown Unknown Unknown Unknown Unknown Model No. CUB-8P-CW burners GLSF-14 Round Flame "Free Jet" burners LE-CSG-12W-PSA burners LE-CSG-12W-PSA burners COOLstar-18 burners CUBL-10W burners LE-CSG-12W burners TBD CUBL-3WDF burners Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Unknown Manufacture Date New burners in 2003 2006* 2006* 2006* 2009* 2011 2009* 2016 2009* 05/11/2009 * Unknown 05/11/2009 * Unknown Unknown Unknown Unknown Unknown Unknown Unknown Capacity 78 MMBtu/hr (LHV Basis) 27 MMBtu/hr (LHV Basis) 60 MMBtu/hr (LHV Basis) 60 MMBtu/hr (LHV Basis) 120 MMBtu/hr (LHV Basis) 32.0 MMBtu/hr (LHV Basis) 52 MMBtu/hr (LHV Basis) 21.3 MMBtu/hr HHV 337 MMBtu/hr (LHV Basis) 9.6 MMBtu/hr (LHV Basis) NA NA NA NA NA NA NA NA 5,000 gpm EPA Inspection Report - Page 939 of 1969 Unit No. Unit Type Manufacturer Model No. Manufacture Date Capacity S. Alky Cooling Tower (Marley Y-0002 Cooling Tower) Unknown Unknown Unknown 5,000 gpm Y-0008 North Alky Cooling Tower Unknown Unknown Unknown 12,500 gpm Y-0011 FCC & NP Cooling Tower Unknown Unknown Unknown 30,000 gpm Y-0012 Hydrogen Plants Cooling Tower Unknown Unknown Unknown 10,000 gpm Unit 07 Amine W-0745 Cooling CT TT-0006 Tower Unknown Unknown Unknown 3,000 gpm Above Ground API Oil-Water MAIN API Separator Unknown Unknown Unknown 1,200 gpm T-0896 DAF Unit T-0896 Unknown Unknown Unknown 1,200 gpm Enhanced Biodegradation Tank T-0801 T-0801 Unknown Unknown Unknown 1,200 gpm Enhanced Biodegradation Tank T-0836 T-0836 Unknown Unknown Unknown 1,200 gpm T-0829 Equalization Tank T-0829 Not yet installed Not yet installed Not yet installed 1,200 gpm T-0806 DAF Unit T-0806 Not yet installed Not yet installed Not yet installed Not yet installed Fugitives (see Table Equipment component leaks 103.B) (pump seals, valves, flanges, etc.) NA NA Varies NA Loading (see Table 103.D) Bulk Loading/Unloading Racks NA NA Varies Varies Fixed Roof, External Floating Tanks (see Table Roof & Internal Floating Roof 103.C) Tanks NA NA Varies Varies * Installation date Note: Serial numbers are not used since most equipment consists of field erected parts that are assembled on site and may have several "serial numbers" for various components. Heaters are the best example because each of the burners has a serial number but the heater as a whole does not have a single serial number. The heater as a whole is typically identified by our equipment number. There may also be a "project number" or "job number" from the manufacturer, but that can change if a heater is revamped at a later date such as when they modify the convection section to improve energy efficiency. EPA Inspection Report - Page 940 of 1969 Source ID B-0007 B-0008 B-0009 H-0009 H-0011 H-0018 H-0019 H-0020 H-0028 H-0030 H-0040 H-0303 H-0312 H-0352 /0353/0354 H-0355 H-0362/ 0363/0364 H-0421 H-0464 H-0600 H-0601 H-2421 H-2501 H-3101 H-3402 H-3403 H-8801 3,5MM Btu/hr 215 215 220 44 38 32 54 78 12.3 42 42 11 35 63/81/56 SO2 5 (lb/hr) (ton/yr) 7.8 12.7 7.8 12.7 2.6 11.4 1.6 2.6 1.4 2.3 1.2 1.9 2.0 3.2 2.8 4.6 0.4 0.7 1.5 2.5 1.5 2.5 0.4 0.7 1.3 2.1 7.3 11.8 5(lb/hr) 12.9 12.9 4.4 4.0 9.5 3.5 2.9 4.2 2.2 3.2 3.8 1.2 4.6 9.0 24 0.9 1.4 2.2 40/50/35 4.6 7.4 6.9 27 1.0 1.6 2.4 9.6 0.4 0.6 0.5 84 3.1 5.0 4.7 78 2.8 4.6 3.5 27 1.0 1.6 1.2 120 4.4 7.1 3.6 9.6 0.4 0.6 0.3 52 1.9 3.1 1.6 32.0 1.2 1.9 1.0 60/60 0.2 0.8 4.2 Table 106.A Allowable Emission Limits 2NOx CO 4PM 5(lb/MM (ton/yr) Btu) 5(lb/hr) (ton/yr) (lb/hr) (ton/yr) 56.5 0.06 19.6 85.7 1.8 7.8 56.5 0.06 19.6 85.7 1.8 7.8 19.3 0.02 8.1 35.7 1.6 7.2 17.3 0.09 4.0 17.5 0.4 1.6 31.6 - 3.5 15.2 0.3 1.4 15.2 - 2.9 12.8 0.3 1.2 12.5 0.0527 4.9 21.5 0.4 2.0 18.3 0.0535 7.1 31.1 0.6 2.8 9.5 - 1.1 4.9 0.1 0.4 14.0 - 3.8 16.8 0.4 1.5 16.6 - 3.8 16.8 0.4 1.5 5.2 - 1.0 4.4 0.1 0.4 20.2 - 3.2 14.0 0.3 1.3 VOC 5(lb/hr) 1.3 1.3 0.9 0.3 0.2 0.2 0.3 0.5 0.1 0.3 0.3 0.1 0.2 (ton/yr) 5.6 5.6 3.9 1.2 1.0 0.8 1.4 2.0 0.3 1.1 1.1 0.3 0.9 H2S (lb/hr) (ton/yr) 39.4 0.045 18.2 79.7 1.7 7.2 1.2 5.2 9.5 - 2.2 9.6 0.2 0.9 0.1 0.6 30.1 0.055 11.4 49.8 1.0 4.5 0.7 3.3 10.6 0.09 2.5 10.8 0.2 1.0 0.2 0.7 2.3 - 0.9 3.8 0.1 0.4 0.1 0.3 20.3 0.05 7.6 33.5 0.7 3.03 0.5 2.2 15.4 0.045 7.1 31.1 0.6 2.8 0.5 2.0 5.3 0.045 2.5 10.8 0.2 1.0 0.2 0.7 15.8 0.03 7.2 31.5 1.0 4.3 0.7 3.1 1.3 0.03 0.9 3.8 0.1 0.4 0.1 0.3 6.8 0.03 4.7 20.7 0.4 1.9 0.3 1.4 4.2 0.03 2.9 12.8 0.3 1.2 0.2 0.8 18.4 0.035 10.9 47.8 1.0 4.3 0.7 3.1 EPA Inspection Report - Page 941 of 1969 Source ID /8802 H-9851 H-5401 H-0473 (SRU1/SRU 2 TGI) SRU3-TGI FCC Regenerator FL-0400, North Plant Flare FL-0401, South Plant Flare FL-0402, FCC Flare FL-0403, Alky Flare FL-0404, GOHT Flare Subtotal Tanks, Table 106.E Fugitives, Table 106.F Misc Sources, Table 106.G 3,5MM Btu/hr 337 6.44 NA NA NA NA NA NA NA NA SO2 5 (lb/hr) (ton/yr) 5(lb/hr) 0.5 2.2 4.2 0.71 1.1 0.64 30.0 81.8 6.5 30.0 81.8 6.5 27.9 61.0 35.0 0.2 0.5 0.2 0.1 0.1 <0.1 0.1 0.1 <0.1 <0.1 <0.1 <0.1 2.4 10.5 4.1 346.6 2NOx (ton/yr) 18.5 2.8 28.5 28.5 101.9 0.8 0.2 0.2 <0.1 18.1 697.9 CO 4PM VOC H2S 5(lb/MM Btu) 5(lb/hr) (ton/yr) (lb/hr) (ton/yr) 5(lb/hr) (ton/yr) (lb/hr) (ton/yr) 0.0125 20.2 88.6 2.8 12.2 2.0 8.8 0.03 0.64 2.8 0.16 0.7 0.12 0.5 N/A 27.7 121.2 0.5 2.2 0.1 0.6 0.3 1.31 N/A 15.0 65.7 0.5 2.2 0.1 0.6 0.3 1.31 N/A 121.9 106.8 25.0 109.5 - - N/A 1.0 4.3 0.0 0.0 0.2 0.7 N/A 0.2 1.1 0.0 0.0 <0.1 0.2 N/A 0.2 1.1 0.0 0.0 <0.1 0.2 N/A <0.1 0.2 0.0 0.0 <0.1 <0.1 N/A 13.6 59.6 0.0 0.0 2.3 10.2 1181.4 197.8 96.2 297.3 1.1 0.83 1022.6 16.6 EPA Inspection Report - Page 942 of 1969 Source ID Cooling Towers, Table 106.H Oil/Water Separators, Table 106.I 6SSM, Table 107 Site TOTAL 1 3,5MM Btu/hr NA SO2 5 (lb/hr) (ton/yr) 5(lb/hr) 27.5 374.1 2NOx (ton/yr) 31.7 729.6 CO 4PM VOC H2S 5(lb/MM Btu) 5(lb/hr) (ton/yr) (lb/hr) (ton/yr) 5(lb/hr) (ton/yr) (lb/hr) (ton/yr) 2.5 8.9 56.2 1.3 5.9 98.0 0.4 36.2 14.32 0.60 N/A 1281.9 207.1 1531.0 1.7 4.05 1 Totals are for information and are not enforceable conditions. 2 Nitrogen dioxide emissions include all oxides of nitrogen expressed as NO2 3 lbs-NOX/MMBtu of heat input, calculated as a 3-hour average, when firing natural gas at 3% stack oxygen at full design load without air preheat. 4 All Particulate Matter emitted is assumed to be of aerodynamic diameter 10 microns or less. 5 Hourly emission limits and lb/MM Btu limits are based on an hourly rolling 3-hour average. 6 Maximum allowable emissions during maintenance, startup, or shutdown (SSM) and malfunction activities. "-" or leaving a cell blank indicates that in accordance with the application, emissions of this pollutant are not expected. "- -" indicates that the emissions are less than 1.0 pph or 1.0 tpy and emission limits are not required for this permit, unless it's for a control device. Unit 9851 has Ammonia Slip limit of 7 ppmv on a wet basis and 6.1 tpy EPA Inspection Report - Page 943 of 1969 TABLE 106.B(1) VAPOR PRESSURE LIMITATIONS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS (VOC) INTERNAL FLOATING ROOF STORAGE TANKS Tank No. Typical Liquid Stored T-0056 T-0106 T-0107 T-0108 T-0109 T-0111 T-0112 T-0011 T-0124 T-0012 T-0413 T-0415 T-0417 T-0439 T-0451 T-0452 Naphthas Sour Water Gasolines Gasolines Gasolines Gasolines Gasolines Gasolines Gasolines Gasolines Distillates Gasolines Gasolines Naphtha Biodiesel Ethanol Most Volatile Category of Allowable Liquids to be Stored1 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 Max Vapor Pressure (psia) of Most Volatile Liquid at Max Temp. 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 1 Liquids in lower volatility categories may also be stored (i.e., tanks allowed to store high vapor pressure category liquids can also store moderate and low vapor pressure category liquids; tanks allowed to store moderate vapor pressure category liquids can also store low vapor pressure category liquids). 2 High Vapor Pressure Liquids include: Crude, Naphtha (raw or treated), Unleaded Gasolines (sub-grade, regular, premium, and other blends), Alkylate, Reformate, FCC Gasoline, Ethanol, Isomerate, Straight Run Gasoline, and other refinery feedstocks, intermediates, products, byproducts, and wastes having a max vapor pressure of 11 psia or less under actual storage conditions. EPA Inspection Report - Page 944 of 1969 TABLE 106.B(2) VAPOR PRESSURE LIMITATIONS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS (VOC) EXTERNAL FLOATING ROOF STORAGE TANKS Tank No. Typical Stored Liquid Most Volatile Category of Allowable Liquids to be Stored1 Max Vapor Pressure (psia) of Most Volatile Liquid at Max Temp. T-0057 Naphthas High Vapor Pressure2 11.0 T-0079 Gasolines High Vapor Pressure2 11.0 T-0117 Gasolines High Vapor Pressure2 11.0 T-0401 Gasolines High Vapor Pressure2 11.0 T-0402 Gasolines High Vapor Pressure2 11.0 T-0411 Gasolines High Vapor Pressure2 11.0 T-0412 Gasolines High Vapor Pressure2 11.0 T-0435 Sour Water High Vapor Pressure2 11.0 T-0437 Crude Oil High Vapor Pressure2 11.0 T-0450 Naphthas High Vapor Pressure2 11.0 T-0802 Sour Water High Vapor Pressure2 11.0 T-0830 Slop High Vapor Pressure2 11.0 T-0834 Distillates Moderate Vapor Pressure3 1.5 T-0835 Distillates High Vapor Pressure2 11.0 T-1225 Crude Oil High Vapor Pressure2 11.0 T-0737 Sour Water High Vapor Pressure2 11.0 T-5401 Gasolines High Vapor Pressure2 11.0 1 Liquids in lower volatility categories may also be stored (i.e., tanks allowed to store high vapor pressure category liquids can also store moderate and low vapor pressure category liquids; tanks allowed to store moderate vapor pressure category liquids can also store low vapor pressure category liquids). 2 High Vapor Pressure Liquids include: Crude, Naphtha (raw or treated), Unleaded Gasolines (sub-grade, regular, premium, and other blends), Alkylate, Reformate, FCC Gasoline, Ethanol, Isomerate, Straight Run Gasoline, and other refinery feedstocks, intermediates, products, byproducts, and wastes having a max vapor pressure of 11 psia or less under actual storage conditions. 3 Moderate Vapor Pressure Liquids include: Desulfurized Naphtha (Splitter Bottoms), Light Slop, and other refinery feedstocks, intermediates, products, byproducts, and wastes having a max vapor pressure of 1.5 psia or less under actual storage conditions. EPA Inspection Report - Page 945 of 1969 TABLE 106.C VAPOR PRESSURE LIMITATIONS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS (VOCs) Tank No. T-0040 T-0041 T-0110 T-0400 T-0410 T-0418 T-0419 T-0420 T-0422 T-0423 T-0431 T-0432 FIXED ROOF STORAGE TANKS Typical Liquid Stored Spent Caustic Spent Caustic Asphalt/Pitch Gas Oils Asphalt/Pitch Distillates Distillates Fuel Oil Black Oil Black Oil Fuel Oil Fuel Oil Most Volatile Category of Allowable Liquids to be Stored1 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Max Vapor Pressure (psia) of Most Volatile Liquid at Max Temp. 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 EPA Inspection Report - Page 946 of 1969 TABLE 106.C -cont'd EMISSION LIMITATIONS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS (VOCs) Tank No. T-0049 T-0055 T-0059 T-0061 T-0063 T-0065 T-0075 T-0433 T-0434 T-0438 T-0814 T-0815 T-0838 T-1227 T-0081 T-0082 RW-4 RW-5 RW-6 FIXED ROOF STORAGE TANKS Typical Liquid Stored Most Volatile Category of Allowable Liquids to be Stored1 Slop Distillates Distillates Distillates Black Oil Black Oil Black Oil Gas Oils Distillates Gas Oils Asphalt/Pitch Distillates Distillates Asphalt/Pitch Asphalt/Pitch Asphalt/Pitch Recovery Well Hydrocarbons Recovery Well Hydrocarbons Recovery Well Hydrocarbons Moderate Vapor Pressure3 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 Low Vapor Pressure4 High Vapor Pressure2 High Vapor Pressure2 High Vapor Pressure2 Max Vapor Pressure (psia) of Most Volatile Liquid at Max Temp. 1.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 11.0 11.0 11.0 1 Liquids in lower volatility categories may also be stored (i.e., tanks allowed to store high vapor pressure category liquids can also store moderate and low vapor pressure category liquids; tanks allowed to store moderate vapor pressure category liquids can also store low vapor pressure category liquids). 2 High Vapor Pressure Liquids include: Crude, Naphtha (raw or treated), Unleaded Gasolines (sub-grade, regular, premium, and other blends), Alkylate, Reformate, FCC Gasoline, Ethanol, Isomerate, Straight Run Gasoline, and other refinery feedstocks, intermediates, products, byproducts, and wastes having a max vapor pressure of 11 psia or less under actual storage conditions. 3 Moderate Vapor Pressure Liquids include: Desulfurized Naphtha (Splitter Bottoms), Light Slop, and other refinery feedstocks, intermediates, products, byproducts, and wastes having a max vapor pressure of 1.5 psia or less under actual storage conditions. 4 Low Vapor Pressure Liquids include: Diesel (raw or finished), Kerosene (raw or finished), JP-8, CBO, LCO, Slurry, Heavy Slop, Cutback Asphalt, Cutter, VGO, AGO, and other refinery feedstocks, intermediates, products, byproducts, and wastes having a max vapor pressure less than 0.5 psia under actual storage conditions. EPA Inspection Report - Page 947 of 1969 TABLE 106.D - STORAGE TANK THROUGHPUT AND TEMPERATURE LIMITS Material Asphalt/Pitch Black Oil Crude Oil Distillate Gas Oil Gasoline (includes isomerates) Naphtha Slop Sour Water BioDiesel Ethanol Fuel Oil Spent Caustic Ground Water Throughput (bbl/yr) 30,872,000 3,305,356 76,212,000 158,185,540 25,059,500 63,438,600 47,632,500 1,049,590 15,030,000 949,000 142,350 10,609,022 56,000 7,200 Maximum Storage Temperature (F) 510 250 Ambient Ambient 310 Ambient Ambient Ambient Ambient Ambient Ambient Ambient Ambient Ambient TABLE 106.E- STORAGE TANK VOC AND H2S EMISSION LIMITS1 Tank Type VOC Emission Rate (tpy) H2S Emission Rate (tpy) Fixed-Roof 195.53 0.0 Floating-Roof 101.77 0.83 Total Tanks 297.30 0.83 1 See Specific Condition A203.E for monitoring, recordkeeping and reporting requirements. EPA Inspection Report - Page 948 of 1969 Table 106.F 1EMISSIONS LIMITS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS (VOC) FUGITIVE EMISSIONS FROM EQUIPMENT LEAKS Process Unit ID Number Description FUG-02-SP CRUDE FUG-10-FCC FUG-20-ISOM FUG-21-SP VACUUM FUG-05-KERO FUG-06-NHDU FUG-18-LSR MEROX TRT FUG-35-SAT GAS FUG-29BLENDER/TK FARM FUG-ASPHALT STG FUG-FUEL GAS FUG-LPG FUG-41-PBC FUG-70-CCR FUG-13-NHDU FUG-43-S ALKY FUG-09-N ALKY FUG-44-DIST-HDU FUG-45-DIST-HDU FUG-07-N AMINE FUGSRU1/SRU2/TGTU FUG-07-SWS1 FUG-80-WWTP CVS FUG-33-DIST HDU FUG-08-TRUCK RK FUG-RLO-ASPHALT FUG-73-SP UTIL FUG-63-H2 PLANT-1 FUG-31SRU3/TGTU3/TGI3 FUG-34- South Division Crude Unit FCC w/CVS BenFree Unit Flasher/Vacuum Unit Kerosene HDS Unit Naphtha HDS Unit 06 Merox/Merichem Treating Units Saturates Gas Plant Light Oil Tankage Asphalt/Heavy Oil Storage Fuel Gas Distribution System LPG Storage System PBC Unit CCR Reformer (w/in battery limits) Naphtha HDS Unit 13 South Alky Unit (W-76) North Alkylation Unit (NewInside battery limits) Gas Oil Hydrotreater (incl. CVS) Gas Oil Hydrotreater (incl. CVS) Amine Unit-Treating/Regen. SRU1/SRU2/SWS w/CVS Sour Water Stripper Oil/Water Separator Relocated Diesel HDS Unit w/CVS Loading Racks Asphalt/Pitch Loading Rack Utilities Hydrogen Plant SRU3 Unit WX Hydrocracker Maximum Hourly VOC Emission Rate (lb/hr) 10.2 10.8 5.94 3.2 5.2 7.11 3.5 Average Annual VOC Emission Rate (tons/yr) 44.6 47.2 26.03 13.9 22.7 31.15 15.3 18.3 80.0 6.8 29.6 3.5 15.3 4.2 18.2 21.6 94.4 3.4 14.7 23.4 102.3 10.17 1.7 12.0 44.55 7.5 52.5 9.39 41.14 2.6 11.2 6.3 27.5 2.4 10.4 1.6 1.3 13.47 7.0 5.9 59.01 2.8 12.1 0.7 2.9 16.7 73.3 2.6 11.2 0.7 3.1 6.2 27.2 EPA Inspection Report - Page 949 of 1969 Maximum Average Process Unit ID Number Description Hourly VOC Annual VOC Emission Emission Rate Rate (lb/hr) (tons/yr) HYDROCRACKER FUG-25-ROSE-2 ROSE Unit 8.0 35.1 FUG-64-H2 PLANT-2 Hydrogen Plant 2.6 11.2 FUG-RRTOTRUCK Crude oil unloading system, 0.1 0.5 closed loop system between railcars and trucks FUG-54-PRIMEG Prime G Unit 5.6 24.7 Subtotal (for informational purposes only, may differ due to 234.084 1,023.38 rounding) 1 Minor changes within the facility to piping and components that affect fugitive VOC emission source shall be updated and added during the next available significant modification to the NSR permit. The VOC total emissions have a safety level due to rounding to accommodate these minor variations in emissions. Table 106.G EMISSION LIMITS FOR REFINERY NON-COMBUSTION SOURCES Of VOLATILE ORGANIC COMPOUNDS (VOCs) -MISCELLANEOUS SOURCES- Maximum Average Hourly VOC Annual VOC Emission Emission Source ID Description Rate (lb/hr) Rate (tons/yr) Asphalt Truck Loading and Off-Loading TLO-1 Rack #1 <0.1 <0.1 TL-2 TL-4a Asphalt Truck Loading Rack #2 Fuels Truck Loading Rack <0.1 <0.1 6.7 4.9 TL-7 CBO/LCO Truck Loading Rack 6.3 1.6 RLO-8 Railcar Loading & Off-Loading Rack 6.3 2.1 RLO-19 Railcar Loading & Off-Loading Rack 8.4 5.6 TLO-20 Asphalt/Pitch Truck Loading Rack <0.1 <0.1 FUG-ODOR Odor Controlling Atomizer 0.46 2.0 Subtotal (for informational purposes only) 28.6 16.6 a Controlled emission rate. The previous controlled rate was set by the terms of the consent agreement between Navajo Refining Co. and the Department executed January 28, 1994. The agreement required that the incinerator have a minimum 90% destruction efficiency for gasoline loading and a minimum 80% destruction efficiency for diesel fuel loading or Jet A fuel loading. This was achieved by a vapor combustor. This device has since been replaced with a carbon adsorption system compliant with MACT Subpart R, as subject per MACT Subpart CC. Emission limits changed in 195-M-17 to correspond to Title V permit values. EPA Inspection Report - Page 950 of 1969 Table 106.H EMISSION LIMITS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUMDS and PM -COOLING TOWERS- Source ID VOC VOC PM PM lb/hr tons/yr (lb/hr) (tons/yr) Y-0001 1.8 7.9 0.3 1.2 Y-0002 1.8 7.9 0.3 1.2 Y-0008a 6.5 28.3 0.7 2.9 Y-0011 1.3 5.5 0.5 2.3 Y-0012 0.4 1.8 0.2 0.8 CT TT-0006 1.1 4.7 0.2 0.7 Subtotal (for 12.8 56.2 2.1 9.0 informational purposes only) a Y-0008 includes 0.58 lbs/hour CO and 2.54 tpy CO. This cooling tower provides 100% control of any NH3 emissions from V-H2 and V-H2-2. Unit 64, Hydrogen Plant has de-aerator line that has dissolved CO that is connected to the cooling tower. Table 106.I EMISSION LIMITS FOR REFINERY NON-COMBUSTION SOURCES OF VOLATILE ORGANIC COMPOUNDS (VOCs) API OIL/WATER SEPARATORS Maximum Average Hourly Annual VOC VOC Emission Emission Rate Rate Equipment ID Emission Point ID Description (lb/hr) (tons/yr) Above Ground API Oil- Water Separators and MAIN API D-0829/0830 enclosed drain system. <0.1 <0.1 T-0896 DAF-0896 DAF Unit T-0896 0.2 0.7 Enhanced Biodegradation Tank T- T-0801 T-0801 0801 0.2 1.0 Enhanced Biodegradation Tank T- T-0836 T-0836 0836 0.8 3.5 Equalization Tank T- T-0829 T-0829 0829 <0.1 <0.1 T-0806 DAF-0806 DAF Unit T-0806 0.2 0.7 Subtotal (for informational purposes only) 1.3 5.9 EPA Inspection Report - Page 951 of 1969 Unit SSM H-9851 SSM T-0737 SSM SRU3TGI SSM FL-HEPPORT SSM SRU2TGI (H-0473) SSM Flare Cap Flares Malf Cap SSM Misc 2 SSM Tanks Misc Subtotal SSM/M1 Table 107.A [return] MAINTENANCE STARTUP AND SHUTDOWN EMISSION LIMITS NOx PM/PM10/PM CO VOC 2.5 Description of Emissions pph tpy pph tpy pph tpy pph tpy Emissions during SCR downtime 10.1 1.2 20.2 2.4 2.0 0.2 2.8 0.3 Emissions from roof landing -- -- -- -- 33.0 0.5 -- -- Emissions from SRU3 startup and shutdown 6.5 0.1 15.0 0.1 0.1 0.1 -- -- Temporary, portable flare for natural gas pipeline maintenance 173.4 0.1 943.5 0.5 160.7 0.1 -- -- Emissions from SRU2 startup and shutdown 6.5 0.1 27.7 0.2 0.2 0.1 -- -- Emissions from venting MSS activity gases to FL-400, FL- 401,FL-402, FL-403, or FL-404. 162.9 18.3 1243.0 77.0 211.6 13.2 -- -- Upset and Malfunction Emissions -- 10.0 -- 10.0 -- 10.0 -- -- Low-Emitting Maintenance Activities such as de-inventorying small equipment, clearing piping associated with emission units, and routine maintenance activities such as heat exchanger repair. 17.0 1.9 127.1 7.8 21.2 1.4 -- -- Storage Tanks -- -- -- -- 173.1 10.6 -- -- 31.7 98.0 36.2 0.3 SO2 pph tpy 0.5 0.1 -- -- 159.0 0.4 1.7 0.1 159.0 0.4 1133. 4 14.9 -- 10.0 129.3 1.6 -- -- 27.5 H2S pph tpy -- -- -- -- 6.5 0.1 0.02 0.1 6.6 0.1 0.4 0.1 -- -- 0.7 0.1 0.1 0.1 14.32 0.6 EPA Inspection Report - Page 952 of 1969 AIR QUALITY BUREAU NEW SOURCE REVIEW PERMIT Issued under 20.2.72 NMAC GENERAL CONDITIONS AND MISCELLANEOUS Part B B100 B101 B102 B103 B104 B105 B106 B107 B108 B109 B110 B111 B112 B113 B114 B115 B116 Part C C100 C101 C102 TABLE OF CONTENTS GENERAL CONDITIONS ..........................................................................................B2 Introduction ............................................................................................................... B2 Legal .........................................................................................................................B2 Authority ...................................................................................................................B3 Annual Fee ................................................................................................................B3 Appeal Procedures ....................................................................................................B3 Submittal of Reports and Certifications....................................................................B4 NSPS and/or MACT Startup, Shutdown, and Malfunction Operations ...................B4 Startup, Shutdown, and Maintenance Operations.....................................................B5 General Monitoring Requirements ...........................................................................B5 General Recordkeeping Requirements .....................................................................B6 General Reporting Requirements..............................................................................B9 General Testing Requirements................................................................................B10 Compliance .............................................................................................................B12 Permit Cancellation and Revocation.......................................................................B13 Notification to Subsequent Owners ........................................................................B13 Asbestos Demolition...............................................................................................B14 Short Term Engine Replacement ............................................................................B14 MISCELLANEOUS .....................................................................................................C1 Supporting On-Line Documents ...............................................................................C1 Definitions................................................................................................................. C1 Acronyms ..................................................................................................................C3 EPA Inspection Report - Page 953 of 1969 PART B GENERAL CONDITIONS B100 Introduction A. The Department has reviewed the permit application for the proposed construction/modification/revision and has determined that the provisions of the Act and ambient air quality standards will be met. Conditions have been imposed in this permit to assure continued compliance. 20.2.72.210.D NMAC, states that any term or condition imposed by the Department on a permit is enforceable to the same extent as a regulation of the Environmental Improvement Board. B101 Legal A. The contents of a permit application specifically identified by the Department shall become the terms and conditions of the permit or permit revision. Unless modified by conditions of this permit, the permittee shall construct or modify and operate the Facility in accordance with all representations of the application and supplemental submittals that the Department relied upon to determine compliance with applicable regulations and ambient air quality standards. If the Department relied on air quality modeling to issue this permit, any change in the parameters used for this modeling shall be submitted to the Department for review. Upon the Department's request, the permittee shall submit additional modeling for review by the Department. Results of that review may require a permit modification. (20.2.72.210.A NMAC) B. Any future physical changes, changes in the method of operation or changes in restricted area may constitute a modification as defined by 20.2.72 NMAC, Construction Permits. Unless the source or activity is exempt under 20.2.72.202 NMAC, no modification shall begin prior to issuance of a permit. (20.2.72 NMAC Sections 200.A.2 and E, and 210.B.4) C. Changes in plans, specifications, and other representations stated in the application documents shall not be made if they cause a change in the method of control of emissions or in the character of emissions, will increase the discharge of emissions or affect modeling results. Any such proposed changes shall be submitted as a revision or modification. (20.2.72 NMAC Sections 200.A.2 and E, and 210.B.4) D. The permittee shall establish and maintain the property's Restricted Area as identified in plot plan submitted with the application. (20.2.72 NMAC Sections 200.A.2 and E, and 210.B.4) E. Applications for permit revisions and modifications shall be submitted to: Program Manager, Permits Section New Mexico Environment Department EPA Inspection Report - Page 954 of 1969 Air Quality Bureau 525 Camino de los Marquez, Suite 1 Santa Fe, NM 87505 F. The owner or operator of a source having an excess emission shall, to the extent practicable, operate the source, including associated air pollution control equipment, in a manner consistent with good air pollutant control practices for minimizing emissions. (20.2.7.109 NMAC). The establishment of allowable malfunction emission limits does not supersede this requirement. B102 Authority A. This permit is issued pursuant to the Air Quality Control Act (Act) and regulations adopted pursuant to the Act including Title 20, Chapter 2, Part 72 of the New Mexico Administrative Code (NMAC), (20.2.72 NMAC), Construction Permits and is enforceable pursuant to the Act and the air quality control regulations applicable to this source. B. The Department is the Administrator for 40 CFR Parts 60, 61, and 63 pursuant to the delegation and exceptions of Section 10 of 20.2.77 NMAC (NSPS), 20.2.78 NMAC (NESHAP), and 20.2.82 NMAC (MACT). B103 Annual Fee A. The Department will assess an annual fee for this Facility. The regulation 20.2.75 NMAC set the fee amount at $1,500 through 2004 and requires it to be adjusted annually for the Consumer Price Index on January 1. The current fee amount is available by contacting the Department or can be found on the Department's website. The AQB will invoice the permittee for the annual fee amount at the beginning of each calendar year. This fee does not apply to sources which are assessed an annual fee in accordance with 20.2.71 NMAC. For sources that satisfy the definition of "small business" in 20.2.75.7.F NMAC, this annual fee will be divided by two. (20.2.75.11 NMAC) B. All fees shall be remitted in the form of a corporate check, certified check, or money order made payable to the "NM Environment Department, AQB" mailed to the address shown on the invoice and shall be accompanied by the remittance slip attached to the invoice. B104 Appeal Procedures A. Any person who participated in a permitting action before the Department and who is adversely affected by such permitting action, may file a petition for hearing before the Environmental Improvement Board. The petition shall be made in writing to the EPA Inspection Report - Page 955 of 1969 Environmental Improvement Board within thirty (30) days from the date notice is given of the Department's action and shall specify the portions of the permitting action to which the petitioner objects, certify that a copy of the petition has been mailed or hand-delivered and attach a copy of the permitting action for which review is sought. Unless a timely request for hearing is made, the decision of the Department shall be final. The petition shall be copied simultaneously to the Department upon receipt of the appeal notice. If the petitioner is not the applicant or permittee, the petitioner shall mail or hand-deliver a copy of the petition to the applicant or permittee. The Department shall certify the administrative record to the board. Petitions for a hearing shall be sent to: (20.2.72.207.F NMAC) Secretary, New Mexico Environmental Improvement Board 1190 St. Francis Drive, Runnels Bldg. Rm. N2153 Santa Fe, New Mexico 87502 B105 Submittal of Reports and Certifications A. Stack Test Protocols and Stack Test Reports shall be submitted electronically to Stacktest.AQB@state.nm.us or as directed by the Department. B. Excess Emission Reports shall be submitted as directed by the Department. (20.2.7.110 NMAC) C. Routine reports shall be submitted to the mailing address below, or as directed by the Department: Manager, Compliance and Enforcement Section New Mexico Environment Department Air Quality Bureau 525 Camino de los Marquez, Suite 1 Santa Fe, NM 87505 B106 NSPS and/or MACT Startup, Shutdown, and Malfunction Operations A. If a facility is subject to a NSPS standard in 40 CFR 60, each owner or operator that installs and operates a continuous monitoring device required by a NSPS regulation shall comply with the excess emissions reporting requirements in accordance with 40 CFR 60.7(c), unless specifically exempted in the applicable subpart. B. If a facility is subject to a NSPS standard in 40 CFR 60, then in accordance with 40 CFR 60.8(c), emissions in excess of the level of the applicable emission limit during periods of startup, shutdown, and malfunction shall not be considered a violation of the applicable emission limit unless otherwise specified in the applicable standard. EPA Inspection Report - Page 956 of 1969 C. If a facility is subject to a MACT standard in 40 CFR 63, then the facility is subject to the requirement for a Startup, Shutdown and Malfunction Plan (SSM) under 40 CFR 63.6(e)(3), unless specifically exempted in the applicable subpart. B107 Startup, Shutdown, and Maintenance Operations A. The establishment of permitted startup, shutdown, and maintenance (SSM) emission limits does not supersede the requirements of 20.2.7.14.A NMAC. Except for operations or equipment subject to Condition B106, the permittee shall establish and implement a plan to minimize emissions during routine or predictable start up, shut down, and scheduled maintenance (SSM work practice plan) and shall operate in accordance with the procedures set forth in the plan. (SSM work practice plan) (20.2.7.14.A NMAC) B108 General Monitoring Requirements A. These requirements do not supersede or relax requirements of federal regulations. B. The following monitoring requirements shall be used to determine compliance with applicable requirements and emission limits. Any sampling, whether by portable analyzer or EPA reference method, that measures an emission rate over the applicable averaging period greater than an emission limit in this permit constitutes noncompliance with this permit. The Department may require, at its discretion, additional tests pursuant to EPA Reference Methods at any time, including when sampling by portable analyzer measures an emission rate greater than an emission limit in this permit; but such requirement shall not be construed as a determination that the sampling by portable analyzer does not establish noncompliance with this permit and shall not stay enforcement of such noncompliance based on the sampling by portable analyzer. C. If the emission unit is shutdown at the time when periodic monitoring is due to be completed, the permittee is not required to restart the unit for the sole purpose of conducting the monitoring. Using electronic or written mail, the permittee shall notify the Department's Compliance and Enforcement Section of a delay in emission tests prior to the deadline for completing the tests. Upon recommencing operation, the permittee shall submit pre-test notification(s) to the Department's Compliance and Enforcement Section and shall complete the monitoring. D. The requirement for monitoring during any monitoring period is based on the percentage of time that the unit has operated. However, to invoke the monitoring period exemption at B108.D(2), hours of operation shall be monitored and recorded. (1) If the emission unit has operated for more than 25% of a monitoring period, then the permittee shall conduct monitoring during that period. EPA Inspection Report - Page 957 of 1969 (2) If the emission unit has operated for 25% or less of a monitoring period then the monitoring is not required. After two successive periods without monitoring, the permittee shall conduct monitoring during the next period regardless of the time operated during that period, except that for any monitoring period in which a unit has operated for less than 10% of the monitoring period, the period will not be considered as one of the two successive periods. (3) If invoking the monitoring period exemption in B108.D(2), the actual operating time of a unit shall not exceed the monitoring period required by this permit before the required monitoring is performed. For example, if the monitoring period is annual, the operating hours of the unit shall not exceed 8760 hours before monitoring is conducted. Regardless of the time that a unit actually operates, a minimum of one of each type of monitoring activity shall be conducted during any five-year period. E. For all periodic monitoring events, except when a federal or state regulation is more stringent, three test runs shall be conducted at 90% or greater of the unit's capacity as stated in this permit, or in the permit application if not in the permit, and at additional loads when requested by the Department. If the 90% capacity cannot be achieved, the monitoring will be conducted at the maximum achievable load under prevailing operating conditions except when a federal or state regulation requires more restrictive test conditions. The load and the parameters used to calculate it shall be recorded to document operating conditions and shall be included with the monitoring report. F. When requested by the Department, the permittee shall provide schedules of testing and monitoring activities. Compliance tests from previous NSR and Title V permits may be re-imposed if it is deemed necessary by the Department to determine whether the source is in compliance with applicable regulations or permit conditions. G. If monitoring is new or is in addition to monitoring imposed by an existing applicable requirement, it shall become effective 120 days after the date of permit issuance. For emission units that have not commenced operation, the associated new or additional monitoring shall not apply until 120 days after the units commence operation. All preexisting monitoring requirements incorporated in this permit shall continue to apply from the date of permit issuance. B109 General Recordkeeping Requirements A. The permittee shall maintain records to assure and verify compliance with the terms and conditions of this permit and any other applicable requirements that become effective after permit issuance. The minimum information to be included in these records is as follows: (1) Records required for testing and sampling: EPA Inspection Report - Page 958 of 1969 (a) equipment identification (include make, model and serial number for all tested equipment and emission controls) (b) date(s) and time(s) of sampling or measurements (c) date(s) analyses were performed (d) the qualified entity that performed the analyses (e) analytical or test methods used (f) results of analyses or tests (g) operating conditions existing at the time of sampling or measurement (2) Records required for equipment inspections and/or maintenance required by this permit: (a) equipment identification number (including make, model and serial number) (b) date(s) and time(s) of inspection, maintenance, and/or repair (c) date(s) any subsequent analyses were performed (if applicable) (d) name of the person or qualified entity conducting the inspection, maintenance, and/or repair (e) copy of the equipment manufacturer's or the owner or operator's maintenance or repair recommendations (if required to demonstrate compliance with a permit condition) (f) description of maintenance or repair activities conducted (g) all results of any required parameter readings (h) a description of the physical condition of the equipment as found during any required inspection (i) results of required equipment inspections including a description of any condition which required adjustment to bring the equipment back into compliance and a description of the required adjustments B. Except as provided in the Specific Conditions, records shall be maintained on-site or at the permittee's local business office for a minimum of two (2) years from the time of recording and shall be made available to Department personnel upon request. Sources subject to 20.2.70 NMAC "Operating Permits" shall maintain records on-site for a minimum of five (5) years from the time of recording. EPA Inspection Report - Page 959 of 1969 C. Unless otherwise indicated by Specific Conditions, the permittee shall keep the following records for malfunction emissions and routine or predictable emissions during startup, shutdown, and scheduled maintenance (SSM): (1) The owner or operator of a source subject to a permit shall establish and implement a plan to minimize emissions during routine or predictable startup, shutdown, and scheduled maintenance through work practice standards and good air pollution control practices. This requirement shall not apply to any affected facility defined in and subject to an emissions standard and an equivalent plan under 40 CFR Part 60 (NSPS), 40 CFR Part 63 (MACT), or an equivalent plan under 20.2.72 NMAC - Construction Permits, 20.2.70 NMAC - Operating Permits, 20.2.74 NMAC Permits - Prevention of Significant Deterioration (PSD), or 20.2.79 NMAC Permits - Nonattainment Areas. The permittee shall keep records of all sources subject to the plan to minimize emissions during routine or predictable SSM and shall record if the source is subject to an alternative plan and therefore, not subject to the plan requirements under 20.2.7.14.A NMAC. (2) If the facility has allowable SSM emission limits in this permit, the permittee shall record all SSM events, including the date, the start time, the end time, a description of the event, and a description of the cause of the event. This record also shall include a copy of the manufacturer's, or equivalent, documentation showing that any maintenance qualified as scheduled. Scheduled maintenance is an activity that occurs at an established frequency pursuant to a written protocol published by the manufacturer or other reliable source. The authorization of allowable SSM emissions does not supersede any applicable federal or state standard. The most stringent requirement applies. (3) If the facility has allowable malfunction emission limits in this permit, the permittee shall record all malfunction events to be applied against these limits. The permittee shall also include the date, the start time, the end time, and a description of the event. Malfunction means any sudden and unavoidable failure of air pollution control equipment or process equipment beyond the control of the owner or operator, including malfunction during startup or shutdown. A failure that is caused entirely or in part by poor maintenance, careless operation, or any other preventable equipment breakdown shall not be considered a malfunction. (20.2.7.7.E NMAC) The authorization of allowable malfunction emissions does not supersede any applicable federal or state standard. The most stringent requirement applies. This authorization only allows the permittee to avoid submitting reports under 20.2.7 NMAC for total annual emissions that are below the authorized malfunction emission limit. (4) The owner or operator of a source shall meet the operational plan defining the measures to be taken to mitigate source emissions during malfunction, startup or shutdown. (20.2.72.203.A(5) NMAC) EPA Inspection Report - Page 960 of 1969 B110 General Reporting Requirements (20.2.72 NMAC Sections 210 and 212) A. Records and reports shall be maintained on-site or at the permittee's local business office unless specifically required to be submitted to the Department or EPA by another condition of this permit or by a state or federal regulation. Records for unmanned sites may be kept at the nearest business office. B. The permittee shall notify the Department's Compliance Reporting Section using the current Submittal Form posted to NMED's Air Quality web site under Compliance and Enforcement/Submittal Forms in writing of, or provide the Department with (20.2.72.212.A and B): (1) the anticipated date of initial startup of each new or modified source not less than thirty (30) days prior to the date. Notification may occur prior to issuance of the permit, but actual startup shall not occur earlier than the permit issuance date; (2) after receiving authority to construct, the equipment serial number as provided by the manufacturer or permanently affixed if shop-built and the actual date of initial startup of each new or modified source within fifteen (15) days after the startup date; and (3) the date when each new or modified emission source reaches the maximum production rate at which it will operate within fifteen (15) days after that date. C. The permittee shall notify the Department's Permitting Program Manager, in writing of, or provide the Department with (20.2.72.212.C and D): (1) any change of operators or any equipment substitutions within fifteen (15) days of such change; (2) any necessary update or correction no more than sixty (60) days after the operator knows or should have known of the condition necessitating the update or correction of the permit. D. Results of emission tests and monitoring for each pollutant (except opacity) shall be reported in pounds per hour (unless otherwise specified) and tons per year. Opacity shall be reported in percent. The number of significant figures corresponding to the full accuracy inherent in the testing instrument or Method test used to obtain the data shall be used to calculate and report test results in accordance with 20.2.1.116.B and C NMAC. Upon request by the Department, CEMS and other tabular data shall be submitted in editable, MS Excel format. E. The permittee shall submit reports of excess emissions in accordance with 20.2.7.110.A NMAC. EPA Inspection Report - Page 961 of 1969 B111 General Testing Requirements A. Compliance Tests (1) Compliance test requirements from previous permits (if any) are still in effect, unless the tests have been satisfactorily completed. Compliance tests may be reimposed if it is deemed necessary by the Department to determine whether the source is in compliance with applicable regulations or permit conditions. (20.2.72 NMAC Sections 210.C and 213) (2) Compliance tests shall be conducted within sixty (60) days after the unit(s) achieve the maximum normal production rate. If the maximum normal production rate does not occur within one hundred twenty (120) days of source startup, then the tests must be conducted no later than one hundred eighty (180) days after initial startup of the source. (3) Unless otherwise indicated by Specific Conditions or regulatory requirements, the default time period for each test run shall be at least 60 minutes and each performance test shall consist of three separate runs using the applicable test method. For the purpose of determining compliance with an applicable emission limit, the arithmetic mean of results of the three runs shall apply. In the event that a sample is accidentally lost or conditions occur in which one of the three runs must be discontinued because of forced shutdown, failure of an irreplaceable portion of the sample train, extreme meteorological conditions, or other circumstances, beyond the owner or operator's control, compliance may, upon the Department approval, be determined using the arithmetic mean of the results of the two other runs. (4) Testing of emissions shall be conducted with the emissions unit operating at 90 to 100 percent of the maximum operating rate allowed by the permit. If it is not possible to test at that rate, the source may test at a lower operating rate, subject to the approval of the Department. (5) Testing performed at less than 90 percent of permitted capacity will limit emission unit operation to 110 percent of the tested capacity until a new test is conducted. (6) If conditions change such that unit operation above 110 percent of tested capacity is possible, the source must submit a protocol to the Department within 30 days of such change to conduct a new emissions test. B. EPA Reference Method Tests (1) All compliance tests required by this permit, unless otherwise specified by Specific Conditions of this permit, shall be conducted in accordance with the requirements of CFR Title 40, Part 60, Subpart A, General Provisions, and the following EPA Reference Methods as specified by CFR Title 40, Part 60, Appendix A: (a) Methods 1 through 4 for stack gas flowrate EPA Inspection Report - Page 962 of 1969 (b) Method 5 for TSP (c) Method 6C and 19 for SO2 (d) Method 7E for NOX (test results shall be expressed as nitrogen dioxide (NO2) using a molecular weight of 46 lb/lb-mol in all calculations (each ppm of NO/NO2 is equivalent to 1.194 x 10-7 lb/SCF) (e) Method 9 for opacity (f) Method 10 for CO (g) Method 19 may be used in lieu of Methods 1-4 for stack gas flowrate upon approval of the Department. A justification for this proposal must be provided along with a contemporaneous fuel gas analysis (preferably on the day of the test) and a recent fuel flow meter calibration certificate (within the most recent quarter). (h) Method 7E or 20 for Turbines per 60.335 or 60.4400 (i) Method 29 for Metals (j) Method 201A for filterable PM10 and PM2.5 (k) Method 202 for condensable PM (l) Method 320 for organic Hazardous Air Pollutants (HAPs) (m) Method 25A for VOC reduction efficiency (n) Method 30B for Mercury (2) Alternative test method(s) may be used if the Department approves the change C. Periodic Monitoring and Portable Analyzer Requirements (1) Periodic emissions tests (periodic monitoring) may be conducted in accordance with EPA Reference Methods or by utilizing a portable analyzer. Periodic monitoring utilizing a portable analyzer shall be conducted in accordance with the requirements of the current version of ASTM D 6522. However, if a facility has met a previously approved Department criterion for portable analyzers, the analyzer may be operated in accordance with that criterion until it is replaced. (2) Unless otherwise indicated by Specific Conditions or regulatory requirements, the default time period for each test run shall be at least 20 minutes. Each performance test shall consist of three separate runs. The arithmetic mean of results of the three runs shall be used to determine compliance with the applicable emission limit. (3) Testing of emissions shall be conducted in accordance with the requirements at Section B108.E. EPA Inspection Report - Page 963 of 1969 (4) During emissions tests, pollutant and diluent concentration shall be monitored and recorded. Fuel flow rate shall be monitored and recorded if stack gas flow rate is determined utilizing Method 19. This information shall be included with the test report furnished to the Department. (5) Stack gas flow rate shall be calculated in accordance with 40 CFR 60, Appendix A, Method 19 utilizing fuel flow rate (scf) determined by a dedicated fuel flow meter and fuel heating value (Btu/scf) determined from a fuel sample obtained preferably during the day of the test, but no earlier than three months prior to the test date. Alternatively, stack gas flow rate may be determined by using EPA Methods 1-4. D. Test Procedures: (1) The permittee shall notify the Department's Program Manager, Compliance and Enforcement Section at least thirty (30) days before the test date and allow a representative of the Department to be present at the test. (2) Equipment shall be tested in the "as found" condition. Equipment may not be adjusted or tuned prior to any test for the purpose of lowering emissions, and then returned to previous settings or operating conditions after the test is complete. (3) Contents of test notifications, protocols and test reports shall conform to the format specified by the Department's Universal Test Notification, Protocol and Report Form and Instructions. Current forms and instructions are posted to NMED's Air Quality web site under Compliance and Enforcement Testing. (4) The permittee shall provide (a) sampling ports adequate for the test methods applicable to the facility, (b) safe sampling platforms, (c) safe access to sampling platforms and (d) utilities for sampling and testing equipment. (5) The stack shall be of sufficient height and diameter and the sample ports shall be located so that a representative test of the emissions can be performed in accordance with the requirements of EPA Method 1 or ASTM D 6522-00 as applicable. (6) Where necessary to prevent cyclonic flow in the stack, flow straighteners shall be installed (7) Unless otherwise indicated by Specific Conditions or regulatory requirements, test reports shall be submitted to the Department no later than 30 days after completion of the test. B112 Compliance A. The Department shall be given the right to enter the facility at all reasonable times to verify the terms and conditions of this permit. Required records shall be organized by date and subject matter and shall at all times be readily available for inspection. The permittee, upon verbal or written request from an authorized representative of the Department who appears at the facility, shall immediately produce for inspection or EPA Inspection Report - Page 964 of 1969 copying any records required to be maintained at the facility. Upon written request at other times, the permittee shall deliver to the Department paper or electronic copies of any and all required records maintained on site or at an off-site location. Requested records shall be copied and delivered at the permittee's expense within three business days from receipt of request unless the Department allows additional time. Required records may include records required by permit and other information necessary to demonstrate compliance with terms and conditions of this permit. (NMSA 1978, Section 74-2-13) B. A copy of the most recent permit(s) issued by the Department shall be kept at the permitted facility or (for unmanned sites) at the nearest company office and shall be made available to Department personnel for inspection upon request. (20.2.72.210.B.4 NMAC) C. Emissions limits associated with the energy input of a Unit, i.e. lb/MMBtu, shall apply at all times unless stated otherwise in a Specific Condition of this permit. The averaging time for each emissions limit, including those based on energy input of a Unit (i.e. lb/MMBtu) is one (1) hour unless stated otherwise in a Specific Condition of this permit or in the applicable requirement that establishes the limit. B113 Permit Cancellation and Revocation A. The Department may revoke this permit if the applicant or permittee has knowingly and willfully misrepresented a material fact in the application for the permit. Revocation will be made in writing, and an administrative appeal may be taken to the Secretary of the Department within thirty (30) days. Appeals will be handled in accordance with the Department's Rules Governing Appeals From Compliance Orders. B. The Department shall automatically cancel any permit for any source which ceases operation for five (5) years or more, or permanently. Reactivation of any source after the five (5) year period shall require a new permit. (20.2.72 NMAC) C. The Department may cancel a permit if the construction or modification is not commenced within two (2) years from the date of issuance or if, during the construction or modification, work is suspended for a total of one (1) year. (20.2.72 NMAC) B114 Notification to Subsequent Owners A. The permit and conditions apply in the event of any change in control or ownership of the Facility. No permit modification is required in such case. However, in the event of any such change in control or ownership, the permittee shall notify the succeeding owner of the permit and conditions and shall notify the Department's Program Manager, Permits Section of the change in ownership within fifteen (15) days of that change. (20.2.72.212.C NMAC) EPA Inspection Report - Page 965 of 1969 B. Any new owner or operator shall notify the Department's Program Manager, Permits Section, within thirty (30) days of assuming ownership, of the new owner's or operator's name and address. (20.2.73.200.E.3 NMAC) B115 Asbestos Demolition A. Before any asbestos demolition or renovation work, the permittee shall determine whether 40 CFR 61 Subpart M, National Emissions Standards for Asbestos applies. If required, the permittee shall notify the Department's Program Manager, Compliance and Enforcement Section using forms furnished by the Department. B116 Short Term Engine Replacement A. The following Alternative Operating Scenario (AOS) addresses engine breakdown or periodic maintenance and repair, which requires the use of a short term replacement engine. The following requirements do not apply to engines that are exempt per 20.2.72.202.B(3) NMAC. Changes to exempt engines must be reported in accordance with 20.2.72.202.B NMAC. A short term replacement engine may be substituted for any engine allowed by this permit for no more than 120 days in any rolling twelve month period per permitted engine. The compliance demonstrations required as part of this AOS are in addition to any other compliance demonstrations required by this permit. (1) The permittee may temporarily replace an existing engine that is subject to the emission limits set forth in this permit with another engine regardless of manufacturer, model, and horsepower without modifying this permit. The permittee shall submit written notification to the Department within 15 days of the date of engine substitution according to condition B110.C(1). (a) The potential emission rates of the replacement engine shall be determined using the replacement engine's manufacturer specifications and shall comply with the existing engine's permitted emission limits. (b) The direction of the exhaust stack for the replacement engine shall be either vertical or the same direction as for the existing engine. The replacement engine's stack height and flow parameters shall be at least as effective in the dispersion of air pollutants as the modeled stack height and flow parameters for the existing permitted engine. The following equation may be used to show that the replacement engine disperses pollutants as well as the existing engine. The value calculated for the replacement engine on the right side of the equation shall be equal to or greater than the value for the existing engine on the left side of the equation. The permitting page of the Air Quality Bureau website contains a spreadsheet that performs this calculation. EPA Inspection Report - Page 966 of 1969 EXISTING ENGINE REPLACMENT ENGINE [(g) x (h1)] + [(v1)2/2] + [(c) x (T1)] <= [(g) x (h2)] + [(v2)2/2] + [(c) x (T2)] q1 q2 Where g = gravitational constant = 32.2 ft/sec2 h1 = existing stack height, feet v1 = exhaust velocity, existing engine, feet per second c = specific heat of exhaust, 0.28 BTU/lb-degree F T1 = absolute temperature of exhaust, existing engine = degree F + 460 q1 = permitted allowable emission rate, existing engine, lbs/hour h2 = replacement stack height, feet v2 = exhaust velocity, replacement engine, feet per second T2 = absolute temperature of exhaust, replacement engine = degree F + 460 q2 = manufacturer's potential emission rate, replacement engine, lbs/hour The permittee shall keep records showing that the replacement engine is at least as effective in the dispersion of air pollutants as the existing engine. (c) Test measurement of NOx and CO emissions from the temporary replacement engine shall be performed in accordance with Section B111 with the exception of Condition B111A(2) and B111B for EPA Reference Methods Tests or Section B111C for portable analyzer test measurements. Compliance test(s) shall be conducted within fifteen (15) days after the unit begins operation, and records of the results shall be kept according to section B109.B. This test shall be performed even if the engine is removed prior to 15 days on site. i. These compliance tests are not required for an engine certified under 40CFR60, subparts IIII, or JJJJ, or 40CFR63, subpart ZZZZ if the permittee demonstrates that one of these requirements causes such engine to comply with all emission limits of this permit. The permittee shall submit this demonstration to the Department within 48 hours of placing the new unit into operation. This submittal shall include documentation that the engine is certified, that the engine is within its useful life, as defined and specified in the applicable requirement, and shall include calculations showing that the applicable emissions standards result in compliance with the permit limits. ii. These compliance tests are not required if a test was conducted by portable analyzer or by EPA Method test (including any required by 40CFR60, subparts IIII and JJJJ and 40CFR63, subpart ZZZZ) within the last 12 months. These previous tests are valid only if EPA Inspection Report - Page 967 of 1969 conducted at the same or lower elevation as the existing engine location prior to commencing operation as a temporary replacement. A copy of the test results shall be kept according to section B109.B. (d) Compliance tests for NOx and CO shall be conducted if requested by the Department in writing to determine whether the replacement engine is in compliance with applicable regulations or permit conditions. (e) Upon determining that emissions data developed according to B116.A.1(c) fail to indicate compliance with either the NOx or CO emission limits, the permittee shall notify the Department within 48 hours. Also within that time, the permittee shall implement one of the following corrective actions: i. The engine shall be adjusted to reduce NOx and CO emissions and tested per B116.A.1(c) to demonstrate compliance with permit limits. ii. The engine shall discontinue operation or be replaced with a different unit. (2) Short term replacement engines, whether of the same manufacturer, model, and horsepower, or of a different manufacturer, model, or horsepower, are subject to all federal and state applicable requirements, regardless of whether they are set forth in this permit (including monitoring and recordkeeping), and shall be subject to any shield afforded by this permit. (3) The permittee shall maintain a contemporaneous record documenting the unit number, manufacturer, model number, horsepower, emission factors, emission test results, and serial number of any existing engine that is replaced, and the replacement engine. Additionally, the record shall document the replacement duration in days, and the beginning and end dates of the short term engine replacement. (4) The permittee shall maintain records of a regulatory applicability determination for each replacement engine (including 40CFR60, subparts IIII and JJJJ and 40CFR63, subpart ZZZZ) and shall comply with all associated regulatory requirements. B. Additional requirements for replacement of engines at sources that are major as defined in regulation 20.2.74 NMAC, Permits - Prevention of Significant Deterioration, section 7.AG. For sources that are major under PSD, the total cumulative operating hours of the replacement engine shall be limited using the following procedure: (1) Daily, the actual emissions from the replacement engine(s) of each pollutant regulated by this permit for the existing engine shall be calculated and recorded. (2) The sum of the total actual emissions since the commencement of operation of the replacement engine(s) shall not equal or exceed the significant emission rates in EPA Inspection Report - Page 968 of 1969 Table 2 of 20.2.74 NMAC, section 502 for the time that the replacement engine is located at the facility. C. All records required by this section shall be kept according to section B109. EPA Inspection Report - Page 969 of 1969 PART C MISCELLANEOUS C100 Supporting On-Line Documents A. Copies of the following documents can be downloaded from NMED's web site under Compliance and Enforcement or requested from the Bureau. (1) Excess Emission Form (for reporting deviations and emergencies) (2) Universal Stack Test Notification, Protocol and Report Form and Instructions (3) SOP for Use of Portable Analyzers in Performance Tests C101 Definitions A. "Daylight" is defined as the time period between sunrise and sunset, as defined by the Astronomical Applications Department of the U.S. Naval Observatory. (Data for one day or a table of sunrise/sunset for an entire year can be obtained at http://aa.usno.navy.mil/. Alternatively, these times can be obtained from a Farmer's Almanac or from http://www.almanac.com/rise/). B. "Exempt Sources" and "Exempt Activities" is defined as those sources or activities that are exempted in accordance with 20.2.72.202 NMAC. Note; exemptions are only valid for most 20.2.72 NMAC permitting actions. C. "Fugitive Emission" means those emissions which could not reasonably pass through a stack, chimney, vent, or other functionally equivalent opening. D. "Insignificant Activities" means those activities which have been listed by the department and approved by the administrator as insignificant on the basis of size, emissions or production rate. Note; insignificant activities are only valid for 20.2.70 NMAC permitting actions. E. "Malfunction" for the requirements under 20.2.7 NMAC, means any sudden and unavoidable failure of air pollution control equipment or process equipment beyond the control of the owner or operator, including malfunction during startup or shutdown. A failure that is caused entirely or in part by poor maintenance, careless operation, or any other preventable equipment breakdown shall not be considered a malfunction. (20.2.7.7.E NMAC) F. "Natural Gas" is defined as a naturally occurring fluid mixture of hydrocarbons that contains 20.0 grains or less of total sulfur per 100 standard cubic feet (SCF) and is either composed of at least 70% methane by volume or has a gross calorific value of between 950 and 1100 Btu per standard cubic foot. (40 CFR 60.631) EPA Inspection Report - Page 970 of 1969 G. "Natural Gas Liquids" means the hydrocarbons, such as ethane, propane, butane, and pentane, that are extracted from field gas. (40 CFR 60.631) H. "National Ambient air Quality Standards" means, unless otherwise modified, the primary (health-related) and secondary (welfare-based) federal ambient air quality standards promulgated by the US EPA pursuant to Section 109 of the Federal Act. I. "Night" is the time period between sunset and sunrise, as defined by the Astronomical Applications Department of the U.S. Naval Observatory. (Data for one day or a table of sunrise/sunset for an entire year can be obtained at http://aa.usno.navy.mil/. Alternatively, these times can be obtained from a Farmer's Almanac or from http://www.almanac.com/rise/). J. "Night Operation or Operation at Night" is operating a source of emissions at night. K. "NO2" or "Nitrogen dioxide" means the chemical compound containing one atom of nitrogen and two atoms of oxygen, for the purposes of ambient determinations. The term "nitrogen dioxide," for the purposes of stack emissions monitoring, shall include nitrogen dioxide (the chemical compound containing one atom of nitrogen and two atoms of oxygen), nitric oxide (the chemical compound containing one atom of nitrogen and one atom of oxygen), and other oxides of nitrogen which may test as nitrogen dioxide and is sometimes referred to as NOx or NO2. (20.2.2 NMAC) L. "NOx" see NO2 M. "Paved Road" is a road with a permanent solid surface that can be swept essentially free of dust or other material to reduce air re-entrainment of particulate matter. To the extent these surfaces remain solid and contiguous they qualify as paved roads: concrete, asphalt, chip seal, recycled asphalt and other surfaces approved by the Department in writing. N. "Potential Emission Rate" means the emission rate of a source at its maximum capacity to emit a regulated air contaminant under its physical and operational design, provided any physical or operational limitation on the capacity of the source to emit a regulated air contaminant, including air pollution control equipment and restrictions on hours of operation or on the type or amount of material combusted, stored or processed, shall be treated as part of its physical and operational design only if the limitation or the effect it would have on emissions is enforceable by the department pursuant to the Air Quality Control Act or the federal Act. O. "Restricted Area" is an area to which public entry is effectively precluded. Effective barriers include continuous fencing, continuous walls, or other continuous barriers approved by the Department, such as rugged physical terrain with a steep grade that would require special equipment to traverse. If a large property is completely enclosed EPA Inspection Report - Page 971 of 1969 by fencing, a restricted area within the property may be identified with signage only. Public roads cannot be part of a Restricted Area. P. "Shutdown" for requirements under 20.2.72 NMAC, means the cessation of operation of any air pollution control equipment, process equipment or process for any purpose, except routine phasing out of batch process units. Q. "SSM" for requirements under 20.2.7 NMAC, means routine or predictable startup, shutdown, or scheduled maintenance. (1) "Shutdown" for requirements under 20.2.7 NMAC, means the cessation of operation of any air pollution control equipment or process equipment. (2) "Startup" for requirements under 20.2.7 NMAC, means the setting into operation of any air pollution control equipment or process equipment. R. "Startup" for requirements under 20.2.72 NMAC, means the setting into operation of any air pollution control equipment, process equipment or process for any purpose, except routine phasing in of batch process units. C102 Acronyms 2SLB ........................................................................................................ 2-stroke lean burn 4SLB ........................................................................................................ 4-stroke lean burn 4SRB ......................................................................................................... 4-stroke rich burn acfm........................................................................................... actual cubic feet per minute AFR....................................................................................................................air fuel ratio AP-42 ...........................................................................EPA Air Pollutant Emission Factors AQB ........................................................................................................Air Quality Bureau AQCR ....................................................................................... Air Quality Control Region ASTM ............................................................. American Society for Testing and Materials Btu ......................................................................................................... British thermal unit CAA .............................................................Clean Air Act of 1970 and 1990 Amendments CEM ................................................................................. continuous emissions monitoring cfh ........................................................................................................... cubic feet per hour cfm .......................................................................................................cubic feet per minute CFR ........................................................................................... Code of Federal Regulation CI ........................................................................................................ compression ignition CO ............................................................................................................ carbon monoxides COMS ...................................................................... continuous opacity monitoring system EIB ............................................................................... Environmental Improvement Board EPA .......................................................... United States Environmental Protection Agency gr/100 cf ........................................................................... grains per one hundred cubic feet gr/dscf ..............................................................................grains per dry standard cubic foot GRI.....................................................................................................Gas Research Institute EPA Inspection Report - Page 972 of 1969 HAP................................................................................................... hazardous air pollutant hp ....................................................................................................................... horsepower H2S ..............................................................................................................hydrogen sulfide IC ..........................................................................................................internal combustion KW/hr ...................................................................................................... kilowatts per hour lb/hr ..............................................................................................................pounds per hour lb/MMBtu ............................................................... pounds per million British thermal unit MACT ............................................................. Maximum Achievable Control Technology MMcf/hr ...................................................................................... million cubic feet per hour MMscf.........................................................................................million standard cubic feet N/A.................................................................................................................. not applicable NAAQS.................................................................National Ambient Air Quality Standards NESHAP ................................. National Emission Standards for Hazardous Air Pollutants NG ....................................................................................................................... natural gas NGL ......................................................................................................... natural gas liquids NMAAQS ......................................................New Mexico Ambient Air Quality Standards NMAC............................................................................ New Mexico Administrative Code NMED..................................................................... New Mexico Environment Department NMSA .................................................................................New Mexico Statues Annotated NOx...............................................................................................................nitrogen oxides NSCR .................................................................................non-selective catalytic reduction NSPS ............................................................................. New Source Performance Standard NSR.......................................................................................................New Source Review PEM .................................................................................. parametric emissions monitoring PM................................ particulate matter (equivalent to TSP, total suspended particulate) PM10 .......................................................particulate matter 10 microns and less in diameter PM2.5 .....................................................particulate matter 2.5 microns and less in diameter pph................................................................................................................pounds per hour ppmv ......................................................................................... parts per million by volume PSD ......................................................................... Prevention of Significant Deterioration RATA........................................................................... Relative Accuracy Test Assessment RICE .................................................................... reciprocating internal combustion engine rpm .................................................................................................... revolutions per minute scfm....................................................................................... standard cubic feet per minute SI ................................................................................................................... spark ignition SO2 .................................................................................................................. sulfur dioxide SSM...................................................Startup Shutdown Maintenance (see SSM definition) TAP ........................................................................................................ Toxic Air Pollutant TBD.............................................................................................................to be determined THC..........................................................................................................total hydrocarbons TSP.......................................................................................... Total Suspended Particulates tpy ..................................................................................................................... tons per year ULSD ..................................................................................................ultra low sulfur diesel USEPA ..................................................... United States Environmental Protection Agency EPA Inspection Report - Page 973 of 1969 UTM......................................................Universal Transverse Mercator Coordinate system UTMH................................................................Universal Transverse Mercator Horizontal UTMV....................................................................Universal Transverse Mercator Vertical VHAP...................................................................................volatile hazardous air pollutant VOC .......................................................................................... volatile organic compounds EPA Inspection Report - Page 974 of 1969 2334562758983 57924 75748327593 57983 3 579 2 7924 !"$% &'(*'+,-./01,2.03'045'67243'04 89:;<=>9!; ?@?A;B$"!<$CD;9E!FG!H ;B;I!GJDKL?M? N9!O;9!"P$9% Q24'R,7S'T,0'2U V.WWUX2.04,'2&717Y.S'T,0,0Z[[\ ?MH];CD;B9!! 89!C;G]""=A$B=GJ!^D!_`$ 8a!B`=bB!9!CJ$cHdK N9!O;9!"=% e7R-.R7QWW,70-'\.3670U fdH?A9$CCA9!!gA$9 89<Ba $BGh!_;CLiMHL KHLcL@icidfd h;C`$C;N9$j!`J$%HMKkHH *7Ulmno EPA Inspection Report - Page 975 of 1969 ;<=>?@ABC ;EFGHIJKLMMNH= OHEPQRRQSTJHKRQMSULQHV?WQEXY<NQR=ZYEH<Y [H\;H]QKM^S_QEMSPHSR`Ha<ERPHSR UHERQVQHI;<QNbcHRYEScHKHQaR[MF d@dU<PQSMIHNMe;<EfYHg?JYQRHB hABijiCAAAAA>@>Cdj>C J<SR<kH?[;lhdAd mno qrstnuvwnxysrz{|nx}rs~|m wwtrysrzx|nx}rsmnznyt ttxzsrnx~yymnrzrz{ xsnrymnrznx {nzzsnxns~ `H<E;EFJKLMMNH=? MNN=kEMSRQHE[<_<McHVQSQSTU[<_<MQeeYPQRRQSTRLQe<aaNQK<RQMSVMEEHSH\<NMVRLHKYEEHSR GQRNHaHE<RQSTOHEPQR[MFOAdBc@;BVME[<_<MeWERHeQ<?[;EHVQSHE=F[<_<MQeeYPQRRQSTRLQe <aaNQK<RQMSQS<KKMEI<SKH\QRL@AF@FhAFjAA[;WUFGLH[H\;H]QKM^S_QEMSPHSR`Ha<ERPHSR[;^` N<eRQeeYHIbEHSH\HIRLHGQRNHaHEPQRMS;<=>?@ABdFRL<e<VQ_H=H<ERHEP?<SIRLHEHVMEHH]aQEHe;<= >?@A@AFS<KKMEI<SKH\QRL@AF@FhAFjAAFZF@[;WU?RLQeEHSH\<N<aaNQK<RQMSQeHQSTeYPQRRHI<R NH<eRR\HN_HPMSRLeaEQMERMRLHH]aQE<RQMSI<RHQFHF?=;<=>?@ABCF Z=RLQeeYPQRR<N?[<_<MEHfYHeReRLH[;^`EHSH\<SIYaI<RHRLHGQRNHaHEPQRRMEHVNHKRRLHGQRNH <SI[H\JMYEKHcH_QH\[JcaHEPQRRQST<KRQMSeRL<RL<_HHHS<aaEM_HI=[;^`eQSKHRLHN<eRGQRNH aHEPQRQeeY<SKHbEHSH\<NFkMEEHVHEHSKH?RLHKYEEHSR[JcaHEPQRVMERLHWERHeQ<cHVQSHE=Qe[JcOHEPQR [MFOJ`[;ABCd;jhcjFS<IIQRQMS?[<_<MEHfYHeRe[;^`YaI<RHRLHGQRNHaHEPQRRMEHVNHKR EHTYN<RME=YaI<RHe<SIKL<STHeeQSKHRLHN<eRGQRNHaHEPQRQeeY<SKHbEHSH\<NFGLHeHaHEPQRRQST<KRQMSe <SIEHTYN<RME=YaI<RHe<EHeYPP<EQgHIHNM\F S<IIQRQMSRMRLQeKM_HENHRRHE?RLH<aaNQK<RQMSQSKNYIHeRLHVMNNM\QST<RR<KLPHSRe ssy}nzswwtrysrzx}qytnzsnzs~x}yzwwtn}nzsytzx}ysrz WIHR<QNHIG<NHMVUMSRHSReVMERLH<aaNQK<RQMSVMEPQeaEM_QIHI<RRLHHTQSSQSTMVWRR<KLPHSRBFRQe VMNNM\HI=RLH<aaNQK<RQMSVMEP\QRLeYaaNHPHSR<NQSVMEP<RQMSQSeHERHI\LHEH<aaNQK<NHFGLHIHR<QNHI G<NHMVUMSRHSReH]a<SIeRLHG<NHMVUMSRHSReQSKNYIHIQSRLH[;^`SQ_HEe<NWQEXY<NQR=OHEPQR WaaNQK<RQMSVMEPHSIMVJHKRQMSBMV<aaNQK<RQMSVMEPFJYaaNHPHSR<NQSVMEP<RQMSQSKNYIHeHPQeeQMS K<NKYN<RQMSeHSIMVJHKRQMS><SIEHTYN<RME=<aaNQK<QNQR=R<NHeHSIMVJHKRQMSBjRL<R\HEHaEH_QMYeN= eYPQRRHI<ea<ERMVRLHPMeREHKHSR[JcaHEPQRRQST<KRQMSeF ssy}nzsyxwxxnzsqrstnuvwnxysrz{|nx}rs~|mGMV<KQNQR<RHRLHKL<STHe RMRLHaHEPQR?[<_<MQeaEM_QIQST<SHNHKREMSQKP<EYaMVRLHaHEPQR\QRLRLHEHfYHeRHIKL<STHeQS;J GE<KUL<STHeF [<_<MEHfYHeReRLH[;^`YaI<RHRLHGQRNHaHEPQRRMEHVNHKRRLHVMNNM\QST[;^`<aaEM_HIaHEPQRRQST <KRQMSe<eEHaH<RHIQSJHKRQMSjMVRLH<aaNQK<RQMSVMEP 123345627896 2 9797 !"#$%&&' ()*)+&,--./0112223.45567"4#"3849 EPA Inspection Report - Page 976 of 1969 012456789 5 505815515 0  5! 2\]^_`a_bcde_afghfjklamnopmqrostnu`]hvwxtntyrsmrtz{h{ztyt|n_}9~ ~155~566015691!15~~~!1 51 5~~~55185~9891555!18~185115155~51 2222}202~15!585695845}95~585~155 6 204765551 6 202 495~55~~~6958515155~655958151!045 ~!8822529555 15955151! 1556249515!15915~58954551895~15151562 2\]^_`a_bcde_afgho{ysoq|mwtnuhmqm|s|xoyrt|nntr`]h{qntqm h{ztyt|n_}9~~ 155~566015691!1 5~~~!19566! 1 ~4~51581 6585!1951568!5~~~55156955~5~418 684 6811!15~5618 69196811515~5~24954 816585~~56~515816585955~ 15851 4989~515~~951 18165852915~589545519~ 518515!5856~895~95!~8656955581851 1865699~8615!515856895 51862 4524 5~~~!1158 452 10596~ 51862 518625758!85155~!1 68~ 452 5~~~ 452~~~!15!51 ~7185~! 51 8 6~~ 2\]^_`a_bcde_afghc]{sz{smqo{n{smr|smnw\s|mn{^sn{yy{yrtnu`]h vwxtntyrsmrtz{h{ztyt|n_}9~~ 155~5660156 91!15~~~!15~1856589891555!1 8~185115155~512222}02 ~15!585695845}9558~1515~~45~ 2 474265~958515155~655~958151!0 ~!8822529~55 15955151! 1556249515!15915~58954551895~1515156!1 4742 ~15!585695845}955~185~9575151}85511 22~~5815718551!1 85761671 77610 895514589 71 046~9515!1558656!18~651~045~!8 828816915~589545519555515~ 895~95!~8656955581851 1~5699~ 8615!515856895 51862 4524 5~~~!1158 518626} 4527 185~ "#$$%&'#()*+'-./.0#1+2*(*(3445 678:;<=>;?@ABC=D<?;EF>GGH87 I6J6KJLGMNN88AO==PQRRSSSTOUVVWXCU@=?DCTYUZ EPA Inspection Report - Page 977 of 1969 012456789 5 505815515 0  5!" \4^5_2`ab5c567c185ded \4^52`` ^5dded _2ghijkljmnopjlqrituvwwxtytz{g|v}tzwkh~hyzyw~tvyj9ddc^ 15c5d5660156c91"15ddd"1185dd5c5 6"8d815d516c895"cda \ 996165dc"c1 \ ! 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Page 990 of 1969 Delayed Repairs Report HollyFrontier Artesia From: 9/1/2019 To: 10/3/2019, All Records Tag: Unit: 29082000 Unit: 1366-000 Date Delayed: Expected Date of Repair: 08-TK-FARM Area: 2/13/2018 12/31/2019 09-N ALKY 8/28/2018 12/1/2019 Area: Due Date: MACT 2/13/2023 09-D-642 8/28/2023 Unit: 1696-000 09-N ALKY 8/23/2018 12/1/2019 Area: NSPS 8/23/2023 1842-000 2/21/2019 12/31/2019 2/21/2024 Unit: 166000000 Unit: 2820-000 10-FCCU 1/29/2019 13-NHD 11/22/2017 Area: 12/31/2019 Area: 12/31/2019 10 D-502 1/29/2024 NSPS 11/22/2022 2898-000 11/22/2017 12/31/2019 11/22/2022 Unit: 77709000 Unit: 2720-000 13-NHD 9/19/2017 30-SRU #2 5/13/2009 Area: 12/31/2019 Area: 12/31/2019 PR SW H-9 9/19/2022 NSPS 5/13/2014 Authorized By: Reason: Equipment: MACT JASON VILLA/ RAYSMALTS REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS Equipment: 09-D-642/643 JASON REYES/ EQUIPMENT IS ISOLATED FROM RAYSMALTS THE PROCESS AND DOES NO Equipment: NSPS JASON REYES/ RAYSMALTS JASON REYES & RAYSMALTS EQUIPMENT IS ISOLATED FROM THE PROCESS AND DOES NO REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS Equipment: 10 D-502 RAY SMALTS / JESUS ACOSTA REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS Equipment: NSPS ROBERT GURROLA/ RAY SMALTS ROBERT GURROLA/ RAY SMALTS REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS Equipment: PR SW H-9 STACI HAMMOND/TIM DUNCAN REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS Equipment: NSPS DANNY PANZER/AARONS TRANGE REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS Repaired?: No No No No No No No No No Page 1 of 3 on 10/3/2019 8:31 :03 AM Printed By: ALeger HFNA-000005928 EPA Inspection Report - Page 991 of 1969 Delayed Repairs Report HollyFrontier Artesia From: 9/1/2019 To: 10/3/2019, All Records Tag: Unit: 20159000 Unit: 3839-000 Unit: 3751-000 Date Delayed: Expected Date of Repair: 31-SRU #3-CVS Area: 10/23/2018 12/31/2019 35-SAT-GAS 1/8/2014 Area: 12/31/2019 35-SAT-GAS 3/26/2015 Area: 12/31/2019 Due Date: H-3101 10/23/2023 E/WPR 1/8/2020 N/S PR 3/26/2020 Unit: 3349-000 3354-000 Unit: 3695-000 35-SAT-GAS 11/24/2018 Area: 12/31/2019 11/24/2018 12/31/2019 35-SAT-GAS 3/26/2015 Area: 12/31/2019 PMP-AllY 11/24/2023 11/24/2023 W-58 3/26/2020 3707-000 3/26/2015 12/31/2019 3/26/2020 Unit: 3655-000 35-SAT-GAS 6/18/2015 Area: 12/31/2019 W-60 6/18/2020 Unit: 3577-000 35-SAT-GAS 3/26/2015 Area: 12/31/2019 X-217 3/26/2020 Authorized By: Reason: Equipment: H-3101 ROBERT GURROLA/ RAY SMALTS REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS Equipment: E/W PR DANNY PANZER/ REPAIR IS TECHNICALLY RAY SMALTS INFEASIBLE WITHOUT A PROCESS Equipment: N/S PR RAY SMALTS/DAVID HAMMOND REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS Equipment: PMP-AllY TODD BARELA/ RAYSMALTS REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS TODD BARELA/ RAYSMALTS REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS Equipment: W-58 RAY SMALTS/DAVID HAMMOND RAY SMALTS /DAVID HAMMOND REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS Equipment: W-60 DAIVD HAMMOND/RAY SMALTS REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS Equipment: X-217 RAY SMALTS/DAVID HAMMOND REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS Repaired?: No No No No No No No No No Page 2 of 3 on 10/3/2019 8:31 :03 AM Printed By: ALeger HFNA-000005929 EPA Inspection Report - Page 992 of 1969 Delayed Repairs Report HollyFrontier Artesia From: 9/1/2019 To: 10/3/2019, All Records Tag: Unit: 4117 A000 4125-000 Unit: 1478-000 Date Delayed: 41-PBC 5/14/2019 5/14/2019 44-DHDU 5/1/2019 Expected Date of Repair: Area: 12/31/2019 Due Date: 41 W-113 5/14/2024 12/31/2019 5/14/2024 Area: 12/31/2019 44 C-421 5/1/2024 1489-000 Unit: 1158-000 5/1/2019 44-DHDU 5/12/2017 12/31/2019 Area: 12/31/2019 5/1/2024 44 D-478 5/12/2022 Authorized By: Reason: Equipment: 41 W-113 TODD BARELA/ RAYSMALTS REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS ROMAN AGULAR/ RAYSMALTS EQUIPMENT IS ISOLATED FROM THE PROCESS AND DOES NO Equipment: 44 C-421 JIM MCFATRIDGE/RAY SMALTS REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS JIM MCFATRIDGE/ RAYSMALTS REPAIR IS TECHNICALLY INFEASIBLE WITHOUT A PROCESS Equipment: 44 D-478 ERIC HARDEN/ RAY SMALTS EQUIPMENT IS ISOLATED FROM THE PROCESS AND DOES NO Repaired?: No No No No No Signature of Owner or Operator Responsible for Delay of Repair Decision Page 3 of 3 on 10/3/2019 8:31 :03 AM Printed By: ALeger HFNA-000005930 EPA Inspection Report - Page 993 of 1969 Inspection History HollyFrontier Artesia From: 1/1/2016 To: 12/31/2019, All Inspections Under NSPS - Wa/GGGa Unit: 30-SRU #2 Area: NSPS Equipment: NSPS Tag: 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 Component Type: Location Description: VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 Page 1 of 3 on 10/2/2019 1:58:18 PM Size: Service: 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR Inspection: Date & Time: 1/11/2016 4:06:46 PM 2/17/2016 2:59:05 PM 3/16/2016 3:35:20 PM 4/5/2016 2:38:28 PM 5/25/2016 9:09:17 AM 7/11/2016 1:34:37 PM 8/3/2016 10:13:53 AM 9/8/2016 10:28:39 AM 10/14/2016 8:17:05AM 11/7/2016 2:36:40 PM 12/21/2016 2:25:16 PM 1/12/2017 9:03:57 AM 2/13/2017 10:28:51 AM 3/24/2017 11:02:28AM 4/25/2017 10:51:38AM 5/31/2017 8:13:57 AM PPM: 814 863 1362 998 742 17 2 262 190 520 677 660 557 6266 4226 4498 DPM: 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Repair: Date & Time: None None None None None None None None None None None None None None None None Rel nspection: Date & Time: None PPM: N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A Printed By: ALeger Applicable Leak Std. PPM: 500 DPM: 1 Taken Out of Service: N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N HFNA-000005890 EPA Inspection Report - Page 994 of 1969 Inspection History HollyFrontier Artesia From: 1/1/2016 To: 12/31/2019, All Inspections Under NSPS - Wa/GGGa Unit: 30-SRU #2 Area: NSPS Equipment: NSPS Tag: 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 Component Type: Location Description: VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 Size: Service: 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR Inspection: Date & Time: 6/2/2017 11 :26:02 AM 6/8/2017 2:54:05 PM 7/26/2017 9:59:13 AM 9/13/2017 2:45:52 PM 10/30/2017 3:21:37 PM 11/7/2017 11:56:37 AM 12/12/2017 9:33:08AM 1/10/2018 3:08:12 PM 2/8/2018 8:52:03 AM 3/9/201811:06:17 AM 4/20/2018 8:40:14 AM 5/15/2018 11:09:03AM 6/11/2018 9:59:04 AM 7/30/2018 11:11:25AM 8/2/2018 9:25:17 AM 9/19/2018 8:00:44 AM PPM: 1401 DPM: 0 16400 0 127700 0 27400 0 4584 0 5964 0 10700 0 30500 0 6694 0 20 0 500000 0 6081 0 6580 0 1922 0 5865 0 7720 0 Repair: Date & Time: None None None None None None None None None None None None None None None None Rel nspection: Date & Time: None PPM: N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A Page 2 of 3 on 10/2/2019 1:58:18 PM Printed By: ALeger Applicable Leak Std. PPM: 500 DPM: 1 Taken Out of Service: N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N HFNA-000005891 EPA Inspection Report - Page 995 of 1969 Inspection History HollyFrontier Artesia From: 1/1/2016 To: 12/31/2019, All Inspections Under NSPS - Wa/GGGa Unit: 30-SRU #2 Area: NSPS Equipment: NSPS Tag: 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 2720-000 Component Type: Location Description: VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE VALVE FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 FG LOOP NW D-469 ORN NW 12.1 Size: Service: 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR 0.75 GASNAPOR Inspection: Date & Time: 10/9/2018 2:05:00 PM 11/2/2018 10:41:52AM 12/10/2018 1:43:46 PM 1/15/2019 11:14:18AM 2/15/2019 11:26:47AM 3/21/2019 1:41 :29 PM 4/15/2019 9:21 :50 AM 5/2/2019 8:46:10 AM 6/10/2019 2:50:37 PM 7/26/2019 7:39:05 AM 8/5/2019 2:24:24 PM 8/29/2019 11:04:24AM 9/18/2019 3:03:39 PM PPM: 8866 DPM: 0 12600 0 4722 0 8617 0 3413 0 2837 0 21300 0 6999 0 559 0 1764 0 720 0 2768 0 602 Repair: Date & Time: None None None None None None None None None None None None None Rel nspection: Date & Time: None PPM: N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A None N/A Applicable Leak Std. PPM: 500 DPM: 1 Taken Out of Service: N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N 500 1 N Page 3 of 3 on 10/2/2019 1:58:18 PM Printed By: ALeger HFNA-000005892 EPA Inspection Report - Page 996 of 1969 2018 API Carbon Canister Monitoring for Month: January Monitoring Date 1-Jan 2-Jan 3-Jan 4-Jan 5-Jan 6-Jan 7-Jan 8-Jan 9-Jan 10-Jan 11-Jan 12-Jan 13-Jan 14-Jan 15-Jan 16-Jan 17-Jan 18-Jan 19-Jan 20-Jan 21-Jan 22-Jan 23-Jan 24-Jan 25-Jan 26-Jan 27-Jan 28-Jan 29-Jan 30-Jan 31-Jan Old System Lead Filter Inlet 137.0 56.0 89.0 12.0 4.0 17.0 245.0 103.0 272.0 90.0 4.0 7.0 6.0 30.0 112.0 61.0 78.0 125.0 455.0 236.0 119.0 126.0 109.0 244.0 390.0 400.0 112.0 233.0 539.0 211.0 340.0 Old System Lead Filter Outlet 10.0 1.0 2.0 3.0 2.0 3.0 2.0 6.0 5.0 6.0 3.0 4.0 4.0 4.0 8.0 5.0 6.0 4.0 2.0 10.0 8.0 4.0 5.0 6.0 7.0 9.0 9.0 10.0 4.0 5.0 8.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 10.0 5.0 1.0 1.0 2.0 1.0 2.0 2.0 2.0 1.0 3.0 3.0 2.0 3.0 4.0 3.0 5.0 3.0 6.0 4.0 3.0 1.0 3.0 3.0 3.0 1.0 4.0 4.0 8.0 5.0 5.0 3.0 6.0 4.0 3.0 3.0 2.0 2.0 10.0 5.0 8.0 3.0 4.0 4.0 4.0 4.0 6.0 3.0 5.0 4.0 7.0 4.0 9.0 5.0 10.0 4.0 3.0 3.0 5.0 5.0 8.0 6.0 Old System Background Minimum 6.0 1.0 1.0 2.0 4.0 4.0 5.0 7.0 14.0 7.0 4.0 5.0 5.0 4.0 3.0 3.0 2.0 5.0 4.0 6.0 4.0 3.0 1.0 2.0 6.0 3.0 4.0 5.0 3.0 9.0 7.0 Old System Background Maximum 19.0 1.0 8.0 5.0 6.0 8.0 18.0 10.0 19.0 15.0 7.0 6.0 7.0 6.0 12.0 6.0 12.0 7.0 5.0 15.0 10.0 6.0 4.0 16.0 8.0 5.0 11.0 21.0 7.0 12.0 17.0 Old System Background Average 12.5 1.0 4.5 3.5 5.0 6.0 11.5 8.5 16.5 11.0 5.5 5.5 6.0 5.0 7.5 4.5 7.0 6.0 4.5 10.5 7.0 4.5 2.5 9.0 7.0 4.0 7.5 13.0 5.0 10.5 12.0 Old System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 96.35% 98.21% 98.88% 83.33% 75.00% 82.35% 98.78% 97.09% 98.90% 95.56% 75.00% 57.14% 83.33% 86.67% 95.54% 95.08% 94.87% 97.60% 99.56% 97.88% 97.48% 96.83% 96.33% 98.77% 98.97% 99.00% 95.54% 98.28% 99.44% 97.63% 98.24% New System Lead Filter Inlet 18.0 6.0 28.0 3.0 8.0 20.0 8.0 12.0 20.0 20.0 36.0 24.0 20.0 17.0 23.0 16.0 12.0 15.0 19.0 26.0 17.0 19.0 12.0 31.0 13.0 16.0 16.0 28.0 11.0 24.0 15.0 New System Between Filters New System Lag Filter Outlet 7.0 4.0 1.0 1.0 10.0 6.0 2.0 2.0 8.0 2.0 6.0 5.0 4.0 4.0 6.0 4.0 10.0 9.0 8.0 6.0 3.0 2.0 4.0 3.0 5.0 4.0 3.0 4.0 11.0 4.0 10.0 6.0 7.0 5.0 7.0 5.0 7.0 8.0 12.0 3.0 9.0 5.0 4.0 3.0 4.0 3.0 12.0 9.0 4.0 4.0 7.0 6.0 8.0 4.0 11.0 5.0 5.0 4.0 4.0 4.0 5.0 4.0 New System Background Minimum 2.0 4.0 4.0 1.0 3.0 11.0 3.0 24.0 13.0 8.0 1.0 7.0 6.0 4.0 6.0 7.0 4.0 11.0 17.0 7.0 2.0 5.0 2.0 8.0 6.0 3.0 3.0 4.0 7.0 5.0 3.0 New System Background Maximum 9.0 5.0 16.0 2.0 4.0 50.0 10.0 72.0 19.0 12.0 6.0 12.0 8.0 6.0 24.0 12.0 9.0 15.0 18.0 19.0 11.0 8.0 5.0 21.0 24.0 56.0 15.0 17.0 36.0 22.0 15.0 New System Background Average 5.5 4.5 10.0 1.5 3.5 30.5 6.5 48.0 16.0 10.0 3.5 9.5 7.0 5.0 15.0 9.5 6.5 13.0 17.5 13.0 6.5 6.5 3.5 14.5 15.0 29.5 9.0 10.5 21.5 13.5 9.0 New System Net Reading 0.0 0.0 0.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 77.78% 83.33% 78.57% 33.33% 75.00% 75.00% 50.00% 66.67% 55.00% 70.00% 94.44% 87.50% 80.00% 76.47% 82.61% 62.50% 58.33% 66.67% 57.89% 88.46% 70.59% 84.21% 75.00% 70.97% 69.23% 62.50% 75.00% 82.14% 63.64% 83.33% 73.33% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Oni Ruiz Israel Estrella Eduardo Chavez Jewel Husselman Jewel Husselman Theo Rodriguez Theo Rodriguez Jewel Husselman Jewel Husselman Jewel Husselman Jewel Husselman Jewel Husselman Jewel Husselman Jewel Husselman Oni Ruiz Eduardo Chavez Eduardo Chavez Israel Estrella Israel Estrella Oni Ruiz Oni Ruiz Jewel Husselman Jewel Husselman Eduardo Chavez Homer Trujillo Homer Trujillo Oni Ruiz Oni Ruiz Carlos Martinez Homer Trujillo Homer Trujillo EPA Inspection Report - Page 997 of 1969 2018 API Carbon Canister Monitoring for Month: February Monitoring Date 1-Feb 2-Feb 3-Feb 4-Feb 5-Feb 6-Feb 7-Feb 8-Feb 9-Feb 10-Feb 11-Feb 12-Feb 13-Feb 14-Feb 15-Feb 16-Feb 17-Feb 18-Feb 19-Feb 20-Feb 21-Feb 22-Feb 23-Feb 24-Feb 25-Feb 26-Feb 27-Feb 28-Feb Old System Lead Filter Inlet 318.0 338.0 330.0 357.0 457.0 383.0 255.0 273.0 279.0 249.0 324.0 397.0 365.0 268.0 247.0 308.0 281.0 326.0 451.0 647.0 279.0 347.0 572.0 389.0 274.0 597.0 126.0 510.0 Old System Lead Filter Outlet 8.0 9.0 8.0 10.0 8.0 3.0 4.0 4.0 4.0 3.0 9.0 9.0 5.0 9.0 8.0 10.0 6.0 9.0 6.0 5.0 4.0 16.0 8.0 8.0 7.0 3.0 8.0 4.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 8.0 6.0 9.0 6.0 8.0 4.0 10.0 5.0 5.0 4.0 3.0 3.0 4.0 4.0 4.0 4.0 4.0 5.0 3.0 3.0 9.0 4.0 9.0 5.0 4.0 3.0 9.0 6.0 8.0 3.0 10.0 6.0 6.0 2.0 9.0 5.0 6.0 6.0 5.0 4.0 4.0 3.0 16.0 17.0 2.0 2.0 8.0 4.0 7.0 3.0 3.0 2.0 8.0 3.0 4.0 4.0 Old System Background Minimum 2.0 5.0 3.0 4.0 2.0 2.0 3.0 5.0 2.0 1.0 2.0 2.0 3.0 2.0 2.0 4.0 4.0 3.0 10.0 2.0 4.0 17.0 2.0 3.0 2.0 7.0 4.0 3.0 Old System Background Maximum 10.0 12.0 9.0 16.0 4.0 5.0 12.0 8.0 6.0 6.0 7.0 9.0 4.0 17.0 15.0 13.0 6.0 7.0 13.0 5.0 4.0 24.0 3.0 14.0 10.0 10.0 14.0 6.0 Old System Background Average 6.0 8.5 6.0 10.0 3.0 3.5 7.5 6.5 4.0 3.5 4.5 5.5 3.5 9.5 8.5 8.5 5.0 5.0 11.5 3.5 4.0 20.5 2.5 8.5 6.0 8.5 9.0 4.5 Old System Net Reading 0.0 0.0 0.0 0.0 1.0 0.0 0.0 0.0 1.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 98.11% 98.22% 98.79% 98.60% 99.12% 99.22% 98.43% 98.53% 98.21% 98.80% 98.77% 98.74% 99.18% 97.76% 98.79% 98.05% 99.29% 98.47% 98.67% 99.38% 98.92% 95.10% 99.65% 98.97% 98.91% 99.66% 97.62% 99.22% New System Lead Filter Inlet 26.0 23.0 24.0 21.0 9.0 10.0 12.0 10.0 11.0 9.0 22.0 15.0 53.0 19.0 38.0 28.0 31.0 57.0 18.0 15.0 17.0 47.0 11.0 14.0 17.0 11.0 59.0 10.0 New System Between Filters New System Lag Filter Outlet 13.0 4.0 14.0 5.0 12.0 5.0 10.0 3.0 3.0 2.0 3.0 2.0 5.0 4.0 7.0 6.0 5.0 4.0 4.0 3.0 11.0 3.0 9.0 5.0 5.0 4.0 11.0 5.0 13.0 4.0 11.0 5.0 5.0 2.0 14.0 4.0 6.0 5.0 9.0 6.0 4.0 4.0 23.0 19.0 6.0 4.0 9.0 3.0 10.0 3.0 6.0 5.0 6.0 3.0 4.0 4.0 New System Background Minimum 6.0 4.0 5.0 5.0 2.0 6.0 10.0 10.0 4.0 5.0 5.0 4.0 8.0 3.0 5.0 2.0 7.0 1.0 5.0 11.0 9.0 18.0 12.0 2.0 5.0 11.0 2.0 3.0 New System Background Maximum 14.0 13.0 13.0 13.0 4.0 14.0 37.0 15.0 7.0 8.0 13.0 12.0 14.0 8.0 17.0 17.0 19.0 13.0 9.0 21.0 13.0 34.0 18.0 12.0 14.0 22.0 7.0 4.0 New System Background Average 10.0 8.5 9.0 9.0 3.0 10.0 23.5 12.5 5.5 6.5 9.0 8.0 11.0 5.5 11.0 9.5 13.0 7.0 7.0 16.0 11.0 26.0 15.0 7.0 9.5 16.5 4.5 3.5 New System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.5 Control Efficiency (%) 84.62% 78.26% 79.17% 85.71% 77.78% 80.00% 66.67% 40.00% 63.64% 66.67% 86.36% 66.67% 92.45% 73.68% 89.47% 82.14% 93.55% 92.98% 72.22% 60.00% 76.47% 59.57% 63.64% 78.57% 82.35% 54.55% 94.92% 60.00% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Eduardo Chavez Oni Ruiz Oni Ruiz Oni Ruiz Jewel Husselman Jewel Husselman Carlos Martinez Jewel Husselman Jewel Husselman Carlos Martinez Oni Ruiz Oni Ruiz Homer Trujillo Oni Ruiz Oni Ruiz Oni Ruiz Eduardo Chavez Oni Ruiz Jewel Husselman Carlos Martinez Israel Estrella Theo Rodriguez Carlos Martinez Oni Ruiz Oni Ruiz Carlos Martinez Oni Ruiz Carlos Martinez EPA Inspection Report - Page 998 of 1969 2018 API Carbon Canister Monitoring for Month: March Monitoring Date 1-Mar 2-Mar 3-Mar 4-Mar 5-Mar 6-Mar 7-Mar 8-Mar 9-Mar 10-Mar 11-Mar 12-Mar 13-Mar 14-Mar 15-Mar 16-Mar 17-Mar 18-Mar 19-Mar 20-Mar 21-Mar 22-Mar 23-Mar 24-Mar 25-Mar 26-Mar 27-Mar 28-Mar 29-Mar 30-Mar 31-Mar Old System Lead Filter Inlet 500.0 217.0 362.0 321.0 244.0 120.0 281.0 118.0 138.0 275.0 298.0 878.0 550.0 330.0 1038.0 921.0 519.0 322.0 90.0 763.0 51.0 371.0 252.0 171.0 496.0 421.0 379.0 285.0 670.0 212.0 500.0 Old System Lead Filter Outlet 2.0 4.0 9.0 6.0 6.0 4.0 3.0 5.0 7.0 8.0 11.0 4.0 3.0 5.0 8.0 9.0 6.0 4.0 3.0 3.0 3.0 4.0 3.0 4.0 4.0 5.0 3.0 9.0 5.0 4.0 5.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 2.0 2.0 4.0 3.0 9.0 3.0 6.0 5.0 6.0 4.0 4.0 3.0 3.0 2.0 5.0 3.0 7.0 3.0 8.0 3.0 11.0 5.0 4.0 3.0 3.0 2.0 5.0 4.0 8.0 6.0 9.0 2.0 6.0 4.0 4.0 2.0 3.0 2.0 3.0 2.0 2.0 3.0 4.0 8.0 7.0 3.0 4.0 3.0 3.0 4.0 4.0 3.0 2.0 3.0 7.0 3.0 5.0 4.0 4.0 6.0 5.0 4.0 Old System Background Minimum 2.0 2.0 5.0 2.0 2.0 2.0 4.0 4.0 2.0 2.0 4.0 3.0 2.0 2.0 4.0 4.0 3.0 2.0 1.0 9.0 2.0 7.0 5.0 3.0 2.0 4.0 2.0 4.0 5.0 7.0 2.0 Old System Background Maximum 3.0 6.0 13.0 9.0 6.0 3.0 6.0 6.0 6.0 9.0 12.0 7.0 3.0 3.0 6.0 11.0 12.0 9.0 1.0 25.0 2.0 21.0 10.0 3.0 3.0 3.0 5.0 8.0 13.0 13.0 38.0 Old System Background Average 2.5 4.0 9.0 5.5 4.0 2.5 5.0 5.0 4.0 5.5 8.0 5.0 2.5 2.5 5.0 7.5 7.5 5.5 1.0 17.0 2.0 14.0 7.5 3.0 2.5 4.0 3.5 6.0 9.0 10.0 20.0 Old System Net Reading 0.0 0.0 0.0 0.0 0.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.5 1.0 0.0 0.0 0.0 1.0 0.0 1.0 0.0 0.0 0.0 1.5 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.60% 98.62% 99.17% 98.44% 98.36% 97.50% 99.29% 97.46% 97.83% 98.91% 98.32% 99.66% 99.64% 98.79% 99.42% 99.78% 99.23% 99.38% 97.78% 99.74% 94.12% 97.84% 98.81% 98.25% 99.19% 99.29% 99.21% 98.95% 99.40% 97.17% 99.20% New System Lead Filter Inlet 8.0 31.0 29.0 25.0 28.0 18.0 23.0 29.0 14.0 21.0 34.0 12.0 8.0 22.0 26.0 34.0 41.0 23.0 9.0 10.0 4.0 13.0 7.0 12.0 13.0 12.0 12.0 50.0 17.0 7.0 13.0 New System Between Filters New System Lag Filter Outlet 8.0 5.0 6.0 2.0 11.0 4.0 11.0 2.0 8.0 6.0 8.0 6.0 10.0 8.0 9.0 6.0 11.0 4.0 14.0 2.0 17.0 2.0 8.0 6.0 3.0 4.0 12.0 9.0 9.0 3.0 13.0 4.0 12.0 9.0 11.0 7.0 4.0 3.0 5.0 7.0 3.0 2.0 7.0 6.0 5.0 4.0 6.0 4.0 7.0 6.0 7.0 5.0 5.0 4.0 18.0 8.0 8.0 6.0 5.0 5.0 8.0 7.0 New System Background Minimum 14.0 3.0 8.0 4.0 3.0 9.0 7.0 7.0 5.0 4.0 6.0 18.0 3.0 3.0 6.0 8.0 8.0 2.0 6.0 19.0 2.0 12.0 7.0 5.0 11.0 6.0 4.0 7.0 6.0 7.0 8.0 New System Background Maximum 16.0 14.0 21.0 7.0 12.0 17.0 10.0 14.0 10.0 7.0 10.0 30.0 5.0 4.0 12.0 36.0 17.0 8.0 6.0 24.0 2.0 14.0 13.0 6.0 17.0 9.0 10.0 9.0 19.0 16.0 21.0 New System Background Average 15.0 8.5 14.5 5.5 7.5 13.0 8.5 10.5 7.5 5.5 8.0 24.0 4.0 3.5 9.0 22.0 12.5 5.0 6.0 21.5 2.0 13.0 10.0 5.5 14.0 7.5 7.0 8.0 12.5 11.5 14.5 New System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 5.5 0.0 0.0 0.0 2.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 37.50% 93.55% 86.21% 92.00% 78.57% 66.67% 65.22% 79.31% 71.43% 90.48% 94.12% 50.00% 50.00% 59.09% 88.46% 88.24% 78.05% 69.57% 66.67% 30.00% 50.00% 53.85% 42.86% 66.67% 53.85% 58.33% 66.67% 84.00% 64.71% 28.57% 46.15% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Jewel Husselman Eduardo Chavez Oni Ruiz Oni Ruiz Eduardo Chavez Eduardo Chavez Eduardo Chavez Eduardo Chavez Oni Ruiz Oni Ruiz Oni Ruiz Carlos Martinez Jose Nava Jose Nava Oni Ruiz Oni Ruiz Eduardo Chavez Eduardo Chavez Jewel Husselman Israel Estrella Israel Estrella Israel Estrella Israel Estrella Israel Estrella Israel Estrella Carlos Martinez Eduardo Chavez Homer Trujillo Oni Ruiz Carlos Martinez Theo Rodriguez EPA Inspection Report - Page 999 of 1969 2018 API Carbon Canister Monitoring for Month: April Monitoring Date 1-Apr 2-Apr 3-Apr 4-Apr 5-Apr 6-Apr 7-Apr 8-Apr 9-Apr 10-Apr 11-Apr 12-Apr 13-Apr 14-Apr 15-Apr 16-Apr 17-Apr 18-Apr 19-Apr 20-Apr 21-Apr 22-Apr 23-Apr 24-Apr 25-Apr 26-Apr 27-Apr 28-Apr 29-Apr 30-Apr Old System Lead Filter Inlet 420.0 1178.0 121.0 304.0 438.0 478.0 335.0 746.0 162.0 819.0 378.0 303.0 238.0 635.0 374.0 297.0 334.0 197.0 379.0 182.0 197.0 116.0 241.0 560.0 362.0 349.0 337.0 378.0 501.0 303.0 Old System Lead Filter Outlet 5.0 9.0 2.0 5.0 8.0 5.0 3.0 4.0 4.0 4.0 11.0 4.0 9.0 11.0 8.0 6.0 8.0 10.0 14.0 3.0 6.0 4.0 9.0 4.0 11.0 4.0 3.0 3.0 4.0 5.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 5.0 3.0 9.0 5.0 2.0 1.0 5.0 3.0 8.0 7.0 4.0 4.0 3.0 2.0 3.0 3.0 4.0 3.0 4.0 3.0 11.0 9.0 4.0 5.0 9.0 3.0 11.0 5.0 8.0 5.0 6.0 2.0 8.0 4.0 10.0 5.0 14.0 7.0 5.0 4.0 6.0 3.0 4.0 2.0 9.0 2.0 4.0 3.0 8.0 7.0 3.0 3.0 3.0 2.0 3.0 2.0 3.0 3.0 5.0 5.0 Old System Background Minimum 3.0 3.0 3.0 3.0 7.0 6.0 1.0 3.0 2.0 4.0 4.0 7.0 4.0 6.0 3.0 3.0 2.0 3.0 47.0 3.0 3.0 4.0 3.0 2.0 6.0 2.0 5.0 3.0 4.0 4.0 Old System Background Maximum 19.0 19.0 9.0 12.0 18.0 11.0 4.0 6.0 8.0 5.0 19.0 11.0 8.0 19.0 13.0 9.0 9.0 11.0 59.0 4.0 8.0 5.0 17.0 3.0 6.0 6.0 6.0 4.0 5.0 4.0 Old System Background Average 11.0 11.0 6.0 7.5 12.5 8.5 2.5 4.5 5.0 4.5 11.5 9.0 6.0 12.5 8.0 6.0 5.5 7.0 53.0 3.5 5.5 4.5 10.0 2.5 6.0 4.0 5.5 3.5 4.5 4.0 Old System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.5 0.0 0.0 0.0 0.5 1.0 0.0 0.0 0.0 0.0 1.0 Control Efficiency (%) 99.29% 99.58% 99.17% 99.01% 98.40% 99.16% 99.40% 99.60% 98.15% 99.63% 97.62% 98.35% 98.74% 99.21% 98.66% 99.33% 98.80% 97.46% 98.15% 97.80% 98.48% 98.28% 99.17% 99.46% 98.07% 99.14% 99.41% 99.47% 99.40% 98.35% New System Lead Filter Inlet 21.0 15.0 16.0 28.0 23.0 11.0 8.0 14.0 22.0 8.0 15.0 10.0 17.0 31.0 19.0 15.0 17.0 19.0 26.0 9.0 11.0 9.0 19.0 17.0 10.0 10.0 13.0 13.0 21.0 21.0 New System Between Filters New System Lag Filter Outlet 10.0 8.0 7.0 4.0 14.0 2.0 6.0 4.0 8.0 7.0 5.0 4.0 6.0 3.0 9.0 7.0 7.0 4.0 6.0 7.0 11.0 9.0 6.0 5.0 12.0 4.0 12.0 4.0 12.0 4.0 9.0 5.0 9.0 3.0 13.0 4.0 13.0 3.0 5.0 5.0 6.0 4.0 4.0 2.0 11.0 4.0 7.0 7.0 7.0 6.0 6.0 3.0 5.0 3.0 5.0 2.0 6.0 3.0 6.0 6.0 New System Background Minimum 10.0 2.0 3.0 2.0 9.0 4.0 7.0 33.0 3.0 17.0 8.0 6.0 2.0 2.0 6.0 4.0 6.0 2.0 12.0 8.0 6.0 3.0 5.0 5.0 10.0 4.0 3.0 4.0 3.0 6.0 New System Background Maximum 21.0 11.0 12.0 17.0 31.0 6.0 18.0 46.0 12.0 22.0 11.0 8.0 11.0 8.0 10.0 12.0 10.0 7.0 24.0 10.0 12.0 9.0 10.0 7.0 45.0 5.0 5.0 7.0 4.0 7.0 New System Background Average 15.5 6.5 7.5 9.5 20.0 5.0 12.5 39.5 7.5 19.5 9.5 7.0 6.5 5.0 8.0 8.0 8.0 4.5 18.0 9.0 9.0 6.0 7.5 6.0 27.5 4.5 4.0 5.5 3.5 6.5 New System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 61.90% 73.33% 87.50% 85.71% 69.57% 63.64% 62.50% 50.00% 81.82% 12.50% 40.00% 50.00% 76.47% 87.10% 78.95% 66.67% 82.35% 78.95% 88.46% 44.44% 63.64% 77.78% 78.95% 58.82% 40.00% 70.00% 76.92% 84.62% 85.71% 71.43% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Theo Rodriguez Oni Ruiz Eduardo Chavez Eduardo Chavez Theo Rodriguez Jose Nava Carlos Martinez Carlos Martinez Eduardo Chavez Israel Estrella Homer Trujillo Jerid Heath Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Jewel Husselman Eduardo Chavez Eduardo Chavez Oni Ruiz Jose Nava Homer Trujillo Jose Nava Jose Nava Jose Nava Jose Nava Jerid Heath EPA Inspection Report - Page 1000 of 1969 2018 API Carbon Canister Monitoring for Month: May Monitoring Date 1-May 2-May 3-May 4-May 5-May 6-May 7-May 8-May 9-May 10-May 11-May 12-May 13-May 14-May 15-May 16-May 17-May 18-May 19-May 20-May 21-May 22-May 23-May 24-May 25-May 26-May 27-May 28-May 29-May 30-May 31-May Old System Lead Filter Inlet 418.0 188.0 232.0 162.0 981.0 476.0 378.0 378.0 263.0 423.0 483.0 396.0 418.0 571.0 141.0 265.0 376.0 117.0 193.0 211.0 193.0 278.0 365.0 388.0 388.0 193.0 218.0 248.0 872.0 712.0 1713.0 Old System Lead Filter Outlet 6.0 8.0 7.0 5.0 3.0 9.0 3.0 8.0 8.0 9.0 8.0 10.0 6.0 5.0 6.0 7.0 10.0 23.0 5.0 4.0 5.0 9.0 4.0 9.0 9.0 4.0 5.0 6.0 10.0 7.0 6.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 5.0 5.0 8.0 9.0 6.0 6.0 4.0 4.0 3.0 2.0 9.0 3.0 3.0 4.0 8.0 4.0 8.0 4.0 9.0 5.0 8.0 2.0 9.0 5.0 6.0 3.0 4.0 4.0 6.0 4.0 7.0 4.0 10.0 6.0 7.0 3.0 5.0 3.0 4.0 3.0 5.0 3.0 9.0 3.0 5.0 5.0 9.0 6.0 9.0 6.0 4.0 2.0 5.0 4.0 6.0 4.0 7.0 8.0 7.0 5.0 6.0 4.0 Old System Background Minimum 4.0 9.0 10.0 4.0 1.0 6.0 3.0 3.0 3.0 7.0 7.0 2.0 2.0 7.0 3.0 3.0 5.0 6.0 3.0 4.0 5.0 6.0 4.0 4.0 4.0 4.0 3.0 5.0 13.0 8.0 3.0 Old System Background Maximum 5.0 11.0 12.0 7.0 4.0 14.0 9.0 9.0 7.0 18.0 12.0 7.0 7.0 10.0 8.0 12.0 18.0 10.0 9.0 8.0 9.0 12.0 4.0 6.0 6.0 8.0 8.0 8.0 15.0 10.0 5.0 Old System Background Average 4.5 10.0 11.0 5.5 2.5 10.0 6.0 6.0 5.0 9.8 9.5 4.5 4.5 8.5 5.5 7.5 11.5 8.0 6.0 6.0 7.0 9.0 4.0 5.0 5.0 6.0 5.5 6.5 14.0 9.0 4.0 Old System Net Reading 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.0 1.0 1.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 98.80% 95.21% 97.41% 97.53% 99.80% 99.37% 98.94% 98.94% 98.48% 98.82% 99.59% 98.74% 99.28% 99.30% 97.16% 98.49% 98.40% 97.44% 98.45% 98.58% 98.45% 98.92% 98.63% 98.45% 98.45% 98.96% 98.17% 98.39% 99.08% 99.30% 99.77% New System Lead Filter Inlet 12.0 13.0 24.0 23.0 19.0 18.0 23.0 23.0 27.0 29.0 21.0 19.0 23.0 24.0 14.0 21.0 28.0 32.0 27.0 23.0 22000.0 3377.0 4805.0 3146.0 3146.0 2831.0 4652.0 5703.0 4500.0 2831.0 2243.0 New System Between Filters New System Lag Filter Outlet 7.0 6.0 9.0 9.0 7.0 6.0 12.0 7.0 11.0 6.0 11.0 5.0 9.0 8.0 9.0 8.0 16.0 4.0 18.0 6.0 13.0 5.0 12.0 3.0 15.0 4.0 8.0 6.0 7.0 5.0 13.0 2.0 18.0 5.0 13.0 9.0 14.0 7.0 16.0 8.0 10.0 7.0 14.0 5.0 7.0 4.0 16.0 10.0 16.0 10.0 13.0 7.0 10.0 5.0 8.0 3.0 19.0 16.0 9.0 8.0 9.0 11.0 New System Background Minimum 10.0 12.0 5.0 6.0 12.0 4.0 13.0 13.0 5.0 10.0 3.0 4.0 5.0 7.0 6.0 2.0 7.0 2.0 6.0 12.0 8.0 2.0 7.0 8.0 8.0 6.0 8.0 4.0 17.0 13.0 34.0 New System Background Maximum 11.0 13.0 6.0 12.0 40.0 12.0 18.0 18.0 26.0 26.0 12.0 8.0 17.0 8.0 10.0 9.0 23.0 17.0 18.0 19.0 16.0 8.0 14.0 14.0 14.0 12.0 10.0 13.0 20.0 15.0 42.0 New System Background Average 10.5 12.5 5.5 9.0 26.0 8.0 15.5 15.5 15.5 18.0 7.5 6.0 11.0 7.5 8.0 5.5 15.0 9.5 12.0 15.5 12.0 5.0 10.5 11.0 11.0 9.0 9.0 8.5 18.5 14.0 38.0 New System Net Reading 0.0 0.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 50.00% 30.77% 75.00% 69.57% 68.42% 72.22% 65.22% 65.22% 85.19% 79.31% 76.19% 84.21% 82.61% 75.00% 64.29% 90.48% 82.14% 71.88% 74.07% 65.22% 99.97% 99.85% 99.92% 99.68% 99.68% 99.75% 99.89% 99.95% 99.64% 99.72% 99.51% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Jerid Heath Jerid Heath Jerid Heath Carlos Martinez Carlos Martinez Oni Ruiz Jewel Husselman Jewel Husselman Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Jose Nava Eduardo Chavez Oni Ruiz Oni Ruiz Jewel Husselman Carlos Martinez Carlos Martinez Oni Ruiz Oni Ruiz Israel Estrella Eduardo Chavez Eduardo Chavez Eduardo Chavez Eduardo Chavez Eduardo Chavez Jerid Heath Jerid Heath Israel Estrella EPA Inspection Report - Page 1001 of 1969 2018 API Carbon Canister Monitoring for Month: June Monitoring Date 1-Jun 2-Jun 3-Jun 4-Jun 5-Jun 6-Jun 7-Jun 8-Jun 9-Jun 10-Jun 11-Jun 12-Jun 13-Jun 14-Jun 15-Jun 16-Jun 17-Jun 18-Jun 19-Jun 20-Jun 21-Jun 22-Jun 23-Jun 24-Jun 25-Jun 26-Jun 27-Jun 28-Jun 29-Jun 30-Jun Old System Lead Filter Inlet 332.0 304.0 485.0 485.0 610.0 731.0 578.0 608.0 731.0 516.0 523.0 478.0 465.0 481.0 556.0 487.0 697.0 233.0 408.0 276.0 676.0 261.0 312.0 375.0 756.0 480.0 460.0 295.0 571.0 673.0 Old System Lead Filter Outlet 5.0 6.0 6.0 5.0 5.0 5.0 6.0 6.0 7.0 4.0 5.0 9.0 6.0 4.0 7.0 8.0 10.0 6.0 5.0 10.0 6.0 14.0 7.0 9.0 23.0 9.0 3.0 4.0 7.0 7.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 5.0 8.0 6.0 5.0 6.0 6.0 4.0 4.0 5.0 4.0 4.0 4.0 4.0 4.0 6.0 5.0 7.0 5.0 4.0 3.0 5.0 4.0 9.0 8.0 8.0 6.0 4.0 7.0 5.0 7.0 8.0 3.0 10.0 6.0 6.0 4.0 4.0 7.0 10.0 7.0 6.0 5.0 14.0 10.0 9.0 7.0 10.0 9.0 23.0 13.0 9.0 7.0 3.0 4.0 4.0 6.0 5.0 5.0 7.0 4.0 Old System Background Minimum 8.0 7.0 5.0 4.0 5.0 6.0 4.0 4.0 6.0 5.0 4.0 6.0 7.0 6.0 6.0 4.0 9.0 2.0 8.0 5.0 4.0 9.0 8.0 8.0 3.0 3.0 2.0 4.0 4.0 5.0 Old System Background Maximum 17.0 8.0 6.0 5.0 8.0 9.0 6.0 6.0 8.0 6.0 5.0 8.0 8.0 6.0 7.0 9.0 34.0 7.0 9.0 5.0 7.0 10.0 9.0 9.0 4.0 4.0 3.0 5.0 13.0 9.0 Old System Background Average 12.5 7.5 5.5 4.5 6.5 7.5 5.0 5.0 7.0 5.5 4.5 7.0 7.5 6.0 6.5 6.5 21.5 4.5 8.5 5.0 5.5 9.5 8.5 8.5 3.5 3.5 2.5 4.5 8.5 7.0 Old System Net Reading 0.0 0.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.0 0.0 1.0 0.5 0.0 0.0 0.0 0.0 2.0 0.0 0.5 0.0 0.5 9.5 3.5 1.5 1.5 0.0 0.0 Control Efficiency (%) 97.59% 98.36% 98.76% 99.18% 99.34% 99.45% 99.31% 99.18% 99.32% 99.42% 99.24% 98.33% 98.71% 98.54% 98.74% 99.38% 99.14% 98.28% 98.28% 97.46% 99.26% 96.17% 97.76% 97.60% 98.28% 98.54% 99.13% 97.97% 99.12% 99.41% New System Lead Filter Inlet 2561.0 2750.0 2371.0 1648.0 1962.0 1972.0 2079.0 1310.0 1997.0 1713.0 1653.0 1276.0 2529.0 2856.0 3517.0 2654.0 3658.0 2496.0 2345.0 1200.0 1465.0 2400.0 2315.0 3219.0 2400.0 3500.0 1745.0 3700.0 1200.0 2738.0 New System Between Filters New System Lag Filter Outlet 8.0 5.0 9.0 9.0 6.0 5.0 12.0 7.0 14.0 8.0 12.0 5.0 14.0 5.0 10.0 5.0 15.0 10.0 9.0 5.0 6.0 6.0 12.0 10.0 8.0 9.0 7.0 7.0 8.0 8.0 14.0 5.0 17.0 5.0 12.0 8.0 4.0 5.0 3.0 3.0 15.0 7.0 6.0 5.0 12.0 10.0 13.0 11.0 7.0 7.0 5.0 5.0 6.0 3.0 5.0 6.0 4.0 3.0 13.0 4.0 New System Background Minimum 8.0 10.0 9.0 8.0 9.0 8.0 5.0 3.0 7.0 4.0 5.0 17.0 10.0 9.0 9.0 2.0 12.0 4.0 10.0 4.0 8.0 9.0 10.0 10.0 9.0 5.0 13.0 11.0 6.0 2.0 New System Background Maximum 9.0 11.0 10.0 11.0 12.0 11.0 7.0 4.0 10.0 5.0 6.0 18.0 12.0 11.0 11.0 12.0 39.0 9.0 12.0 7.0 14.0 24.0 12.0 12.0 14.0 7.0 17.0 13.0 10.0 12.0 New System Background Average 8.5 10.5 9.5 9.5 10.5 9.5 6.0 3.5 8.5 4.5 5.5 17.5 11.0 10.0 10.0 7.0 25.5 6.5 11.0 5.5 11.0 16.5 11.0 11.0 11.5 6.0 15.0 12.0 8.0 7.0 New System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.5 1.5 0.5 0.5 0.0 0.0 0.0 0.0 0.0 0.0 1.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.80% 99.67% 99.79% 99.58% 99.59% 99.75% 99.76% 99.62% 99.50% 99.71% 99.64% 99.22% 99.64% 99.75% 99.77% 99.81% 99.86% 99.68% 99.79% 99.75% 99.52% 99.79% 99.57% 99.66% 99.71% 99.86% 99.83% 99.84% 99.75% 99.85% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Israel Estrella Jerid Heath Jerid Heath Jose Nava Jose Nava Jose Nava Jose Nava Jose Nava Jose Nava Jerid Heath Jerid Heath Jerid Heath Jerid Heath Jerid Heath Jerid Heath Oni Ruiz Oni Ruiz Eduardo Chavez Jerid Heath Homer Trujillo Eduardo Chavez Homer Trujillo Jerid Heath Jerid Heath Homer Trujillo Homer Trujillo Carlos Martinez Jerid Heath Carlos Martinez Oni Ruiz EPA Inspection Report - Page 1002 of 1969 2018 API Carbon Canister Monitoring for Month: July Monitoring Date 1-Jul 2-Jul 3-Jul 4-Jul 5-Jul 6-Jul 7-Jul 8-Jul 9-Jul 10-Jul 11-Jul 12-Jul 13-Jul 14-Jul 15-Jul 16-Jul 17-Jul 18-Jul 19-Jul 20-Jul 21-Jul 22-Jul 23-Jul 24-Jul 25-Jul 26-Jul 27-Jul 28-Jul 29-Jul 30-Jul 31-Jul Old System Lead Filter Inlet 739.0 365.0 473.0 551.0 228.0 169.0 706.0 465.0 639.0 724.0 425.0 691.0 589.0 547.0 625.0 544.0 566.0 490.0 619.0 681.0 541.0 695.0 369.0 425.0 457.0 463.0 379.0 393.0 453.0 965.0 245.0 Old System Lead Filter Outlet 8.0 7.0 5.0 9.0 5.0 2.0 5.0 5.0 8.0 9.0 6.0 8.0 7.0 9.0 7.0 5.0 4.0 4.0 5.0 4.0 5.0 6.0 7.0 5.0 7.0 7.0 7.0 9.0 7.0 7.0 9.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 8.0 5.0 7.0 8.0 5.0 7.0 9.0 7.0 4.0 4.0 2.0 2.0 5.0 3.0 5.0 3.0 8.0 5.0 9.0 4.0 5.0 6.0 8.0 3.0 7.0 3.0 9.0 3.0 7.0 3.0 5.0 4.0 4.0 3.0 4.0 3.0 5.0 3.0 4.0 3.0 5.0 4.0 6.0 4.0 7.0 6.0 5.0 6.0 7.0 8.0 8.0 8.0 8.0 8.0 10.0 11.0 7.0 9.0 7.0 5.0 9.0 5.0 Old System Background Minimum 2.0 8.0 6.0 4.0 5.0 1.0 2.0 3.0 3.0 7.0 4.0 4.0 4.0 4.0 2.0 4.0 4.0 7.0 3.0 4.0 3.0 3.0 8.0 7.0 8.0 9.0 9.0 7.0 8.0 2.0 4.0 Old System Background Maximum 12.0 9.0 8.0 8.0 13.0 3.0 4.0 5.0 10.0 19.0 5.0 7.0 6.0 13.0 6.0 7.0 5.0 8.0 5.0 5.0 5.0 5.0 10.0 9.0 9.0 10.0 10.0 12.0 10.0 4.0 11.0 Old System Background Average 7.0 8.5 7.0 6.0 9.0 2.0 3.0 4.0 6.5 13.0 4.5 5.5 5.0 8.5 4.0 5.5 4.5 7.5 4.0 4.5 4.0 4.0 9.0 8.0 8.5 9.5 9.5 9.5 9.0 3.0 7.5 Old System Net Reading 0.0 0.0 0.0 1.0 0.0 0.0 0.0 0.0 0.0 0.0 1.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.5 0.0 2.0 0.0 Control Efficiency (%) 99.32% 97.81% 98.52% 98.73% 98.25% 98.82% 99.58% 99.35% 99.22% 99.45% 98.59% 99.57% 99.49% 99.45% 99.52% 99.26% 99.47% 99.39% 99.52% 99.56% 99.26% 99.42% 98.37% 98.59% 98.25% 98.27% 97.89% 97.20% 98.01% 99.48% 97.96% New System Lead Filter Inlet 3500.0 3765.0 2870.0 2896.0 1456.0 1055.0 1557.0 1145.0 2764.0 2136.0 2315.0 2880.0 3500.0 3500.0 2478.0 1423.0 1937.0 1368.0 1372.0 1648.0 1237.0 1472.0 3135.0 3719.0 4379.0 5679.0 5239.0 5342.0 5362.0 1532.0 2774.0 New System Between Filters New System Lag Filter Outlet 17.0 4.0 10.0 9.0 8.0 10.0 14.0 8.0 17.0 8.0 6.0 5.0 12.0 8.0 8.0 7.0 12.0 2.0 12.0 2.0 8.0 9.0 13.0 5.0 21.0 5.0 21.0 5.0 12.0 4.0 14.0 9.0 10.0 5.0 13.0 4.0 12.0 5.0 11.0 4.0 9.0 5.0 15.0 5.0 13.0 10.0 13.0 10.0 11.0 10.0 13.0 11.0 10.0 11.0 8.0 12.0 12.0 9.0 10.0 6.0 15.0 3.0 New System Background Minimum 2.0 10.0 13.0 6.0 13.0 5.0 28.0 16.0 4.0 3.0 12.0 2.0 6.0 8.0 4.0 11.0 5.0 8.0 7.0 6.0 5.0 5.0 10.0 10.0 10.0 13.0 10.0 12.0 11.0 11.0 2.0 New System Background Maximum 12.0 12.0 14.0 10.0 28.0 14.0 72.0 38.0 13.0 6.0 13.0 10.0 17.0 17.0 9.0 13.0 6.0 11.0 11.0 8.0 9.0 7.0 12.0 12.0 12.0 14.0 13.0 16.0 13.0 14.0 8.0 New System Background Average 7.0 11.0 13.5 8.0 20.5 9.5 50.0 27.0 8.5 4.5 12.5 6.0 11.5 12.5 6.5 12.0 5.5 9.5 9.0 7.0 7.0 6.0 11.0 11.0 11.0 13.5 11.5 14.0 12.0 12.5 5.0 New System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.89% 99.76% 99.65% 99.72% 99.45% 99.53% 99.49% 99.39% 99.93% 99.91% 99.61% 99.83% 99.86% 99.86% 99.84% 99.37% 99.74% 99.71% 99.64% 99.76% 99.60% 99.66% 99.68% 99.73% 99.77% 99.81% 99.79% 99.78% 99.83% 99.61% 99.89% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Oni Ruiz Jerid Heath Jerid Heath Eduardo Chavez Carlos Martinez Carlos Martinez Carlos Martinez Carlos Martinez Oni Ruiz Oni Ruiz Jerid Heath Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Jose Nava Jose Nava Jose Nava Jose Nava Jose Nava Jose Nava Jose Nava Jerid Heath Jerid Heath Jerid Heath Jerid Heath Jerid Heath Jewel Husselman Jewel Husselman Jose Nava Oni Ruiz EPA Inspection Report - Page 1003 of 1969 2018 API Carbon Canister Monitoring for Month: August Monitoring Date 1-Aug 2-Aug 3-Aug 4-Aug 5-Aug 6-Aug 7-Aug 8-Aug 9-Aug 10-Aug 11-Aug 12-Aug 13-Aug 14-Aug 15-Aug 16-Aug 17-Aug 18-Aug 19-Aug 20-Aug 21-Aug 22-Aug 23-Aug 24-Aug 25-Aug 26-Aug 27-Aug 28-Aug 29-Aug 30-Aug 31-Aug Old System Lead Filter Inlet 415.0 732.0 445.0 279.0 683.0 263.0 436.0 332.0 427.0 114.0 186.0 127.0 397.0 341.0 396.0 368.0 77.0 238.0 278.0 368.0 312.0 439.0 373.0 471.0 567.0 479.0 673.0 573.0 111.0 341.0 387.0 Old System Lead Filter Outlet 12.0 8.0 5.0 8.0 8.0 4.0 8.0 4.0 7.0 2.0 3.0 3.0 7.0 6.0 7.0 7.0 4.0 9.0 6.0 9.0 7.0 8.0 9.0 6.0 4.0 5.0 9.0 8.0 2.0 8.0 8.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 12.0 5.0 8.0 4.0 5.0 4.0 8.0 3.0 8.0 3.0 4.0 3.0 5.0 7.0 4.0 4.0 7.0 6.0 2.0 1.0 2.0 2.0 2.0 2.0 7.0 2.0 6.0 5.0 7.0 3.0 9.0 7.0 4.0 3.0 9.0 5.0 6.0 3.0 8.0 8.0 7.0 5.0 7.0 7.0 7.0 7.0 6.0 4.0 4.0 3.0 5.0 4.0 9.0 3.0 9.0 5.0 2.0 1.0 8.0 4.0 8.0 4.0 Old System Background Minimum 4.0 6.0 2.0 6.0 4.0 3.0 6.0 3.0 8.0 1.0 3.0 6.0 3.0 6.0 8.0 3.0 2.0 2.0 4.0 9.0 5.0 8.0 8.0 8.0 3.0 4.0 4.0 7.0 2.0 2.0 6.0 Old System Background Maximum 7.0 9.0 6.0 17.0 13.0 4.0 8.0 4.0 10.0 2.0 6.0 9.0 12.0 14.0 24.0 9.0 3.0 12.0 17.0 11.0 8.0 9.0 9.0 13.0 4.0 5.0 8.0 10.0 3.0 2.0 10.0 Old System Background Average 5.5 7.5 4.0 11.5 8.5 3.5 7.0 3.5 9.0 1.5 4.5 7.5 7.5 10.0 16.0 6.0 2.5 7.0 10.5 10.0 6.5 8.5 8.5 10.5 3.5 4.5 6.0 8.5 2.5 14.0 8.0 Old System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 98.80% 99.45% 99.10% 98.92% 99.56% 98.86% 98.39% 98.80% 98.59% 99.12% 98.92% 98.43% 99.50% 98.53% 99.24% 98.10% 96.10% 97.90% 98.92% 97.83% 98.40% 98.41% 98.12% 99.15% 99.47% 99.16% 99.55% 99.13% 99.10% 98.83% 98.97% New System Lead Filter Inlet 7600.0 1681.0 3200.0 2439.0 2864.0 7873.0 3725.0 697.0 5764.0 1100.0 1213.0 2018.0 2386.0 40260.0 20600.0 6724.0 837.0 3500.0 20400.0 5624.0 12000.0 6734.0 7293.0 1136.0 1349.0 1122.0 2247.0 2176.0 1356.0 2448.0 2497.0 New System Between Filters New System Lag Filter Outlet 12.0 9.0 15.0 8.0 12.0 7.0 16.0 2.0 17.0 5.0 7.0 6.0 8.0 10.0 9.0 6.0 12.0 10.0 4.0 3.0 7.0 4.0 9.0 3.0 13.0 4.0 9.0 4.0 15.0 6.0 12.0 10.0 5.0 3.0 17.0 3.0 13.0 4.0 11.0 12.0 16.0 14.0 10.0 11.0 12.0 10.0 16.0 8.0 11.0 4.0 15.0 4.0 14.0 5.0 16.0 6.0 5.0 3.0 17.0 3.0 14.0 3.0 New System Background Minimum 6.0 10.0 5.0 4.0 3.0 12.0 9.0 11.0 8.0 5.0 6.0 8.0 7.0 8.0 12.0 11.0 3.0 3.0 3.0 9.0 5.0 10.0 11.0 7.0 3.0 4.0 2.0 3.0 5.0 4.0 5.0 NOTE: 8/8/18 - Lower than normal readings due to purging of covers & lids of API sump tank. New System Background Maximum 11.0 19.0 9.0 10.0 11.0 16.0 11.0 20.0 9.0 8.0 11.0 10.0 23.0 19.0 38.0 13.0 6.0 14.0 6.0 10.0 13.0 12.0 13.0 10.0 4.0 7.0 7.0 9.0 10.0 12.0 17.0 New System Background Average 8.5 14.5 7.0 7.0 7.0 14.0 10.0 15.5 8.5 6.5 8.5 9.0 15.0 13.5 25.0 12.0 4.5 8.5 4.5 9.5 9.0 11.0 12.0 8.5 3.5 5.5 4.5 6.0 7.5 8.0 11.0 New System Net Reading 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 2.5 5.0 0.0 0.0 0.0 0.5 0.0 0.5 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.88% 99.52% 99.78% 99.92% 99.83% 99.92% 99.73% 99.14% 99.83% 99.73% 99.67% 99.85% 99.83% 99.99% 99.97% 99.85% 99.64% 99.91% 99.98% 99.79% 99.88% 99.84% 99.86% 99.30% 99.70% 99.64% 99.78% 99.72% 99.78% 99.88% 99.88% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Eduardo Chavez Jose Nava Eduardo Chavez Oni Ruiz Oni Ruiz Carlos Martinez Jerid Heath Carlos Martinez Jerid Heath Carlos Martinez Carlos Martinez Carlos Martinez Oni Ruiz Oni Ruiz Oni Ruiz Jerid Heath Carlos Martinez Oni Ruiz Oni Ruiz Jerid Heath Eduardo Chavez Jerid Heath Jerid Heath Jose Nava Jose Nava Jose Nava Oni Ruiz Jewel Husselman Carlos Martinez Oni Ruiz Oni Ruiz EPA Inspection Report - Page 1004 of 1969 2018 API Carbon Canister Monitoring for Month: September Monitoring Date 1-Sep 2-Sep 3-Sep 4-Sep 5-Sep 6-Sep 7-Sep 8-Sep 9-Sep 10-Sep 11-Sep 12-Sep 13-Sep 14-Sep 15-Sep 16-Sep 17-Sep 18-Sep 19-Sep 20-Sep 21-Sep 22-Sep 23-Sep 24-Sep 25-Sep 26-Sep 27-Sep 28-Sep 29-Sep 30-Sep Old System Lead Filter Inlet 487.0 681.0 294.0 374.0 328.0 119.0 342.0 297.0 429.0 210.0 374.0 297.0 142.0 136.0 181.0 155.0 110.0 315.0 151.0 343.0 321.0 342.0 277.0 669.0 661.0 66.0 348.0 160.0 189.0 732.0 Old System Lead Filter Outlet 9.0 9.0 6.0 9.0 5.0 3.0 6.0 8.0 8.0 2.0 9.0 2.0 2.0 2.0 3.0 5.0 3.0 6.0 2.0 7.0 6.0 9.0 8.0 16.0 6.0 3.0 8.0 2.0 5.0 4.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 9.0 4.0 9.0 3.0 6.0 3.0 9.0 8.0 4.0 5.0 3.0 3.0 6.0 4.0 8.0 3.0 8.0 3.0 2.0 3.0 9.0 3.0 2.0 3.0 2.0 6.0 2.0 3.0 3.0 5.0 5.0 3.0 3.0 5.0 6.0 2.0 2.0 5.0 7.0 6.0 6.0 5.0 9.0 4.0 8.0 3.0 16.0 8.0 4.0 4.0 3.0 7.0 7.0 1.0 2.0 5.0 5.0 4.0 4.0 3.0 Old System Background Minimum 2.0 6.0 2.0 8.0 8.0 6.0 4.0 4.0 6.0 2.0 4.0 4.0 4.0 4.0 2.0 6.0 7.0 3.0 3.0 8.0 8.0 6.0 2.0 10.0 6.0 9.0 8.0 4.0 4.0 3.0 Old System Background Maximum 17.0 18.0 7.0 10.0 9.0 8.0 9.0 12.0 14.0 8.0 11.0 7.0 6.0 9.0 5.0 11.0 9.0 8.0 8.0 9.0 10.0 17.0 9.0 11.0 9.0 20.0 10.0 8.0 7.0 4.0 Old System Background Average 9.5 12.0 4.5 9.0 8.5 7.0 6.5 8.0 10.0 5.0 7.5 5.5 5.0 6.5 3.5 8.5 8.0 5.5 5.5 8.5 9.0 11.5 5.5 10.5 7.5 14.5 9.0 6.0 5.5 3.5 Old System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.0 0.0 1.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.18% 99.56% 98.98% 97.86% 98.48% 97.48% 98.83% 98.99% 99.30% 98.57% 99.20% 98.99% 95.77% 97.79% 97.24% 98.06% 95.45% 99.37% 96.69% 98.25% 98.44% 98.83% 98.92% 98.80% 99.39% 89.39% 99.71% 96.88% 97.88% 99.59% New System Lead Filter Inlet 5500.0 3398.0 4745.0 7659.0 6775.0 4380.0 4500.0 4568.0 3500.0 3500.0 4428.0 4375.0 3213.0 3516.0 3256.0 3400.0 6743.0 2211.0 3100.0 6245.0 6324.0 2478.0 3500.0 1800.0 6713.0 3113.0 6743.0 1200.0 3748.0 23000.0 New System Between Filters New System Lag Filter Outlet 16.0 5.0 17.0 3.0 13.0 5.0 11.0 12.0 11.0 12.0 2.0 3.0 14.0 6.0 13.0 4.0 15.0 5.0 12.0 3.0 16.0 4.0 6.0 4.0 3.0 5.0 3.0 4.0 5.0 7.0 13.0 6.0 10.0 12.0 16.0 5.0 5.0 7.0 10.0 11.0 10.0 8.0 12.0 2.0 15.0 4.0 7.0 7.0 7.0 6.0 5.0 3.0 11.0 10.0 5.0 8.0 5.0 7.0 11.0 9.0 New System Background Minimum 2.0 4.0 3.0 10.0 9.0 6.0 6.0 2.0 4.0 5.0 5.0 6.0 7.0 7.0 9.0 5.0 10.0 4.0 6.0 9.0 10.0 3.0 6.0 9.0 8.0 5.0 11.0 46.0 4.0 26.0 New System Background Maximum 10.0 14.0 11.0 11.0 11.0 8.0 12.0 10.0 17.0 10.0 17.0 10.0 11.0 11.0 12.0 13.0 11.0 13.0 13.0 11.0 12.0 9.0 18.0 10.0 13.0 7.0 13.0 112.0 12.0 67.0 New System Background Average 6.0 9.0 7.0 10.5 10.0 7.0 9.0 6.0 10.5 7.5 11.0 8.0 9.0 9.0 10.5 9.0 10.5 8.5 9.5 10.0 11.0 6.0 9.0 9.5 10.5 6.0 12.0 79.0 8.0 46.5 New System Net Reading 0.0 0.0 0.0 1.5 2.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.5 0.0 0.0 1.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.91% 99.91% 99.89% 99.84% 99.82% 99.93% 99.87% 99.91% 99.86% 99.91% 99.91% 99.91% 99.84% 99.89% 99.79% 99.82% 99.82% 99.77% 99.77% 99.82% 99.87% 99.92% 99.89% 99.61% 99.91% 99.90% 99.85% 99.33% 99.81% 99.96% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Oni Ruiz Oni Ruiz Oni Ruiz Jerid Heath Jerid Heath Isaac Sanchez Eduardo Chavez Oni Ruiz Oni Ruiz Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Jerid Heath Oni Ruiz Isaac Sanchez Jerid Heath Jerid Heath Oni Ruiz Oni Ruiz Homer Trujillo Carlos Martinez Carlos Martinez Jerid Heath Isaac Sanchez Carlos Martinez Carlos Martinez EPA Inspection Report - Page 1005 of 1969 2018 API Carbon Canister Monitoring for Month: OCTOBER Monitoring Date 1-Oct 2-Oct 3-Oct 4-Oct 5-Oct 6-Oct 7-Oct 8-Oct 9-Oct 10-Oct 11-Oct 12-Oct 13-Oct 14-Oct 15-Oct 16-Oct 17-Oct 18-Oct 19-Oct 20-Oct 21-Oct 22-Oct 23-Oct 24-Oct 25-Oct 26-Oct 27-Oct 28-Oct 29-Oct 30-Oct 31-Oct Old System Lead Filter Inlet 147.0 286.0 156.0 224.0 299.0 223.0 201.0 98.0 92.0 92.0 204.0 146.0 198.0 238.0 483.0 621.0 579.0 181.0 674.0 628.0 577.0 628.0 30.0 411.0 536.0 517.0 673.0 863.0 254.0 1024.0 362.0 Old System Lead Filter Outlet 2.0 4.0 4.0 8.0 6.0 2.0 3.0 9.0 8.0 7.0 6.0 2.0 7.0 9.0 8.0 5.0 6.0 6.0 4.0 4.0 5.0 5.0 7.0 7.0 7.0 8.0 7.0 7.0 4.0 9.0 6.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 6.0 2.0 4.0 2.0 4.0 3.0 8.0 4.0 6.0 2.0 2.0 3.0 3.0 5.0 9.0 3.0 8.0 4.0 7.0 2.0 6.0 5.0 2.0 5.0 7.0 3.0 9.0 3.0 8.0 6.0 5.0 4.0 6.0 3.0 6.0 4.0 4.0 3.0 4.0 3.0 5.0 3.0 5.0 6.0 7.0 3.0 7.0 6.0 6.0 8.0 7.0 7.0 7.0 4.0 6.0 1.0 4.0 8.0 9.0 8.0 6.0 4.0 Old System Background Minimum 4.0 5.0 4.0 3.0 6.0 5.0 3.0 2.0 6.0 3.0 3.0 4.0 4.0 6.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 7.0 3.0 4.0 7.0 7.0 3.0 3.0 6.0 7.0 4.0 Old System Background Maximum 11.0 14.0 17.0 18.0 12.0 9.0 9.0 7.0 10.0 9.0 8.0 7.0 6.0 7.0 5.0 4.0 5.0 6.0 11.0 5.0 5.0 6.0 4.0 7.0 8.0 7.0 9.0 9.0 9.0 12.0 5.0 Old System Background Average 7.5 9.5 10.5 10.5 9.0 7.0 6.0 4.5 8.0 6.0 5.5 5.5 5.0 6.5 4.0 3.5 4.0 4.5 7.0 4.0 4.0 6.5 3.5 5.5 7.5 8.0 6.0 6.0 7.5 9.5 4.5 Old System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 2.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.5 0.5 0.0 0.0 0.0 0.5 0.0 0.0 Control Efficiency (%) 98.64% 99.30% 98.08% 98.21% 99.33% 98.65% 97.51% 96.94% 95.65% 97.83% 97.55% 96.58% 98.48% 98.74% 98.76% 99.36% 99.48% 97.79% 99.55% 99.52% 99.48% 99.04% 90.00% 98.54% 98.51% 98.65% 99.41% 99.88% 96.85% 99.22% 98.90% New System Lead Filter Inlet 1200.0 3910.0 5590.0 3500.0 2364.0 3879.0 2416.0 1764.0 2549.0 2278.0 2231.0 2011.0 2362.0 2766.0 2337.0 1638.0 2762.0 2499.0 3127.0 2488.0 1488.0 6432.0 1200.0 3212.0 6219.0 7431.0 7267.0 3217.0 4413.0 3414.0 1648.0 New System Between Filters New System Lag Filter Outlet 3.0 5.0 5.0 8.0 14.0 9.0 16.0 5.0 14.0 7.0 5.0 4.0 4.0 7.0 11.0 3.0 18.0 5.0 14.0 5.0 15.0 5.0 10.0 4.0 10.0 54.0 13.0 3.0 14.0 9.0 14.0 7.0 17.0 6.0 18.0 3.0 4.0 7.0 16.0 7.0 17.0 9.0 10.0 10.0 3.0 3.0 6.0 4.0 7.0 9.0 13.0 11.0 16.0 9.0 9.0 3.0 3.0 5.0 9.0 7.0 5.0 5.0 New System Background Minimum 13.0 9.0 7.0 2.0 4.0 10.0 13.0 4.0 2.0 6.0 7.0 13.0 4.0 2.0 10.0 8.0 8.0 2.0 8.0 9.0 7.0 10.0 3.0 3.0 10.0 9.0 5.0 5.0 7.0 6.0 3.0 New System Background Maximum 20.0 16.0 20.0 7.0 18.0 23.0 26.0 12.0 17.0 11.0 12.0 26.0 12.0 8.0 12.0 12.0 9.0 5.0 22.0 10.0 9.0 11.0 4.0 8.0 12.0 10.0 14.0 11.0 16.0 8.0 5.0 New System Background Average 16.5 12.5 13.5 4.5 11.0 16.5 19.5 8.0 9.5 8.5 9.5 19.5 8.0 5.0 11.0 10.0 8.5 3.5 15.0 9.5 8.0 10.5 3.5 5.5 11.0 9.5 9.5 8.0 11.5 7.0 4.0 New System Net Reading 0.0 0.0 0.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 46.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.0 0.0 0.0 0.0 0.0 1.5 0.0 0.0 0.0 0.0 1.0 Control Efficiency (%) 99.58% 99.80% 99.84% 99.86% 99.70% 99.90% 99.71% 99.83% 99.80% 99.78% 99.78% 99.80% 97.71% 99.89% 99.61% 99.57% 99.78% 99.88% 99.78% 99.72% 99.40% 99.84% 99.75% 99.88% 99.86% 99.85% 99.88% 99.91% 99.89% 99.79% 99.70% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Isaac Sanchez Eduardo Chavez Eduardo Chavez Oni Ruiz Oni Ruiz Isaac Sanchez Isaac Sanchez Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Isaac Sanchez Oni Ruiz Oni Ruiz Jose Nava Jose Nava Jose Nava Oni Ruiz Isaac Sanchez Jose Nava Jose Nava Jerid Heath Homer Trujillo Homer Trujillo Jerid Heath Jerid Heath Isaac Sanchez Isaac Sanchez Isaac Sanchez Homer Trujillo Jose Nava EPA Inspection Report - Page 1006 of 1969 2018 API Carbon Canister Monitoring for Month: November Monitoring Date 1-Nov 2-Nov 3-Nov 4-Nov 5-Nov 6-Nov 7-Nov 8-Nov 9-Nov 10-Nov 11-Nov 12-Nov 13-Nov 14-Nov 15-Nov 16-Nov 17-Nov 18-Nov 19-Nov 20-Nov 21-Nov 22-Nov 23-Nov 24-Nov 25-Nov 26-Nov 27-Nov 28-Nov 29-Nov 30-Nov Old System Lead Filter Inlet 930.0 837.0 827.0 4344.0 1312.0 803.0 1471.0 605.0 987.0 791.0 912.0 891.0 979.0 528.0 680.0 516.0 793.0 879.0 581.0 629.0 582.0 664.0 504.0 738.0 582.0 871.0 667.0 297.0 225.0 416.0 Old System Lead Filter Outlet 5.0 7.0 7.0 5.0 10.0 7.0 5.0 4.0 4.0 4.0 5.0 6.0 8.0 7.0 7.0 6.0 8.0 8.0 6.0 5.0 8.0 9.0 6.0 9.0 8.0 4.0 9.0 4.0 5.0 7.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 5.0 4.0 7.0 3.0 7.0 4.0 5.0 2.0 10.0 3.0 4.0 3.0 5.0 6.0 4.0 3.0 5.0 6.0 4.0 5.0 5.0 6.0 6.0 4.0 7.0 5.0 8.0 8.0 6.0 8.0 6.0 4.0 8.0 4.0 8.0 5.0 6.0 4.0 5.0 2.0 8.0 5.0 9.0 3.0 6.0 3.0 9.0 6.0 8.0 3.0 4.0 3.0 9.0 3.0 3.0 5.0 6.0 2.0 7.0 5.0 Old System Background Minimum 3.0 5.0 4.0 3.0 2.0 2.0 5.0 3.0 4.0 2.0 4.0 2.0 2.0 7.0 4.0 3.0 4.0 9.0 4.0 4.0 7.0 4.0 2.0 3.0 4.0 8.0 4.0 3.0 3.0 5.0 Old System Background Maximum 5.0 7.0 11.0 10.0 3.0 3.0 3.0 5.0 6.0 5.0 6.0 4.0 3.0 9.0 5.0 6.0 6.0 16.0 8.0 9.0 11.0 7.0 9.0 5.0 6.0 10.0 8.0 3.0 8.0 9.0 Old System Background Average 4.0 6.0 7.5 6.5 2.5 2.5 4.0 4.0 5.0 3.5 5.0 3.0 2.5 8.0 4.5 4.5 5.0 12.5 6.0 6.5 9.0 5.5 5.5 4.0 5.0 9.0 6.0 3.0 5.5 7.0 Old System Net Reading 0.0 0.0 0.0 0.0 0.5 0.5 2.0 0.0 1.0 1.5 1.0 1.0 2.5 0.0 3.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 2.0 0.0 0.0 0.0 2.0 0.0 0.0 Control Efficiency (%) 99.57% 99.64% 99.52% 99.95% 99.77% 99.63% 99.59% 99.50% 99.39% 99.37% 99.34% 99.55% 99.49% 98.48% 98.82% 99.22% 99.50% 99.43% 99.31% 99.68% 99.14% 99.55% 99.40% 99.19% 99.48% 99.66% 99.55% 98.32% 99.11% 98.80% New System Lead Filter Inlet 3510.0 460.0 3711.0 4615.0 4512.0 2453.0 3243.0 2350.0 4711.0 3211.0 4112.0 7893.0 7916.0 5284.0 6308.0 7612.0 2278.0 2169.0 7912.0 6127.0 2828.0 3436.0 2166.0 3374.0 2677.0 6371.0 6132.0 3241.0 4295.0 5020.0 New System Between Filters New System Lag Filter Outlet 6.0 4.0 4.0 5.0 4.0 6.0 3.0 4.0 12.0 8.0 8.0 6.0 9.0 7.0 5.0 4.0 9.0 5.0 8.0 4.0 10.0 5.0 13.0 7.0 21.0 9.0 10.0 11.0 11.0 12.0 17.0 10.0 13.0 5.0 10.0 2.0 12.0 9.0 17.0 8.0 6.0 4.0 19.0 4.0 9.0 4.0 13.0 4.0 18.0 5.0 10.0 5.0 6.0 7.0 3.0 5.0 3.0 4.0 3.0 4.0 New System Background Minimum 7.0 7.0 6.0 8.0 17.0 11.0 13.0 5.0 12.0 5.0 12.0 8.0 7.0 9.0 7.0 9.0 3.0 6.0 7.0 4.0 7.0 6.0 4.0 4.0 7.0 12.0 18.0 4.0 4.0 3.0 New System Background Maximum 13.0 15.0 18.0 15.0 25.0 31.0 21.0 6.0 23.0 16.0 23.0 14.0 14.0 10.0 8.0 14.0 12.0 7.0 12.0 18.0 16.0 13.0 10.0 12.0 9.0 23.0 24.0 10.0 12.0 10.0 New System Background Average 10.0 11.0 12.0 11.5 21.0 21.0 17.0 5.5 17.5 10.5 17.5 11.0 10.5 9.5 7.5 11.5 7.5 6.5 9.5 11.0 11.5 9.5 7.0 8.0 8.0 17.5 21.0 7.0 8.0 6.5 New System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.5 4.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.89% 98.91% 99.84% 99.91% 99.82% 99.76% 99.78% 99.83% 99.89% 99.88% 99.88% 99.91% 99.89% 99.79% 99.81% 99.87% 99.78% 99.91% 99.89% 99.87% 99.86% 99.88% 99.82% 99.88% 99.81% 99.92% 99.89% 99.85% 99.91% 99.92% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Carlos Martinez Carlos Martinez Carlos Martinez Carlos Martinez Carlos Martinez Carlos Martinez Carlos Martinez Eduardo Chavez Eduardo Chavez Jerid Heath Jerid Heath Eduardo Chavez Oni Ruiz Oni Ruiz Eduardo Chavez Jewel Husselman Homer Trujillo Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Carlos Martinez Josh Beydo Josh Beydo Josh Beydo Josh Beydo EPA Inspection Report - Page 1007 of 1969 2018 API Carbon Canister Monitoring for Month: December Monitoring Date 1-Dec 2-Dec 3-Dec 4-Dec 5-Dec 6-Dec 7-Dec 8-Dec 9-Dec 10-Dec 11-Dec 12-Dec 13-Dec 14-Dec 15-Dec 16-Dec 17-Dec 18-Dec 19-Dec 20-Dec 21-Dec 22-Dec 23-Dec 24-Dec 25-Dec 26-Dec 27-Dec 28-Dec 29-Dec 30-Dec 31-Dec Old System Lead Filter Inlet 835.0 630.0 225.0 467.0 512.0 548.0 397.0 468.0 421.0 463.0 419.0 426.0 319.0 321.0 571.0 643.0 444.0 418.0 437.0 451.0 165.0 323.0 335.0 523.0 381.0 246.0 181.0 215.0 17.0 203.0 187.0 Old System Lead Filter Outlet 6.0 9.0 10.0 5.0 5.0 5.0 5.0 5.0 4.0 6.0 4.0 4.0 5.0 6.0 9.0 7.0 8.0 6.0 9.0 6.0 7.0 6.0 5.0 11.0 12.0 9.0 7.0 10.0 11.0 9.0 8.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 6.0 3.0 9.0 4.0 11.0 5.0 5.0 3.0 5.0 4.0 5.0 4.0 5.0 4.0 5.0 4.0 4.0 3.0 6.0 5.0 4.0 6.0 4.0 6.0 5.0 4.0 6.0 5.0 9.0 3.0 7.0 2.0 8.0 2.0 6.0 9.0 9.0 3.0 5.0 5.0 7.0 4.0 6.0 2.0 5.0 3.0 13.0 11.0 12.0 6.0 8.0 4.0 7.0 4.0 10.0 8.0 10.0 5.0 6.0 5.0 8.0 4.0 Old System Background Minimum 2.0 3.0 3.0 3.0 4.0 4.0 3.0 3.0 3.0 4.0 6.0 6.0 6.0 5.0 5.0 2.0 4.0 9.0 4.0 7.0 3.0 4.0 4.0 4.0 3.0 4.0 4.0 2.0 3.0 3.0 3.0 Old System Background Maximum 4.0 10.0 13.0 5.0 5.0 5.0 4.0 4.0 5.0 6.0 7.0 5.0 8.0 7.0 7.0 4.0 9.0 11.0 7.0 12.0 6.0 6.0 7.0 11.0 9.0 9.0 11.0 9.0 7.0 9.0 6.0 Old System Background Average 3.0 6.5 8.0 4.0 4.5 4.5 3.5 3.5 4.0 5.0 6.5 5.5 7.0 6.0 6.0 3.0 6.5 10.0 5.5 9.5 4.5 5.0 5.5 7.5 6.0 6.5 7.5 5.5 5.0 6.0 4.5 Old System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.5 0.5 0.0 0.0 0.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 3.5 0.0 0.0 0.0 2.5 0.0 0.0 0.0 Control Efficiency (%) 99.64% 99.37% 97.78% 99.36% 99.22% 99.27% 98.99% 99.15% 99.29% 98.92% 98.57% 98.59% 98.75% 98.44% 99.47% 99.69% 99.55% 97.85% 99.31% 98.89% 97.58% 99.38% 99.10% 97.90% 98.43% 98.37% 97.79% 96.28% 70.59% 97.54% 97.86% New System Lead Filter Inlet 2633.0 4468.0 1426.0 1175.0 3566.0 1844.0 2148.0 1148.0 1139.0 3278.0 5241.0 4284.0 4263.0 4265.0 2155.0 2471.0 2353.0 3716.0 2467.0 4711.0 2400.0 2451.0 2641.0 1386.0 1113.0 2023.0 2418.0 9461.0 4210.0 4652.0 2414.0 New System Between Filters New System Lag Filter Outlet 16.0 4.0 17.0 5.0 5.0 5.0 8.0 5.0 5.0 3.0 6.0 4.0 7.0 3.0 10.0 3.0 7.0 3.0 9.0 8.0 8.0 7.0 10.0 8.0 8.0 7.0 10.0 12.0 13.0 4.0 13.0 4.0 9.0 5.0 5.0 6.0 7.0 5.0 8.0 5.0 2.0 3.0 2.0 2.0 4.0 2.0 7.0 8.0 2.0 3.0 2.0 3.0 2.0 2.0 4.0 2.0 0.0 1.0 2.0 1.0 7.0 5.0 New System Background Minimum 3.0 4.0 4.0 4.0 7.0 8.0 2.0 3.0 3.0 5.0 8.0 7.0 9.0 7.0 2.0 5.0 6.0 14.0 11.0 12.0 4.0 5.0 4.0 7.0 4.0 4.0 3.0 3.0 3.0 4.0 5.0 New System Background Maximum 7.0 8.0 11.0 5.0 18.0 16.0 3.0 5.0 8.0 6.0 9.0 9.0 10.0 8.0 18.0 10.0 14.0 25.0 18.0 19.0 11.0 11.0 13.0 10.0 13.0 13.0 8.0 6.0 9.0 11.0 7.0 New System Background Average 5.0 6.0 7.5 4.5 12.5 12.0 2.5 4.0 5.5 5.5 8.5 8.0 9.5 7.5 10.0 7.5 10.0 19.5 14.5 15.5 7.5 8.0 8.5 8.5 8.5 8.5 5.5 4.5 6.0 7.5 6.0 New System Net Reading 0.0 0.0 0.0 0.5 0.0 0.0 0.5 0.0 0.0 2.5 0.0 0.0 0.0 4.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.85% 99.89% 99.65% 99.57% 99.92% 99.78% 99.86% 99.74% 99.74% 99.76% 99.87% 99.81% 99.84% 99.72% 99.81% 99.84% 99.79% 99.84% 99.80% 99.89% 99.88% 99.92% 99.92% 99.42% 99.73% 99.85% 99.92% 99.98% 99.98% 99.98% 99.79% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Oni Ruiz Oni Ruiz Josh Beydo Jose Nava Jose Nava Jose Nava Jose Nava Jose Nava Jose Nava Jerid Heath Jerid Heath Jerid Heath Jerid Heath Jerid Heath Oni Ruiz Oni Ruiz Isaac Sanchez Carlos Martinez Isaac Sanchez Carlos Martinez Isaac Sanchez Isaac Sanchez Isaac Sanchez Josh Beydo Josh Beydo Josh Beydo Josh Beydo Eduardo Chavez Josh Beydo Josh Beydo Isaac Sanchez EPA Inspection Report - Page 1008 of 1969 2019 API Carbon Canister Monitoring for Month: January Monitoring Date 1-Jan 2-Jan 3-Jan 4-Jan 5-Jan 6-Jan 7-Jan 8-Jan 9-Jan 10-Jan 11-Jan 12-Jan 13-Jan 14-Jan 15-Jan 16-Jan 17-Jan 18-Jan 19-Jan 20-Jan 21-Jan 22-Jan 23-Jan 24-Jan 25-Jan 26-Jan 27-Jan 28-Jan 29-Jan 30-Jan 31-Jan Old System Lead Filter Inlet 361.0 111.0 102.0 154.0 147.0 118.0 122.0 91.0 95.0 142.0 260.0 418.0 318.0 188.0 210.0 190.0 190.0 155.0 164.0 101.0 261.0 380.0 253.0 98.0 562.0 319.0 386.0 512.0 165.0 121.0 322.0 Old System Lead Filter Outlet 7.0 9.0 4.0 5.0 6.0 6.0 6.0 5.0 6.0 5.0 9.0 6.0 7.0 6.0 5.0 6.0 8.0 7.0 6.0 8.0 9.0 8.0 18.0 2.0 6.0 6.0 9.0 5.0 5.0 9.0 4.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 7.0 4.0 6.0 3.0 4.0 4.0 5.0 2.0 6.0 2.0 6.0 4.0 5.0 3.0 5.0 2.0 6.0 3.0 5.0 6.0 8.0 4.0 6.0 4.0 6.0 6.0 6.0 4.0 5.0 3.0 5.0 3.0 8.0 4.0 7.0 2.0 6.0 3.0 7.0 3.0 9.0 5.0 8.0 4.0 16.0 8.0 4.0 6.0 6.0 4.0 6.0 2.0 9.0 6.0 5.0 4.0 6.0 7.0 8.0 6.0 4.0 3.0 Old System Background Minimum 3.0 3.0 3.0 3.0 3.0 4.0 4.0 1.0 3.0 4.0 4.0 3.0 5.0 5.0 4.0 4.0 3.0 4.0 5.0 5.0 3.0 3.0 5.0 4.0 3.0 4.0 7.0 5.0 4.0 4.0 4.0 Old System Background Maximum 8.0 10.0 8.0 4.0 7.0 7.0 19.0 8.0 8.0 8.0 7.0 10.0 8.0 8.0 7.0 6.0 7.0 8.0 6.0 7.0 14.0 4.0 9.0 9.0 6.0 7.0 13.0 6.0 5.0 11.0 5.0 Old System Background Average 5.5 6.5 5.5 3.5 5.0 5.5 11.5 4.5 5.5 6.0 5.5 6.5 6.5 6.5 5.5 5.0 5.0 6.0 5.5 6.0 8.5 3.5 7.0 6.5 4.5 5.5 10.0 5.5 4.5 7.5 4.5 Old System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.5 1.0 0.0 0.0 0.0 0.0 0.0 2.5 0.0 0.0 Control Efficiency (%) 98.89% 97.30% 96.08% 98.70% 98.64% 96.61% 97.54% 97.80% 96.84% 95.77% 98.46% 99.04% 98.11% 97.87% 98.57% 98.42% 97.89% 98.71% 98.17% 97.03% 98.08% 98.95% 96.84% 93.88% 99.29% 99.37% 98.45% 99.22% 95.76% 95.04% 99.07% New System Lead Filter Inlet 2960.0 816.0 2537.0 6412.0 5312.0 4317.0 1431.0 2539.0 8966.0 8257.0 4671.0 37916.0 4112.0 3211.0 2515.0 3316.0 6317.0 3317.0 4610.0 6317.0 2469.0 3500.0 1700.0 6473.0 1496.0 1873.0 2658.0 1372.0 5243.0 2148.0 1395.0 New System Between Filters New System Lag Filter Outlet 11.0 2.0 1.0 2.0 1.0 3.0 2.0 3.0 2.0 4.0 3.0 5.0 5.0 4.0 2.0 3.0 2.0 3.0 5.0 3.0 3.0 3.0 6.0 4.0 7.0 6.0 3.0 4.0 3.0 5.0 2.0 4.0 3.0 6.0 3.0 4.0 3.0 5.0 2.0 7.0 17.0 4.0 15.0 4.0 4.0 3.0 3.0 3.0 12.0 6.0 14.0 5.0 18.0 4.0 14.0 9.0 12.0 11.0 5.0 7.0 11.0 5.0 New System Background Minimum 2.0 2.0 2.0 2.0 3.0 4.0 7.0 3.0 4.0 5.0 5.0 7.0 8.0 6.0 5.0 4.0 5.0 5.0 6.0 8.0 6.0 6.0 5.0 2.0 5.0 6.0 10.0 5.0 13.0 6.0 6.0 New System Background Maximum 7.0 9.0 6.0 6.0 8.0 12.0 11.0 9.0 10.0 11.0 11.0 12.0 12.0 10.0 7.0 9.0 11.0 6.0 10.0 11.0 10.0 9.0 9.0 10.0 9.0 8.0 19.0 6.0 15.0 13.0 9.0 New System Background Average 4.5 5.5 4.0 4.0 5.5 8.0 9.0 6.0 7.0 8.0 8.0 9.5 10.0 8.0 6.0 6.5 8.0 5.5 8.0 9.5 8.0 7.5 7.0 6.0 7.0 7.0 14.5 5.5 14.0 9.5 7.5 New System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 3.5 0.0 0.0 0.0 Control Efficiency (%) 99.93% 99.75% 99.88% 99.95% 99.92% 99.88% 99.72% 99.88% 99.97% 99.96% 99.94% 99.99% 99.85% 99.88% 99.80% 99.88% 99.91% 99.88% 99.89% 99.89% 99.84% 99.89% 99.82% 99.95% 99.60% 99.73% 99.85% 99.34% 99.79% 99.67% 99.64% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Oni Ruiz Josh Baydo Josh Baydo Josh Baydo Isaac Sanchez Isaac Sanchez Carlos Martinez Josh Baydo Josh Baydo Josh Baydo Isaac Sanchez Carlos Martinez Carlos Martinez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Oni Ruiz Oni Ruiz Homer Trujillo Josh Baydo Jose Nava Oni Ruiz Oni Ruiz Jose Nava Jerid Heath Josh Baydo Jose Nava EPA Inspection Report - Page 1009 of 1969 2019 API Carbon Canister Monitoring for Month: February Monitoring Date 1-Feb 2-Feb 3-Feb 4-Feb 5-Feb 6-Feb 7-Feb 8-Feb 9-Feb 10-Feb 11-Feb 12-Feb 13-Feb 14-Feb 15-Feb 16-Feb 17-Feb 18-Feb 19-Feb 20-Feb 21-Feb 22-Feb 23-Feb 24-Feb 25-Feb 26-Feb 27-Feb 28-Feb Old System Lead Filter Inlet 247.0 427.0 359.0 143.0 321.0 284.0 236.0 201.0 396.0 461.0 171.0 233.0 246.0 205.0 295.0 177.0 330.0 291.0 412.0 341.0 451.0 271.0 337.0 276.0 622.0 221.0 345.0 304.0 Old System Lead Filter Outlet 6.0 5.0 5.0 5.0 6.0 5.0 5.0 5.0 7.0 9.0 10.0 10.0 6.0 7.0 11.0 9.0 12.0 8.0 4.0 5.0 5.0 5.0 9.0 6.0 4.0 4.0 14.0 12.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 6.0 4.0 5.0 4.0 5.0 3.0 5.0 6.0 6.0 7.0 5.0 7.0 5.0 7.0 5.0 2.0 7.0 3.0 9.0 6.0 10.0 3.0 10.0 4.0 6.0 5.0 7.0 3.0 10.0 6.0 9.0 2.0 12.0 2.0 7.0 4.0 4.0 3.0 4.0 4.0 6.0 6.0 4.0 4.0 9.0 4.0 6.0 4.0 4.0 5.0 4.0 3.0 14.0 7.0 12.0 13.0 Old System Background Minimum 3.0 3.0 2.0 6.0 6.0 6.0 6.0 3.0 5.0 3.0 3.0 4.0 5.0 3.0 4.0 3.0 3.0 4.0 3.0 4.0 4.0 3.0 5.0 2.0 4.0 7.0 4.0 14.0 Old System Background Maximum 4.0 4.0 4.0 8.0 7.0 7.0 7.0 5.0 18.0 27.0 5.0 9.0 7.0 5.0 13.0 9.0 9.0 8.0 5.0 10.0 7.0 6.0 13.0 7.0 8.0 10.0 17.0 19.0 Old System Background Average 3.5 3.5 3.0 7.0 6.5 6.5 6.5 4.0 11.5 15.0 4.0 6.5 6.0 4.0 8.5 6.0 6.0 6.0 4.0 7.0 5.5 4.5 9.0 4.5 6.0 8.5 10.5 16.5 Old System Net Reading 0.5 0.5 0.0 0.0 0.5 0.5 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 98.38% 99.06% 99.16% 95.80% 97.82% 97.54% 97.03% 99.00% 99.24% 98.70% 98.25% 98.28% 97.97% 98.54% 97.97% 98.87% 99.39% 98.63% 99.27% 98.83% 98.67% 98.52% 98.81% 98.55% 99.20% 98.64% 97.97% 95.72% New System Lead Filter Inlet 1169.0 1782.0 1168.0 3219.0 2464.0 3243.0 2393.0 4316.0 3781.0 2650.0 3519.0 4616.0 5219.0 3317.0 2671.0 2331.0 2651.0 3411.0 1258.0 2378.0 3246.0 3220.0 3960.0 2871.0 7090.0 4371.0 4637.0 3511.0 New System Between Filters New System Lag Filter Outlet 15.0 6.0 12.0 6.0 14.0 5.0 11.0 10.0 11.0 9.0 11.0 10.0 13.0 11.0 3.0 5.0 19.0 5.0 10.0 4.0 6.0 7.0 7.0 8.0 8.0 6.0 4.0 3.0 6.0 5.0 17.0 5.0 11.0 4.0 9.0 5.0 14.0 7.0 15.0 7.0 12.0 5.0 14.0 6.0 17.0 3.0 18.0 5.0 12.0 7.0 9.0 5.0 8.0 8.0 7.0 10.0 New System Background Minimum 7.0 5.0 9.0 10.0 9.0 10.0 10.0 4.0 6.0 2.0 10.0 10.0 10.0 5.0 7.0 6.0 4.0 7.0 7.0 12.0 7.0 8.0 7.0 3.0 6.0 9.0 13.0 11.0 New System Background Maximum 10.0 9.0 13.0 12.0 10.0 11.0 12.0 13.0 15.0 12.0 16.0 17.0 13.0 13.0 17.0 20.0 15.0 12.0 10.0 18.0 16.0 16.0 19.0 34.0 10.0 17.0 20.0 21.0 New System Background Average 8.5 7.0 11.0 11.0 9.5 10.5 11.0 8.5 10.5 7.0 13.0 13.5 11.5 9.0 12.0 13.0 9.5 9.5 8.5 15.0 11.5 12.0 13.0 18.5 8.0 13.0 16.5 16.0 New System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.49% 99.66% 99.57% 99.69% 99.63% 99.69% 99.54% 99.88% 99.87% 99.85% 99.80% 99.83% 99.89% 99.91% 99.81% 99.79% 99.85% 99.85% 99.44% 99.71% 99.85% 99.81% 99.92% 99.83% 99.90% 99.89% 99.83% 99.72% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Jose Nava Jose Nava Jose Nava Jerid Heath Jerid Heath Jerid Heath Jerid Heath Isaac Sanchez Oni Ruiz Oni Ruiz Oni Ruiz Isaac Sanchez Jerid Heath Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Carlos Martinez Jose Nava Carlos Martinez Carlos Martinez Carlos Martinez Oni Ruiz Oni Ruiz Eduardo Chavez Carlos Martinez Carlos Martinez Isaac Sanchez EPA Inspection Report - Page 1010 of 1969 2019 API Carbon Canister Monitoring for Month: March Monitoring Date 1-Mar 2-Mar 3-Mar 4-Mar 5-Mar 6-Mar 7-Mar 8-Mar 9-Mar 10-Mar 11-Mar 12-Mar 13-Mar 14-Mar 15-Mar 16-Mar 17-Mar 18-Mar 19-Mar 20-Mar 21-Mar 22-Mar 23-Mar 24-Mar 25-Mar 26-Mar 27-Mar 28-Mar 29-Mar 30-Mar 31-Mar Old System Lead Filter Inlet 154.0 189.0 253.0 179.0 140.0 450.0 342.0 276.0 394.0 274.0 99.0 122.0 379.0 379.0 150.0 171.0 137.0 361.0 101.0 92.0 233.0 141.0 64.0 147.0 171.0 362.0 217.0 241.0 210.0 261.0 311.0 Old System Lead Filter Outlet 11.0 10.0 15.0 9.0 10.0 6.0 7.0 11.0 6.0 9.0 6.0 7.0 8.0 8.0 5.0 5.0 6.0 7.0 4.0 5.0 10.0 6.0 4.0 10.0 7.0 5.0 5.0 6.0 12.0 7.0 8.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 11.0 4.0 10.0 2.0 15.0 6.0 9.0 5.0 10.0 7.0 9.0 7.0 7.0 6.0 10.0 6.0 6.0 5.0 9.0 3.0 5.0 4.0 6.0 5.0 8.0 4.0 8.0 4.0 5.0 3.0 5.0 4.0 6.0 4.0 7.0 2.0 4.0 3.0 5.0 3.0 10.0 4.0 6.0 4.0 4.0 2.0 10.0 4.0 7.0 3.0 5.0 3.0 5.0 4.0 6.0 3.0 7.0 7.0 7.0 5.0 8.0 4.0 Old System Background Minimum 3.0 3.0 10.0 3.0 5.0 5.0 6.0 2.0 6.0 2.0 3.0 4.0 6.0 6.0 3.0 4.0 5.0 2.0 2.0 2.0 3.0 2.0 2.0 3.0 5.0 4.0 2.0 3.0 7.0 2.0 9.0 Old System Background Maximum 7.0 6.0 17.0 11.0 11.0 12.0 8.0 3.0 7.0 14.0 9.0 7.0 27.0 27.0 4.0 9.0 11.0 7.0 5.0 3.0 7.0 7.0 3.0 7.0 9.0 6.0 4.0 5.0 13.0 6.0 17.0 Old System Background Average 5.0 4.5 13.5 7.0 8.0 8.5 7.0 2.5 6.5 8.0 6.0 5.5 16.5 16.5 3.5 6.5 8.0 4.5 3.5 2.5 5.0 4.5 4.0 5.0 7.0 4.0 3.0 4.0 10.0 4.0 13.0 Old System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 3.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 1.0 0.0 0.0 1.0 0.0 Control Efficiency (%) 97.40% 98.94% 97.63% 97.21% 95.00% 98.44% 98.25% 97.83% 98.73% 98.91% 95.96% 95.90% 98.94% 98.94% 98.00% 97.66% 97.08% 99.45% 97.03% 96.74% 98.28% 97.16% 96.88% 97.28% 98.25% 99.17% 98.16% 98.76% 96.67% 98.08% 98.71% New System Lead Filter Inlet 2569.0 6314.0 6123.0 20100.0 9184.0 9365.0 7234.0 3246.0 3479.0 3500.0 3124.0 6327.0 2868.0 2868.0 8658.0 3678.0 3361.0 3317.0 4371.0 2719.0 4671.0 1799.0 3213.0 3310.0 2749.0 6941.0 2043.0 2093.0 7132.0 2287.0 2463.0 New System Between Filters New System Lag Filter Outlet 10.0 3.0 11.0 7.0 19.0 5.0 5.0 4.0 5.0 5.0 6.0 7.0 11.0 10.0 5.0 5.0 13.0 4.0 15.0 3.0 2.0 4.0 4.0 5.0 13.0 5.0 13.0 5.0 4.0 3.0 6.0 4.0 7.0 4.0 14.0 8.0 7.0 3.0 8.0 5.0 11.0 6.0 9.0 4.0 8.0 3.0 13.0 8.0 3.0 4.0 11.0 8.0 10.0 7.0 10.0 7.0 3.0 5.0 18.0 4.0 14.0 3.0 New System Background Minimum 6.0 3.0 13.0 6.0 6.0 4.0 9.0 9.0 3.0 3.0 4.0 5.0 9.0 9.0 4.0 8.0 8.0 5.0 2.0 7.0 6.0 6.0 4.0 7.0 6.0 8.0 6.0 8.0 8.0 4.0 5.0 New System Background Maximum 13.0 13.0 24.0 14.0 12.0 14.0 11.0 17.0 9.0 19.0 11.0 11.0 12.0 12.0 5.0 13.0 14.0 11.0 10.0 16.0 13.0 19.0 6.0 19.0 13.0 10.0 9.0 12.0 11.0 6.0 12.0 New System Background Average 9.5 8.0 18.5 10.0 9.0 9.0 10.0 13.0 6.0 11.0 7.5 8.0 10.5 10.5 4.5 10.5 11.0 8.0 6.0 11.5 9.5 12.5 5.0 13.0 9.5 9.0 7.5 10.0 9.5 5.0 8.5 New System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.88% 99.89% 99.92% 99.98% 99.95% 99.93% 99.86% 99.85% 99.89% 99.91% 99.87% 99.92% 99.83% 99.83% 99.97% 99.89% 99.88% 99.76% 99.93% 99.82% 99.87% 99.78% 99.91% 99.76% 99.85% 99.88% 99.66% 99.67% 99.93% 99.83% 99.88% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Isaac Sanchez Isaac Sanchez Isaac Sanchez Josh Baydo Josh Baydo Josh Baydo Jerid Heath Carlos Martinez Oni Ruiz Oni Ruiz Josh Baydo Josh Baydo Oni Ruiz Oni Ruiz Carlos Martinez Carlos Martinez Carlos Martinez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Josh Baydo Eduardo Chavez Eduardo Chavez Eduardo Chavez Josh Baydo Oni Ruiz Oni Ruiz EPA Inspection Report - Page 1011 of 1969 2019 API Carbon Canister Monitoring for Month: April Monitoring Date 1-Apr 2-Apr 3-Apr 4-Apr 5-Apr 6-Apr 7-Apr 8-Apr 9-Apr 10-Apr 11-Apr 12-Apr 13-Apr 14-Apr 15-Apr 16-Apr 17-Apr 18-Apr 19-Apr 20-Apr 21-Apr 22-Apr 23-Apr 24-Apr 25-Apr 26-Apr 27-Apr 28-Apr 29-Apr 30-Apr Old System Lead Filter Inlet 419.0 115.0 121.0 422.0 349.0 412.0 527.0 563.0 400.0 423.0 295.0 271.0 350.0 337.0 249.0 401.0 241.0 167.0 172.0 247.0 265.0 267.0 329.0 162.0 356.0 257.0 121.0 214.0 340.0 335.0 Old System Lead Filter Outlet 10.0 5.0 8.0 8.0 4.0 5.0 4.0 8.0 10.0 9.0 8.0 7.0 4.0 9.0 6.0 3.0 5.0 4.0 5.0 9.0 8.0 6.0 5.0 8.0 6.0 5.0 7.0 7.0 10.0 8.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 6.0 10.0 5.0 2.0 8.0 6.0 8.0 6.0 4.0 3.0 4.0 3.0 4.0 4.0 8.0 5.0 10.0 6.0 9.0 3.0 8.0 4.0 7.0 4.0 4.0 2.0 9.0 5.0 6.0 4.0 3.0 1.0 5.0 3.0 4.0 2.0 5.0 8.0 9.0 5.0 8.0 4.0 6.0 4.0 5.0 7.0 8.0 6.0 6.0 4.0 5.0 6.0 7.0 5.0 7.0 3.0 10.0 6.0 7.0 5.0 Old System Background Minimum 5.0 2.0 2.0 5.0 9.0 3.0 4.0 4.0 4.0 3.0 4.0 3.0 3.0 3.0 4.0 2.0 3.0 2.0 9.0 7.0 3.0 5.0 7.0 4.0 4.0 5.0 4.0 4.0 2.0 3.0 Old System Background Maximum 13.0 4.0 7.0 10.0 11.0 5.0 6.0 11.0 8.0 8.0 9.0 9.0 7.0 10.0 5.0 6.0 5.0 7.0 25.0 18.0 16.0 9.0 9.0 7.0 10.0 6.0 8.0 12.0 8.0 7.0 Old System Background Average 9.0 3.0 4.5 7.5 10.0 4.0 5.0 7.5 6.0 5.5 6.5 6.0 5.0 6.5 4.5 4.0 4.0 4.5 17.0 12.5 9.5 7.0 8.0 5.5 7.0 5.5 6.0 8.0 5.0 5.0 Old System Net Reading 1.0 0.0 1.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.5 0.0 0.5 0.0 0.0 1.0 0.0 Control Efficiency (%) 97.61% 98.26% 95.04% 98.58% 99.14% 99.27% 99.24% 99.11% 98.50% 99.29% 98.64% 98.52% 99.43% 98.52% 98.39% 99.75% 98.76% 98.80% 95.35% 97.98% 98.49% 98.50% 97.87% 96.30% 98.88% 97.67% 95.87% 98.60% 98.24% 98.51% New System Lead Filter Inlet 2722.0 2314.0 2139.0 5132.0 1478.0 4687.0 2346.0 15500.0 1748.0 5138.0 10000.0 7320.0 5320.0 4341.0 6981.0 8600.0 3314.0 4716.0 8114.0 9942.0 8963.0 5243.0 4289.0 6640.0 4766.0 3386.0 4728.0 8661.0 732.0 8433.0 New System Between Filters New System Lag Filter Outlet 2.0 5.0 2.0 5.0 4.0 5.0 6.0 5.0 15.0 7.0 17.0 8.0 15.0 8.0 4.0 4.0 7.0 6.0 7.0 7.0 5.0 5.0 6.0 6.0 7.0 6.0 7.0 6.0 12.0 8.0 15.0 9.0 11.0 8.0 16.0 10.0 23.0 17.0 34.0 11.0 21.0 7.0 10.0 7.0 12.0 11.0 11.0 9.0 5.0 5.0 10.0 12.0 14.0 11.0 19.0 14.0 7.0 5.0 6.0 10.0 New System Background Minimum 4.0 5.0 7.0 6.0 6.0 8.0 9.0 3.0 5.0 4.0 3.0 4.0 4.0 7.0 8.0 5.0 5.0 5.0 14.0 13.0 19.0 9.0 9.0 9.0 3.0 9.0 10.0 8.0 5.0 6.0 New System Background Maximum 12.0 8.0 13.0 12.0 9.0 9.0 10.0 12.0 13.0 12.0 11.0 11.0 11.0 19.0 10.0 9.0 11.0 13.0 31.0 26.0 24.0 11.0 10.0 13.0 11.0 11.0 16.0 15.0 11.0 8.0 New System Background Average 8.0 6.5 10.0 9.0 7.5 8.5 9.5 7.5 9.0 8.0 7.0 7.5 7.5 13.0 9.0 7.0 8.0 9.0 22.5 19.5 21.5 10.0 9.5 11.0 7.0 10.0 13.0 11.5 8.0 7.0 New System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 2.0 0.0 1.0 0.0 0.0 0.0 0.0 1.5 0.0 0.0 2.0 0.0 2.5 0.0 3.0 Control Efficiency (%) 99.82% 99.78% 99.77% 99.90% 99.53% 99.83% 99.66% 99.97% 99.66% 99.86% 99.95% 99.92% 99.89% 99.86% 99.89% 99.90% 99.76% 99.79% 99.79% 99.89% 99.92% 99.87% 99.74% 99.86% 99.90% 99.65% 99.77% 99.84% 99.32% 99.88% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Josh Baydo Isaac Sanchez Isaac Sanchez Josh Baydo Jose Nava Jose Nava Jose Nava Josh Baydo Marcus Morris Josh Baydo Josh Baydo Josh Baydo Isaac Sanchez Isaac Sanchez Eduardo Chavez Eduardo Chavez Isaac Sanchez Eduardo Chavez Eduardo Chavez Oni Ruiz Oni Ruiz Jerid Heath Jerid Heath Eduardo Chavez Josh Baydo Jerid Heath Eduardo Chavez Eduardo Chavez Marcus Morris Marcus Morris EPA Inspection Report - Page 1012 of 1969 2019 API Carbon Canister Monitoring for Month: May Monitoring Date 1-May 2-May 3-May 4-May 5-May 6-May 7-May 8-May 9-May 10-May 11-May 12-May 13-May 14-May 15-May 16-May 17-May 18-May 19-May 20-May 21-May 22-May 23-May 24-May 25-May 26-May 27-May 28-May 29-May 30-May 31-May Old System Lead Filter Inlet 394.0 169.0 413.0 261.0 385.0 181.0 70.0 236.0 298.0 212.0 391.0 284.0 341.0 157.0 203.0 328.0 332.0 281.0 298.0 211.0 346.0 177.0 214.0 208.0 198.0 168.0 493.0 542.0 290.0 385.0 247.0 Old System Lead Filter Outlet 9.0 5.0 11.0 8.0 9.0 6.0 9.0 8.0 10.0 7.0 9.0 7.0 6.0 4.0 3.0 6.0 6.0 5.0 9.0 7.0 7.0 9.0 8.0 6.0 8.0 6.0 10.0 6.0 14.0 7.0 13.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 5.0 10.0 5.0 3.0 10.0 6.0 8.0 4.0 9.0 6.0 6.0 4.0 9.0 3.0 8.0 3.0 10.0 3.0 7.0 3.0 9.0 6.0 7.0 5.0 6.0 5.0 4.0 6.0 3.0 5.0 6.0 5.0 7.0 6.0 5.0 6.0 9.0 5.0 7.0 4.0 7.0 6.0 9.0 6.0 8.0 5.0 6.0 4.0 8.0 5.0 6.0 4.0 10.0 5.0 5.0 8.0 13.0 8.0 7.0 4.0 13.0 5.0 Old System Background Minimum 3.0 2.0 7.0 3.0 7.0 4.0 2.0 3.0 2.0 2.0 8.0 3.0 8.0 7.0 5.0 6.0 5.0 4.0 6.0 4.0 4.0 3.0 2.0 5.0 3.0 3.0 3.0 4.0 15.0 4.0 2.0 Old System Background Maximum 7.0 8.0 9.0 14.0 10.0 6.0 7.0 9.0 8.0 7.0 25.0 14.0 14.0 9.0 7.0 10.0 9.0 7.0 23.0 6.0 12.0 7.0 7.0 7.0 6.0 9.0 7.0 11.0 165.0 12.0 7.0 Old System Background Average 5.0 5.0 8.0 8.5 8.5 5.0 4.5 6.0 5.0 9.8 16.5 8.5 11.0 8.0 6.0 8.0 7.0 5.5 14.5 5.0 8.0 5.0 4.5 6.0 4.5 6.0 5.0 7.5 90.0 8.0 4.5 Old System Net Reading 5.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.5 0.0 0.0 0.0 1.0 0.5 0.0 0.5 0.0 0.0 0.5 0.0 0.0 0.5 Control Efficiency (%) 97.46% 98.22% 98.55% 98.47% 98.44% 97.79% 95.71% 98.73% 98.99% 98.58% 98.47% 98.24% 98.53% 96.18% 97.54% 98.48% 98.19% 97.86% 98.32% 98.10% 98.27% 96.61% 97.66% 98.08% 97.47% 97.62% 98.99% 98.52% 97.24% 98.96% 97.98% New System Lead Filter Inlet 8495.0 5876.0 8116.0 3659.0 4341.0 5682.0 3126.0 3120.0 3516.0 3014.0 4687.0 2571.0 3671.0 1781.0 2361.0 3211.0 4327.0 3211.0 3877.0 4619.0 3648.0 5699.0 4512.0 3410.0 4368.0 3481.0 3616.0 6492.0 4378.0 4905.0 3027.0 New System Between Filters New System Lag Filter Outlet 5.0 4.0 17.0 12.0 7.0 5.0 17.0 5.0 15.0 3.0 16.0 10.0 5.0 5.0 6.0 5.0 5.0 5.0 4.0 4.0 23.0 7.0 16.0 4.0 8.0 6.0 5.0 4.0 7.0 5.0 7.0 5.0 5.0 4.0 7.0 5.0 16.0 3.0 8.0 4.0 10.0 6.0 15.0 12.0 11.0 8.0 14.0 11.0 9.0 6.0 15.0 10.0 9.0 9.0 4.0 4.0 13.0 10.0 5.0 7.0 5.0 5.0 New System Background Minimum 4.0 10.0 6.0 6.0 10.0 5.0 6.0 3.0 4.0 6.0 10.0 3.0 10.0 8.0 9.0 8.0 5.0 8.0 10.0 6.0 8.0 7.0 9.0 6.0 7.0 7.0 5.0 5.0 10.0 5.0 11.0 New System Background Maximum 9.0 17.0 8.0 19.0 19.0 8.0 16.0 21.0 18.0 13.0 21.0 10.0 19.0 21.0 17.0 15.0 12.0 15.0 13.0 12.0 15.0 14.0 12.0 16.0 12.0 14.0 13.0 13.0 11.0 14.0 19.0 New System Background Average 6.5 13.5 7.0 12.5 14.5 6.5 11.0 12.0 11.0 9.5 15.5 6.5 14.5 14.5 13.0 11.5 8.5 11.5 11.5 9.0 11.5 10.5 10.5 11.0 9.5 10.5 9.0 9.0 10.5 9.5 15.0 New System Net Reading 0.0 0.0 0.0 0.0 0.0 3.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.95% 99.80% 99.94% 99.86% 99.93% 99.82% 99.84% 99.84% 99.86% 99.87% 99.85% 99.84% 99.84% 99.78% 99.79% 99.84% 99.91% 99.84% 99.92% 99.91% 99.84% 99.79% 99.82% 99.68% 99.86% 99.71% 99.75% 99.94% 99.77% 99.86% 99.83% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Marcus Morris Eduardo Chavez Marcus Morris Oni Ruiz Oni Ruiz Eduardo Chavez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Oni Ruiz Oni Ruiz Carlos Martinez Carlos Martinez Carlos Martinez Marcus Morris Marcus Morris Carlos Martinez Oni Ruiz Eduardo Chavez Eduardo Chavez Eduardo Chavez Eduardo Chavez Eduardo Chavez Eduardo Chavez Eduardo Chavez Isaac Sanchez Josh Baydo Marcus Morris Josh Baydo Isaac Sanchez EPA Inspection Report - Page 1013 of 1969 2019 API Carbon Canister Monitoring for Month: June Monitoring Date 1-Jun 2-Jun 3-Jun 4-Jun 5-Jun 6-Jun 7-Jun 8-Jun 9-Jun 10-Jun 11-Jun 12-Jun 13-Jun 14-Jun 15-Jun 16-Jun 17-Jun 18-Jun 19-Jun 20-Jun 21-Jun 22-Jun 23-Jun 24-Jun 25-Jun 26-Jun 27-Jun 28-Jun 29-Jun 30-Jun Old System Lead Filter Inlet 315.0 234.0 201.0 366.0 274.0 384.0 388.0 231.0 291.0 329.0 349.0 426.0 439.0 328.0 717.0 412.0 300.0 201.0 199.0 379.0 189.0 416.0 560.0 184.0 318.0 411.0 432.0 518.0 396.0 281.0 Old System Lead Filter Outlet 9.0 11.0 4.0 7.0 8.0 9.0 9.0 8.0 5.0 6.0 7.0 5.0 7.0 8.0 4.0 6.0 7.0 7.0 9.0 8.0 11.0 12.0 14.0 6.0 5.0 8.0 6.0 4.0 9.0 7.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 9.0 3.0 11.0 3.0 4.0 3.0 7.0 4.0 8.0 3.0 9.0 4.0 9.0 3.0 8.0 4.0 5.0 4.0 6.0 5.0 7.0 6.0 5.0 7.0 7.0 9.0 8.0 1.0 4.0 2.0 6.0 4.0 7.0 3.0 7.0 3.0 9.0 3.0 8.0 3.0 11.0 4.0 12.0 3.0 14.0 4.0 6.0 4.0 5.0 6.0 8.0 3.0 6.0 5.0 4.0 3.0 9.0 4.0 7.0 4.0 Old System Background Minimum 2.0 3.0 3.0 4.0 6.0 2.0 2.0 3.0 6.0 5.0 5.0 6.0 8.0 7.0 4.0 7.0 2.0 2.0 4.0 3.0 2.0 4.0 6.0 4.0 4.0 6.0 2.0 3.0 6.0 3.0 Old System Background Maximum 7.0 11.0 9.0 10.0 7.0 4.0 6.0 5.0 12.0 7.0 7.0 8.0 10.0 9.0 7.0 12.0 7.0 7.0 6.0 7.0 6.0 11.0 12.0 10.0 10.0 11.0 8.0 10.0 18.0 8.0 Old System Background Average 4.5 7.0 6.0 7.0 6.5 3.0 4.0 4.0 9.0 6.0 6.0 7.0 9.0 8.0 5.5 9.5 4.5 4.5 5.0 5.0 4.0 7.5 9.0 7.0 7.0 8.5 5.0 6.5 12.0 5.5 Old System Net Reading 0.0 0.0 0.0 0.0 0.0 1.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.05% 98.72% 98.51% 98.91% 98.91% 98.96% 99.23% 98.27% 98.63% 98.48% 98.28% 98.36% 97.95% 99.70% 99.72% 99.03% 99.00% 98.51% 98.49% 99.21% 97.88% 99.28% 99.29% 97.83% 98.11% 99.27% 98.84% 99.42% 98.99% 98.58% New System Lead Filter Inlet 3316.0 2141.0 5342.0 5329.0 2751.0 3311.0 3891.0 2219.0 4781.0 5287.0 3433.0 4289.0 6749.0 4306.0 4378.0 4356.0 3117.0 2132.0 2117.0 2617.0 2014.0 3714.0 3416.0 3680.0 5362.0 6429.0 7612.0 3512.0 3261.0 2469.0 New System Between Filters New System Lag Filter Outlet 4.0 4.0 7.0 7.0 6.0 6.0 8.0 5.0 11.0 5.0 19.0 5.0 22.0 7.0 13.0 4.0 7.0 4.0 11.0 10.0 11.0 9.0 10.0 8.0 12.0 10.0 10.0 9.0 7.0 4.0 8.0 4.0 7.0 4.0 5.0 5.0 4.0 4.0 4.0 5.0 5.0 6.0 16.0 9.0 6.0 5.0 17.0 11.0 4.0 4.0 9.0 6.0 4.0 4.0 3.0 3.0 18.0 5.0 17.0 3.0 New System Background Minimum 5.0 5.0 4.0 7.0 10.0 7.0 9.0 7.0 8.0 8.0 8.0 9.0 10.0 10.0 8.0 9.0 5.0 4.0 7.0 6.0 2.0 8.0 14.0 6.0 5.0 8.0 3.0 3.0 7.0 6.0 New System Background Maximum 13.0 16.0 11.0 14.0 18.0 10.0 24.0 10.0 19.0 9.0 9.0 11.0 13.0 11.0 19.0 17.0 13.0 17.0 14.0 14.0 14.0 19.0 19.0 18.0 13.0 13.0 10.0 13.0 14.0 9.0 New System Background Average 9.0 10.5 7.5 10.5 14.0 8.5 16.5 8.5 13.5 8.5 8.5 10.0 11.5 10.5 13.5 13.0 9.0 10.5 10.5 10.0 8.0 13.5 16.5 12.0 9.0 10.5 6.5 8.0 10.5 7.5 New System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.5 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.88% 99.67% 99.89% 99.91% 99.82% 99.85% 99.82% 99.82% 99.92% 99.81% 99.74% 99.81% 99.85% 99.79% 99.91% 99.91% 99.87% 99.77% 99.81% 99.81% 99.70% 99.76% 99.85% 99.70% 99.93% 99.91% 99.95% 99.91% 99.85% 99.88% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Isaac Sanchez Isaac Sanchez Josh Baydo Marcus Morris Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Carlos Martinez Jerid Heath Jerid Heath Jerid Heath Jerid Heath Jerid Heath Carlos Martinez Carlos Martinez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Isaac Sanchez Eduardo Chavez Josh Baydo Marcus Morris Josh Baydo Josh Baydo Oni Ruiz Oni Ruiz EPA Inspection Report - Page 1014 of 1969 2019 API Carbon Canister Monitoring for Month: July Monitoring Date 1-Jul 2-Jul 3-Jul 4-Jul 5-Jul 6-Jul 7-Jul 8-Jul 9-Jul 10-Jul 11-Jul 12-Jul 13-Jul 14-Jul 15-Jul 16-Jul 17-Jul 18-Jul 19-Jul 20-Jul 21-Jul 22-Jul 23-Jul 24-Jul 25-Jul 26-Jul 27-Jul 28-Jul 29-Jul 30-Jul 31-Jul Old System Lead Filter Inlet 420.0 387.0 342.0 276.0 345.0 377.0 291.0 342.0 422.0 487.0 424.0 241.0 316.0 562.0 310.0 274.0 321.0 216.0 388.0 469.0 192.0 203.0 312.0 198.0 203.0 201.0 233.0 274.0 293.0 261.0 Old System Lead Filter Outlet 7.0 8.0 8.0 8.0 6.0 9.0 7.0 8.0 7.0 5.0 4.0 4.0 10.0 8.0 8.0 9.0 4.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 7.0 4.0 9.0 5.0 9.0 5.0 8.0 4.0 6.0 4.0 9.0 5.0 7.0 4.0 7.0 5.0 7.0 8.0 5.0 6.0 4.0 3.0 4.0 5.0 10.0 4.0 8.0 6.0 8.0 5.0 9.0 3.0 4.0 5.0 5.0 5.0 3.0 8.0 8.0 4.0 10.0 10.0 8.0 6.0 6.0 4.0 6.0 6.0 5.0 6.0 7.0 5.0 5.0 5.0 4.0 6.0 6.0 6.0 4.0 4.0 3.0 5.0 5.0 4.0 8.0 8.0 3.0 6.0 6.0 5.0 7.0 7.0 4.0 Old System Background Minimum 2.0 6.0 4.0 2.0 4.0 8.0 3.0 5.0 5.0 3.0 2.0 3.0 3.0 5.0 4.0 3.0 3.0 3.0 6.0 14.0 3.0 4.0 6.0 4.0 4.0 4.0 3.0 6.0 4.0 2.0 Old System Background Maximum 11.0 13.0 12.0 7.0 11.0 26.0 6.0 12.0 11.0 11.0 9.0 8.0 11.0 9.0 10.0 6.0 10.0 8.0 7.0 32.0 12.0 7.0 9.0 6.0 8.0 9.0 5.0 9.0 7.0 7.0 Old System Background Average 6.5 9.5 8.0 4.5 7.5 17.0 4.5 8.5 8.0 7.0 5.5 5.5 7.0 7.0 7.0 4.5 6.5 No Data 5.5 6.5 23.0 7.5 5.5 7.5 5.0 6.0 6.5 4.0 7.5 5.5 4.5 Old System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 No Data 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.05% 98.71% 98.54% 98.55% 98.84% 98.67% 98.63% 98.54% 98.10% 98.77% 99.29% 97.93% 98.73% 98.93% 98.39% 98.91% 98.44% 98.61% 98.97% 98.29% 97.92% 97.54% 98.40% 97.98% 97.04% 98.51% 98.28% 98.91% 98.29% 98.47% New System Lead Filter Inlet 5121.0 6482.0 7843.0 2654.0 4920.0 3376.0 2618.0 5328.0 5331.0 6138.0 5123.0 5124.0 3617.0 3714.0 2771.0 2891.0 6941.0 New System Between Filters New System Lag Filter Outlet 11.0 10.0 10.0 6.0 9.0 6.0 11.0 55.0 5.0 4.0 13.0 3.0 11.0 6.0 7.0 4.0 5.0 4.0 6.0 6.0 5.0 5.0 6.0 6.0 4.0 4.0 8.0 8.0 18.0 4.0 16.0 4.0 5.0 5.0 New System Background Minimum 22.0 8.0 9.0 5.0 3.0 4.0 10.0 7.0 7.0 4.0 3.0 4.0 3.0 14.0 10.0 7.0 4.0 3650.0 12.0 9.0 6.0 3744.0 18.0 5.0 12.0 4955.0 27.0 6.0 23.0 1653.0 7.0 5.0 5.0 2365.0 8.0 4.0 8.0 2763.0 8.0 5.0 12.0 3311.0 10.0 7.0 7.0 2789.0 10.0 5.0 7.0 2789.0 7.0 5.0 7.0 2781.0 9.0 5.0 7.0 2861.0 22.0 5.0 7.0 2789.0 9.0 7.0 7.0 3114.0 16.0 7.0 5.0 18-Jul Plant was down due to power outage. Units were not giving permits for the day. New System Background Maximum 40.0 15.0 16.0 14.0 12.0 7.0 16.0 13.0 12.0 12.0 11.0 13.0 19.0 22.0 14.0 12.0 13.0 12.0 26.0 39.0 8.0 13.0 15.0 10.0 13.0 12.0 10.0 13.0 10.0 8.0 New System Background Average 31.0 11.5 12.5 9.5 7.5 5.5 13.0 10.0 9.5 8.0 7.0 8.5 11.0 18.0 12.0 9.5 8.5 No Data 9.0 19.0 31.0 6.5 10.5 13.5 8.5 10.0 9.5 8.5 10.0 8.5 6.5 New System Net Reading 0.0 0.0 0.0 45.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 No Data 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.5 Control Efficiency (%) 99.80% 99.91% 99.92% 97.93% 99.92% 99.91% 99.77% 99.92% 99.92% 99.90% 99.90% 99.88% 99.89% 99.78% 99.86% 99.86% 99.93% 99.75% 99.87% 99.88% 99.70% 99.83% 99.82% 99.79% 99.82% 99.82% 99.82% 99.83% 99.75% 99.78% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Isaac Sanchez Marcus Morris Marcus Morris Oni Ruiz Josh Baydo Oni Ruiz Oni Ruiz Marcus Morris Marcus Morris Josh Baydo Josh Baydo Josh Baydo Isaac Sanchez Isaac Sanchez Oni Ruiz Oni Ruiz Marcus Morris Eduardo Chavez Oni Ruiz Oni Ruiz Carlos Martinez Carlos Martinez Carlos Martinez Carlos Martinez Carlos Martinez Carlos Martinez Carlos Martinez Oni Ruiz Carlos Martinez Eduardo Chavez EPA Inspection Report - Page 1015 of 1969 2019 API Carbon Canister Monitoring for Month: August Monitoring Date 1-Aug 2-Aug 3-Aug 4-Aug 5-Aug 6-Aug 7-Aug 8-Aug 9-Aug 10-Aug 11-Aug 12-Aug 13-Aug 14-Aug 15-Aug 16-Aug 17-Aug 18-Aug 19-Aug 20-Aug 21-Aug 22-Aug 23-Aug 24-Aug 25-Aug 26-Aug 27-Aug 28-Aug 29-Aug 30-Aug 31-Aug Old System Lead Filter Inlet 384.0 311.0 377.0 359.0 281.0 264.0 413.0 437.0 357.0 411.0 375.0 211.0 330.0 271.0 281.0 370.0 316.0 380.0 315.0 395.0 430.0 179.0 193.0 497.0 856.0 375.0 347.0 381.0 412.0 357.0 387.0 Old System Lead Filter Outlet 8.0 8.0 9.0 7.0 9.0 6.0 7.0 9.0 8.0 7.0 9.0 5.0 10.0 8.0 5.0 6.0 9.0 13.0 6.0 9.0 11.0 6.0 4.0 10.0 8.0 9.0 10.0 11.0 7.0 4.0 9.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 8.0 5.0 8.0 3.0 9.0 6.0 7.0 3.0 9.0 5.0 6.0 3.0 7.0 2.0 9.0 4.0 8.0 4.0 7.0 4.0 9.0 3.0 5.0 4.0 10.0 3.0 8.0 4.0 5.0 4.0 9.0 5.0 9.0 3.0 13.0 3.0 6.0 4.0 9.0 5.0 11.0 2.0 6.0 4.0 4.0 3.0 11.0 4.0 7.0 5.0 8.0 6.0 10.0 3.0 9.0 5.0 7.0 4.0 4.0 3.0 9.0 5.0 Old System Background Minimum 5.0 4.0 7.0 2.0 7.0 7.0 6.0 7.0 3.0 3.0 4.0 5.0 3.0 3.0 7.0 4.0 2.0 2.0 4.0 5.0 3.0 6.0 4.0 2.0 3.0 6.0 2.0 6.0 5.0 5.0 6.0 Old System Background Maximum 12.0 9.0 13.0 6.0 9.0 8.0 9.0 8.0 6.0 6.0 5.0 9.0 7.0 9.0 9.0 12.0 8.0 4.0 6.0 11.0 9.0 10.0 9.0 11.0 7.0 11.0 10.0 19.0 9.0 10.0 18.0 Old System Background Average 8.5 6.5 10.0 4.0 8.0 7.5 7.5 7.5 4.5 4.5 4.5 7.0 5.0 6.0 8.0 8.0 5.0 3.0 5.0 8.0 6.0 8.0 6.5 6.5 5.0 8.5 6.0 12.5 7.0 14.0 12.0 Old System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 98.70% 99.04% 98.41% 99.16% 98.22% 98.86% 99.52% 99.08% 98.88% 99.03% 99.20% 98.10% 99.09% 98.52% 98.58% 98.65% 99.05% 99.21% 98.73% 98.73% 99.53% 97.77% 98.45% 99.20% 99.42% 98.40% 99.14% 98.69% 99.03% 99.16% 98.71% New System Lead Filter Inlet 7329.0 2179.0 2965.0 2391.0 2311.0 2589.0 2855.0 2988.0 2614.0 2987.0 2714.0 3321.0 3014.0 2614.0 2374.0 5576.0 3671.0 3124.0 3912.0 6437.0 3019.0 3244.0 2457.0 4617.0 5714.0 7329.0 4617.0 2659.0 3146.0 5126.0 2954.0 New System Between Filters New System Lag Filter Outlet 9.0 7.0 16.0 2.0 19.0 4.0 16.0 4.0 14.0 3.0 17.0 4.0 23.0 5.0 28.0 6.0 16.0 3.0 9.0 4.0 17.0 5.0 8.0 5.0 7.0 5.0 4.0 4.0 6.0 4.0 6.0 6.0 5.0 4.0 4.0 4.0 12.0 9.0 8.0 5.0 5.0 4.0 7.0 5.0 12.0 6.0 5.0 5.0 9.0 8.0 7.0 4.0 5.0 6.0 17.0 3.0 15.0 5.0 4.0 3.0 19.0 4.0 New System Background Minimum 9.0 10.0 4.0 7.0 7.0 13.0 12.0 14.0 10.0 6.0 10.0 7.0 8.0 7.0 10.0 8.0 4.0 8.0 9.0 7.0 6.0 7.0 12.0 10.0 6.0 6.0 7.0 4.0 6.0 5.0 10.0 New System Background Maximum 15.0 14.0 10.0 16.0 7.0 24.0 20.0 17.0 11.0 10.0 12.0 12.0 15.0 14.0 13.0 17.0 12.0 19.0 14.0 14.0 20.0 13.0 16.0 24.0 23.0 13.0 19.0 26.0 11.0 13.0 27.0 New System Background Average 12.0 12.0 7.0 11.5 7.0 18.5 16.0 15.5 10.5 8.0 11.0 9.5 11.5 10.5 11.5 12.5 8.0 13.5 11.5 10.5 13.0 10.0 14.0 17.0 14.5 9.5 13.0 15.0 8.5 9.0 18.5 New System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.90% 99.91% 99.87% 99.83% 99.87% 99.85% 99.82% 99.80% 99.89% 99.87% 99.82% 99.85% 99.83% 99.85% 99.83% 99.89% 99.89% 99.87% 99.77% 99.92% 99.87% 99.85% 99.76% 99.89% 99.86% 99.95% 99.87% 99.89% 99.84% 99.94% 99.86% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Marcus Morris Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Oni Ruiz Carlos Martinez Isaac Sanchez Isaac Sanchez Carlos Martinez Jewel Hussalman Isaac Sanchez Isaac Sanchez Eduardo Chavez Marcus Morris Isaac Sanchez Carlos Martinez Carlos Martinez Isaac Sanchez Isaac Sanchez Marcus Morris Isaac Sanchez Oni Ruiz Josh Baydo Josh Baydo Oni Ruiz EPA Inspection Report - Page 1016 of 1969 2019 API Carbon Canister Monitoring for Month: September Monitoring Date 1-Sep 2-Sep 3-Sep 4-Sep 5-Sep 6-Sep 7-Sep 8-Sep 9-Sep 10-Sep 11-Sep 12-Sep 13-Sep 14-Sep 15-Sep 16-Sep 17-Sep 18-Sep 19-Sep 20-Sep 21-Sep 22-Sep 23-Sep 24-Sep 25-Sep 26-Sep 27-Sep 28-Sep 29-Sep 30-Sep Old System Lead Filter Inlet 478.0 416.0 289.0 295.0 286.0 239.0 243.0 253.0 412.0 386.0 410.0 331.0 370.0 291.0 398.0 411.0 263.0 377.0 271.0 198.0 311.0 355.0 317.0 203.0 316.0 197.0 178.0 197.0 210.0 193.0 Old System Lead Filter Outlet 9.0 8.0 5.0 6.0 9.0 5.0 7.0 10.0 9.0 7.0 9.0 7.0 8.0 6.0 9.0 8.0 7.0 9.0 6.0 4.0 8.0 9.0 10.0 6.0 10.0 5.0 6.0 4.0 4.0 5.0 Old Old System System Lag Filter Lag Filter Inlet Outlet 9.0 6.0 8.0 4.0 5.0 4.0 6.0 5.0 9.0 3.0 5.0 4.0 7.0 6.0 9.0 8.0 9.0 5.0 7.0 4.0 9.0 6.0 7.0 3.0 8.0 4.0 6.0 4.0 9.0 5.0 8.0 5.0 7.0 3.0 9.0 6.0 6.0 5.0 4.0 3.0 8.0 3.0 9.0 4.0 10.0 4.0 6.0 5.0 9.0 4.0 5.0 4.0 6.0 5.0 4.0 4.0 4.0 3.0 5.0 5.0 Old System Background Minimum 10.0 12.0 7.0 8.0 6.0 6.0 8.0 10.0 10.0 8.0 6.0 4.0 4.0 3.0 7.0 6.0 5.0 3.0 7.0 3.0 6.0 3.0 7.0 5.0 2.0 6.0 6.0 5.0 4.0 4.0 Old System Background Maximum 36.0 25.0 15.0 14.0 13.0 8.0 15.0 17.0 18.0 16.0 14.0 9.0 20.0 7.0 14.0 10.0 4.0 15.0 13.0 9.0 10.0 7.0 9.0 8.0 9.0 12.0 7.0 7.0 7.0 6.0 Old System Background Average 23.0 18.5 11.0 11.0 9.5 7.0 11.5 13.5 14.0 12.0 10.0 6.5 12.0 5.0 10.5 8.0 4.5 9.0 10.0 6.0 8.0 5.0 8.0 6.5 5.5 9.0 6.5 6.0 5.5 5.0 Old System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 98.74% 99.04% 98.62% 98.31% 98.95% 98.33% 97.53% 96.84% 98.79% 98.96% 98.54% 99.09% 98.92% 98.63% 98.74% 98.78% 98.86% 98.41% 98.15% 98.48% 99.04% 98.87% 98.74% 97.54% 98.73% 97.97% 97.19% 97.97% 98.57% 97.41% New System Lead Filter Inlet 3351.0 2795.0 8952.0 9842.0 4817.0 3247.0 3272.0 3294.0 2761.0 3961.0 4716.0 2477.0 2638.0 2266.0 3247.0 2963.0 2140.0 2659.0 3276.0 5711.0 2173.0 2369.0 2172.0 4711.0 3015.0 3487.0 4678.0 3411.0 4387.0 3246.0 New System Between Filters New System Lag Filter Outlet 21.0 5.0 19.0 4.0 6.0 6.0 6.0 4.0 9.0 5.0 17.0 8.0 15.0 7.0 18.0 9.0 17.0 4.0 12.0 6.0 12.0 7.0 16.0 5.0 19.0 5.0 14.0 5.0 19.0 5.0 17.0 4.0 13.0 4.0 17.0 4.0 7.0 4.0 5.0 3.0 19.0 4.0 17.0 5.0 17.0 6.0 9.0 5.0 5.0 5.0 8.0 6.0 6.0 4.0 10.0 8.0 8.0 4.0 10.0 7.0 New System Background Minimum 16.0 12.0 8.0 6.0 7.0 7.0 8.0 14.0 7.0 6.0 9.0 10.0 4.0 10.0 13.0 11.0 8.0 5.0 10.0 8.0 4.0 10.0 4.0 7.0 10.0 8.0 12.0 7.0 8.0 6.0 New System Background Maximum 41.0 30.0 18.0 12.0 18.0 19.0 23.0 32.0 9.0 19.0 15.0 13.0 20.0 12.0 21.0 18.0 10.0 17.0 15.0 12.0 26.0 11.0 32.0 16.0 17.0 14.0 19.0 18.0 13.0 9.0 New System Background Average 28.5 21.0 13.0 9.0 12.5 13.0 15.5 23.0 8.0 12.5 12.0 11.5 12.0 11.0 17.0 14.5 9.0 11.0 12.5 10.0 15.0 10.5 18.0 11.5 13.5 11.0 15.5 12.5 10.5 7.5 New System Net Reading 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Control Efficiency (%) 99.85% 99.86% 99.93% 99.96% 99.90% 99.75% 99.79% 99.73% 99.86% 99.85% 99.85% 99.80% 99.81% 99.78% 99.85% 99.87% 99.81% 99.85% 99.88% 99.95% 99.82% 99.79% 99.72% 99.89% 99.83% 99.83% 99.91% 99.77% 99.91% 99.78% Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name Oni Ruz Oni Ruz Marcus Morris Marcus Morris Marcus Morris Jerid Heath Jewel Husselman Jewel Husselman Eduardo Chavez Eduardo Chavez Eduardo Chavez Oni Ruz Oni Ruz Oni Ruz Oni Ruz Oni Ruz Oni Ruz Oni Ruz Carlos Martinez Carlos Martinez Oni Ruz Oni Ruz Jewel Husselman Carlos Martinez Isaac Sanchez Carlos Martinez Carlos Martinez Carlos Martinez Carlos Martinez Marcus Morris EPA Inspection Report - Page 1017 of 1969 2019 API Carbon Canister Monitoring for Month: OCTOBER Monitoring Date 1-Oct 2-Oct 3-Oct 4-Oct 5-Oct 6-Oct 7-Oct 8-Oct 9-Oct 10-Oct 11-Oct 12-Oct 13-Oct 14-Oct 15-Oct 16-Oct 17-Oct 18-Oct 19-Oct 20-Oct 21-Oct 22-Oct 23-Oct 24-Oct 25-Oct 26-Oct 27-Oct 28-Oct 29-Oct 30-Oct 31-Oct Old System Lead Filter Inlet Old System Lead Filter Outlet Old Old System System Lag Filter Lag Filter Inlet Outlet Old System Background Minimum Old System Background Maximum Old System Background Average No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data 8.0 No Data No Data No Data No Data No Data Old System Net Reading No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data 0.0 No Data No Data No Data No Data No Data Control Efficiency (%) New System Lead Filter Inlet New System Between Filters New System Lag Filter Outlet New System Background Minimum New System Background Maximum New System Background Average No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data New System Net Reading No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data Control Efficiency (%) Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name EPA Inspection Report - Page 1018 of 1969 2019 API Carbon Canister Monitoring for Month: November Monitoring Date 1-Nov 2-Nov 3-Nov 4-Nov 5-Nov 6-Nov 7-Nov 8-Nov 9-Nov 10-Nov 11-Nov 12-Nov 13-Nov 14-Nov 15-Nov 16-Nov 17-Nov 18-Nov 19-Nov 20-Nov 21-Nov 22-Nov 23-Nov 24-Nov 25-Nov 26-Nov 27-Nov 28-Nov 29-Nov 30-Nov Old System Lead Filter Inlet Old System Lead Filter Outlet Old Old System System Lag Filter Lag Filter Inlet Outlet Old System Background Minimum Old System Background Maximum Old System Background Average No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data Old System Net Reading No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data Control Efficiency (%) New System Lead Filter Inlet New System Between Filters New System Lag Filter Outlet New System Background Minimum New System Background Maximum New System Background Average No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data New System Net Reading No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data Control Efficiency (%) Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name EPA Inspection Report - Page 1019 of 1969 2019 API Carbon Canister Monitoring for Month: December Monitoring Date 1-Dec 2-Dec 3-Dec 4-Dec 5-Dec 6-Dec 7-Dec 8-Dec 9-Dec 10-Dec 11-Dec 12-Dec 13-Dec 14-Dec 15-Dec 16-Dec 17-Dec 18-Dec 19-Dec 20-Dec 21-Dec 22-Dec 23-Dec 24-Dec 25-Dec 26-Dec 27-Dec 28-Dec 29-Dec 30-Dec 31-Dec Old System Lead Filter Inlet Old System Lead Filter Outlet Old Old System System Lag Filter Lag Filter Inlet Outlet Old System Background Minimum Old System Background Maximum Old System Background Average No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data Old System Net Reading No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data Control Efficiency (%) New System Lead Filter Inlet New System Between Filters New System Lag Filter Outlet New System Background Minimum New System Background Maximum New System Background Average No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data New System Net Reading No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data No Data Control Efficiency (%) Low Range Monitoring Calibration Gas 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 High Range Monitoring Calibration Gas 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 500 Monitoring Technician Name EPA Inspection Report - Page 1020 of 1969 ( FAX (505) 746-5283 DIV. ORDERS (505) 746-5481 TRUCKING (505) 746-5458 PERSONNEL REFINING COMPANY, L.P. 501 EAST MAIN STREET P. 0. BOX 159 ARTESIA, NEW MEXICO 88211-0159 TELEPHONE (506) 748-3311 FAX (505) 746"5419 ACCOUNTING (505) 746-5451 EXEC/MKTG (505) 746-5421 ENGINEERING (505) 746-5480 PIPELINE March 31; 2004 U.S. Environmental Protection Agency Director, Air Enforcement Division Ariel Rios Building 1200 Pennsylvania Avenue, N.W. Mail Code 2242-A Washington, DC 20460 CERTIFIED MAIL/RETURN RECElPT Re: Revi~ed EOL Sampling Plan Pursuant to the Consent Decree entered March 5, 2002 by the U.S. District Court/or the District ofNew Mexico in United States ofAmerica et al v. Navajo Refining Company, LP. et al. Dear Director: Enclosed, please find Navajo Refining Company, L.P.'s revised End of Line (EOL) sampling plan for our Artesia, New Mexico facility. This EOL sampling plan is being submitted per the above referenced consent decree, paragraph 22.J.ii. This revised EOL sampling plan reflects 1) the change in sampling points due to a reconfiguration ofthe wastewater treatment system for purposes of meeting NSPS Subpart QQQ, 2) a cJarification of the method of calculating total API water effluent volume, and 3) EPA's comments on the proposed sampling plan provided in EPA's letter dated January 23, 2004. We would be pleased to answer any questions EPA may have about this submission. If you have any questions, please contact me at 505-748-3311 or e-mail me at darrell.moore@navajorefining.com Sincerely, NAVAJO REFINING COMPANY, LP ~M#Ui Darrell Moore Environmental Manager for Water and Waste An Independent Refinery Serving .. NEW MEXICO ARIZONA WEST TEXAS NORTHERN MEXICO HFNA-000000039 EPA Inspection Report - Page 1021 of 1969 ( Director EPA March19, 2004 Page2 Enclosures cc: Bureau Chief Air Quality Bureau New Mexico Environment Department 20411 Galiste[) St.. Santa Fe, New Mexico 87505 Chief Air, Toxics, and Inspections Coordinmion Branch Environmental l>rotection Agency, Region 6 1445 Ross Avenue Dallas; TX 75202-2733 cc: Navajo: PLY, JER, DEW, FOG, RAS, SLB Holly: WJG Elec. cc: neichlin@.matrix\:Ilgjpeering.com (letter with Enclosures) J1;m:mr.ra.mario(@.epa.gov (letter with Enclosures) Cannon.elizabelh@i:Jti.\,@.Y (letter with Enclosures) Envr. File: ( General Counsel Office of General Counsel New Mexico Enviromnent Department P.O. Box261l0 Santa Fe, New Mexico 87502-6110 Director, Air Enforcement Division U.S. Environmental Prntection Agency c/o Matrix Environmental & Geotechnical Services 120 Eagle Rock Avenue, 2nd Floor East Hanover, NJ 07936 HFNA-000000040 EPA Inspection Report - Page 1022 of 1969 ( PROPOSED END-OF-LINE (EOL) DETERMINATION PLAN NAVAJO REFINING COMPANY ARTESIA, NEW MEXICO March 2004 I. INTRODUCTION As required by its Consent Decree with EPA lodged on March 5, 2001, Navajo Refining Company (Navajo) is required to develop an End-Of-Line (EOL) Determination for any facility that has a Benzene Waste Operations NESHAP (BWON) Total Annual Benzene (TAB) Quantity greater than 1 Mg, but less than 10 Mg. Navajo's Artesia, New Mexico refinery has a TAB Quantity greater than 1 Mg, but less than 10 Mg. Therefore, this EOL Determination Plan was prepared for the Artesia refinery. The EOL determination calculates a benzene quantity used by EPA to corroborate that the TAB quantity calculated at the point of generation ofbenzene wastes is roughly equivalent to the benzene quantity of wastes and wastewater collected at the outlet ofthe HFNA-000000041 EPA Inspection Report - Page 1023 of 1969 ( facility after taking into account some volatilization of benzene in the oily sewer system and from handling of waste streams. The total EOL benzene quantity shall be determined by quantifying the total mass of benzene in various streams exiting the wastewater treatment system and adding benzene quantities. leaving the refinery in other streams, including that from aqueous wastes that are managed in a contractor owned and operated oil recovery process for wastewater sludges along with other oily wastes generated in the refinery. This contractor process recovers oil and water from the waste streams and returns it to the WW API and generates a semi-solid sludge that is reconstituted with slurry oil (for heating value) and is sent off-site as supplemental fuel for cement kilns. The final cement kiln fuel product generated by the contractor process will be quantified and sampled for benzene concentration and will be added to the EOL benzene quantity. Additionally, waste caustic, generated in some of the refinery processes and then sent offsite for recovery, ,vill be assessed for total benzene and that quantity will be added to the total mass of benzene. / The mathematical representation of the EOL Determination Plan can be found in the equation below: EOL = (QAP1 Discharge Water X Cnen:rene) + (QAPI Recovered Oil X Cnenzene) + (QAqueous Waste Caustic X Cnenzene) + (Qwaste Caustic Hydrocarbon X Caenzene) + (Qcentrifuge Sludge X CBenzene) EOL = End-of-Line benzene quantity (pounds per quarter) Q = Flow (pounds per quarter) C = Concentration Benzene (ppmw) II. EOL SAMPLING POINTS The Artesia facility is a nominal 75,000 crude barrel per calendar day petroleum refinery that utilizes the distillate capacities of its 45,000 crude barrel per calendar day crude unit and that of a 30,000 crude barrel per calendar day topping plant refinery owned by Navajo in Lovington, New Mexico to produce motor fuels and a full range of distillate products for transfer via truck loading racks and pipeline. The majority of the crude feedstock is sour and the facility has an extensive sour water treatment system to reduce the sulfur and ammonia in wastewater streams for subsequent reuse in the process or final treatment in its wastewater treatment facility. The Artesia facility does not have the traditional slop oil management facilities normaHy found in,a petroleum refinery due to the design ofthe crude unit and major distillate receiver and accumulator process vessels HFNA-000000042 EPA Inspection Report - Page 1024 of 1969 ( that route the organic streams recovered back into crude unit process vessels without subsequent storage or introduction to the atmosphere. Additionally, oil recovered in its sour water system is routed back to crude unit process vessels without subsequent storage or introduction to the atmosphere. The BOL management of benzene waste streams is limited to: (1) the main wastewater API, hereinafter referred to as the WW API, (2) the Alky API that serves both the Alkylation Unit and the Reformer Unit, (3) waste caustic and skimmed hydrocarbon at Tank 40 and Tank 41, and (4) tank cleaning wastes, sewer cleaning wastes and sludges generated in the two API systems, all of which are processed in a contractor owned and operated centrifuge/heating system. For the purposes ofthe EOL, the skimmed oil from the APis will be routed to surge tanks that are fitted with a calibrated volumetric sight glass, where the accumulated recovered oil wiH be held for the duration ofthe EOL sampling timeframe. Additionally, the centrifuge/heating system routes the recovered oil and water to the WW APL Water separating from the oil in the surge tanks will be decanted back to the APis and a final measurement of recovered oil will be made at the end ofthe EOL sampling period. A schematic of the EOL sampling plan for the API system and the contractor centrifuge/heating system is presented as Figure 1 on the following page. HFNA-000000043 EPA Inspection Report - Page 1025 of 1969 { FIGURE 1 DIAGRAM INDICATING EOL SAMPLING OF API AND CONTRACTOR CENTRIFUGE/HEATING SYSTEMS ALKV API W.Rtnr Q,urge Tank Surgel Biologic:al Treatment Tanks Water was~. water APi , - - - - - -... Treated OAF and water Filtration Oil& Water Surge Tank OH to Crude OH&Wm:er ~nd injection Wells Shut~s from A.Pl, Contractor Oentrifugt Se~r, ---- /Heating and Tank CJeanouts System Come:tit -~-JI- Kiln fuel !'l Product ~_,,.,H,.......,..io < (s11~1e1 ,._Pt,S4 .I '~ "'",,rt~-,.<l'i"t"' HFNA-000000044 EPA Inspection Report - Page 1026 of 1969 ( ( Waste not generated or counted against the TAB quantity, per the BWON regulation, is remediation wastes from groundwater recovery wells that are returned to the oily water sewer in the facility. These waste streams wi11 not be introduced into the Artesia wastewater system during EOL sampling, and wiU not be counted in the EOL calculations. The EOL sampling points for the required sampling activities will be: 1. Surge Tank OH - Sample Numbers S-1 and S.,2 Prior to the EOL sampling date for the quarter, surge tanks will be placed near each of the APls to collect aU recovered oil from the APis along with some water which is skimmed off of the APIs with the oil. The surge tanks will be decanted and the water wiH be pumped back to the APis. Sample points S-1 and S-2 sample the oil after the point .where the water is returned to the APis. 2. WW API/Alky API Water- Sample Number S-3 All wastewater from the facility is discharged to the aggressive biological treatment system at Tanks 801/836. The discharge water from the WW API (includes water from the centrifuge system) and the Alky API is combined prior to Tanks 801/836. Sample S-3 is the combined flow of the WW API and the Alky API, and will be coUected at a sample point prior to entering Tanks 801/836. 3. Contractor's Cement Kiln Fuel Product- Sample Number S-4 The contractor owned and operated centrifuge/heating system is operated to recover the oil and water content ofAPI separator sludges, sewer cleanings and tank turnaround cleanings within the facility. The recovered oil and water from the centrifuge system is returned to the WW API and will be accounted for in the EOL there. The solids from the centrifuge are reconstituted with slurry oil for subsequent energy recovery in a cement kiln. The cement kiln fuel product will be sampled for benzene. 4. Waste Caustic- Sample Number S-5 through S-7 Waste caustic from various process units is transferred to one of two tanks, Tank 40 or 41. A waste caustic sample will be taken at each tank to determine the benzene concentration in the aqueous phase of the tank. Also, a sample will be taken of the hydrocarbon that is skimmed off and recycled to crude. A schematic of the waste caustic tank operation is presented in Figure 2 on the following page. HFNA-000000045 EPA Inspection Report - Page 1027 of 1969 ( ( FIGURE 2 Waste Caustic Tank Operation Waste caustic TanksT-40 andT-41 HFNA-000000046 EPA Inspection Report - Page 1028 of 1969 ( HI. EOL SAMPLING SCHEDULE The EOL sampling will be performed during a one week period on a quarterly basis to arrive at the EOL calculation. During the seven (7) day time period of sampling, the remediation wells will be turned off 3-4 days prior to the sampling events in order to preclude remediation waste from being counted. The sampling will follow 40 CFR 61.355 procedures to the extent possible. A notation will be made if the sample cannot be taken 1mderthe 61.355 procedures, as most of the samples will be from open systems that do not allow the sample to be taken with the cooling coH and vacuum pump. With the exception of the waste caustic samples, it is believed that very little, if any, benzene Vvill be lost to vaporization because the samples have already been exposed to the atmosphere in the API's. In the case of samples taken without the cooling coil, the sample must be placed on ice immediately. The sample will be analyzed for benzene per Methods 8240 or 8260. 1. Surge Tanks - Sample Numbers S-1 and S-2 a. Recovered oil - three composite benzene samples at the end of the EOL sampling period. b. Recovered oil- one specific gravity sample for each of the composite oil samples. 2. \VW API/Alky API-Sample Number S-3 a. Discharge water - three (3) benzene samples in the EOL sampling period with at least 24 hours between samples. 3. Contractor's Cement Kiln Fuel Product- Sample Number S-4 a. Solids - three (3) benzene samples in the EOL sampling period with at least 24 hours between samples. 4. Waste Caustic - Sample Numbers S-5 through S-7 a. Waste Caustic Tank 40-three benzene samples ofthe aqueous phase during the EOL sampling period. b. Waste Caustic Tank 41 -three benzene samples of the aqueous phase during the EOL sampling period. c. Hydrocarbon Skimmed from Waste Caustic-three benzene samples will be taken during the EOL sampling period. IV. EOL FLOW VOLUMES HFNA-00000004 7 EPA Inspection Report - Page 1029 of 1969 ( ( The EOL volumes will be calculated as follows: 1. Surge Tanks - Sample Nmnbers S-1 and S-2 The recovered oil volume will be read directly from the sight glass on the surge tank which is calibrated for the tank. Prior to the beginning ofthe EOL sampling period, the recovered oil smnps at each ofthe API's and the centrifuge system will be pumped out to the lowest possible level, and the surge tank will be empty. During the one week sampling period, the recovered oil will be pumped on an as needed basis to the surge tank to avoid overflow from the recovered oil sumps back into the API's. It is expected that the WW API will be pumped daily with the South API and the Alky AP.I pumped every other day. Pumping from the recovered oil sumps to the surge tank will be noted each time the operation is performed. 2. \VW API/Alky API- Sample Number S-3 The flow wm be measured from the totalizer flowmeter at the deepwell (after Tanks 801/836) for the facility. There is a1so a small slip-stream of water that is diverted to the Artesia POTW. This stream is also measured on a flowmeter and wiU be added to the total going to the deepwe11s. There are no other flowmeters in the system and it is thought that pump curve calculations will not be accurate enough for the purposes ofthe EOL Determination. The combined flow reading at the beginning and end of each 24 hour period during the EOL sampling period will be.noted. The total flow between the readings will be computed to arrive at the volume of aqueous wastewater discharged daily from the facility during the sampling period. In order to compensate for potentially lower volumes, the two lowest 24 hour volumes will be dropped from the calculation to arrive at an average daily flow based on the 5 highest daily flows. It is anticipated that daily flow through the system averages approximately 400,000 gallons per day. 3. Contractor Cement Kiln Fuel Product - Sample Number S-4 Product weight will be determined for the entire quarter based on shipping manifests for the entire quarter. 4. Aqueous Waste Caustic-Sample Nmnbers S-5 and S-6 The weight of caustic generated from Tanks 40 and 41 will be determined for the entire quarter based on shipping manifests for the entire quarter. 5. Waste Caustic Tank Hydrocarbon - Sample Number S-7 The volume ofhydrocarbon skimmed from each tank cannot be directly measured as the TAB quantity is based upon operator process knowledge. Operator process knowledge estimates that approximately 100 gallons ofhydrocarbon are skimmed off each tank every month. A specific gravity will be determined from each of the three samples. HFNA-000000048 EPA Inspection Report - Page 1030 of 1969 ( ( V. EOL CALCULATION The EOL will be calculated as the sum of all average benzene sample results multiplied by the volume of wastes generated at each sampling location. The following calculations will form the basis of the EOL Determination. 1. Surge Tanks The recovered oil from the API systems will be calculated as follows: EOL (Mg/quarter)= 13 (weeks/quarter) x Oil Volume (gal) x 8.34 (lbs water/gal) x Specific Gravit (dimensionless) x Average Benzene Concentration (ppmw) x 454 (g/lb) + 106(g/Mg) 2. WW API/Alky API The discharge water from the API systems will be calculated as follows: EOL (Mg/quarter)= 91 (days/quarter) x Average Flow (gal/day) x 8.34 (lbs water/gal) x Average Benzene Concentration (ppmw) x 454 (g/lb) + 106 (g/Mg) 3. Contractor Cement Kiln Fuel Product The centrifuge solids win be calculated as follows: EOL (Mg/quarter)= Amount of.cement kiln fuel shTped in the quarter (lbs) x Average Benzene Concentration (ppmw) + 10 4. Aqueous Waste Caustic The waste caustic for each tank wiH be calculated as follows: EOL (Mg/quarter)= Amount of aqueous waste caustic shipped in the quarter (lbs) x Average Benzene Concentration (ppmw) + 106 . 5. Waste Caustic Tank Hydrocarbon The waste caustic tank hydrocarbon is known from process knowledge. The following calculation for each tank wiU be as follows: EOL (Mg/quarter)= 3 (months/quarter) x 100 (gal) x 8.34 (lbs water/gal) x Sp. Grav. (dimensionless) x Average Benzene Concentration (ppmw) + 106 HFNA-000000049 EPA Inspection Report - Page 1031 of 1969 9biU.S. DOT Description (including Proper Shipping Name, Hazard Class, ID Number, ~ni:1 Pac~ing Group (if any)) U_,,. EPA ID Number U.S. EPA ID Number 4. dt" . ' > - - ' ., ~ C F1""5:-""G-E=N-E.RATOR'S/OFFEROR'S CERTIFICATION:' I hereby declare that !he contents oft~is oonsignroent are.fully and~1::wrntely desrn'.bed above by the proper shipping name, aral are.classified, packagei:!;, ar,ci labe!ediplaciirrled; and are.in all respec!S In proper comiitlon fortnfoiort ilci:oidi:'19 fo awlicabie in!ematlonal and nationalgovemmelital regulations. I! export'sh1pmeniand I am t~e Prtmary : . .. . 'marked .,.~: Exporter: Icilrtify thati\heconlernioti:hls colisignmsnt conform to.the !tinns of the'attached ~!(AAclsnowllldgmMt of Ctin~n\. . ' . .. : . -~. . ...:s;' . . .... v . ; .. tcertifylhat ttie ~~ste'.mii1imiziitionsiatementidenjffied in 40 CFR262.27(al (ill am alarge quantity generator) or fo) (rrl arruismall qliantiiygenerato;) is tru~. .. t. . ' ,--""""0~~+~-:-""'1 _Generatof;;!Off~ror'.Pii~ff~ Name i ' _: :._c " ' ,. '. -;: ' . LJ Import to U.S. 0 Exportirom U,S. Port of ent~iex~: Dale leaving UsS.: ''s:: .. ._Signature. , -1....:..... .... _._:)j ,... 'Sig&r)i{L,, .. .. ,-~.,, Ooilan!ity (or Generator) Monll'! Day Year. HFNA-000003520 EPA Inspection Report - Page 1032 of 1969 9b. U.S. DOT Description (including Proper Shipping Name, Hazarrl Class, ID Number, and Packing Group (ifany)) U.S. EPA ID Number NMROOOfi23952 U.S. EPA 10 Number . U;S, EPA IDNumber . 10. Conminers Type ~. 4, ~~~~'-'-~,-~~~~--r ! l''t:14:r,J/50:,:rtHt:'.an'."'.dm'.lir:'.'.:19'i.ln=strt::-:::;ct1e'.::o".'.:ns:-:a::n,dA'"d'-'d'"ilic::n:::;_al"'ln::.:fo::rm:::ia:,!i;:::on' 1} 00Jit1.'475-0 Hlb?. SEWER !lh.UOGE ., .... , V . 0 Export l'mm'.u.s. Port of ent')'lexit '" " ""'-- .. _Date leaving U.S.: <..::>~- St_~~_r:~~u~..-.....~ ,,/ ~.. =-"'f"'"""iM"s"""~=,-.-=~-~"""'----~-------~wm,,;Signa!ura ----- 1Sa. Discrepancy indicati9n Spaoe . 0 . .', Quantity 0Residue. 0 Partial Rejeciion Facility's Plione: 18c. Signature of AJten,a!e Facili!y (or Generator) Waste Report Management Method Codes (i.e., codes for hazardous waste lreatrnsnt," disposal, and recycling systemsf I "~ Year '(''. 't"'' HFNA-000003521 EPA Inspection Report - Page 1033 of 1969 .,,..,.,.,,.M~lN F.oml'Approved. 0MB No. 2050-0039 U.S. EPA ID Number -'\'.);$, EPA IDNumber 1"1. Total Quantity 12. Unit W!.NoL D Import tz,.u.s: Transporter sigr.atiire (for exports only): 17. Transporter Ackr\owledgrnen! oJ Receip! of Maierials edName :.,,.,..., I" :ti {, /' ..)r"" (f n rnscrepancy ' Refection [ ] Fu~ Rejection -Ha-zari-fous-W-asie-Re-por-t Ma-na-gem-ent-Me-ihoc-t Co-de-s (L-e., r-ode-s fo-r h-aza-rdou-s w-ast-e tr-ea\m-en-t, di-spo-sal,-'and-ra-cycl-ing-sys-tem-s) - - - - - - - ~ Month Day Year HFNA-000003522 EPA Inspection Report - Page 1034 of 1969 .:i,x,.i-' } . 2,Page 1 d 1,::: ~~<~ ir- &.' . U.S. EPA ID 1,/umher ~, ,. . , , ,. ;:,_, > i !,, ,t.; . NMR000023952 u .s. EPA ID Numoor , ......,. -~ .,,,. .z..,. -~.J;.-. _,,,: .-:,.,+-....~:~'4~--,.-w-,~'f )"""1~+<-..,.-'" -:...:;.:*"':,~-..:..,,~~~~~-~.;,.. ;~~.....~.~~,.,; *""....,., JJ.~.??.~J;J:~ iown.~w:~.-~~~-~~ -"l"-~~...A-.,.;. ~-~,:_ ,,:,,...:.:;;;....,."'.4"'f:!\~. ~ cl,:f tf" .,:, .. ~~> -l', t~(t TXDOOS4!52340 ! 1(), Conminern. No. Type 4. ....,~ .. ., ,,,;;.;,, ,., . ;_,, ,;~.....:.>: '. . . .. . ... ..tl1at the conlen!s of !his consignment. are fully and accurately described above by !he proper shipping name, and are classified, pac~aged, marked ahd label,Wplacartled, a~d are .in'all respects in)roer cqnd:!ion for tmnSP,Ort acmrding tp aiplicable in\emau0ri.a?,ano naijo~argovemme'ntal mgulalior;s. 1iaxport shipment and Iam ttm Prim~~ . &porter; I certify,(MMhe oonlanls of !])is oonsignme\l\ (X)nform fo:lliiHerms of !he alt.lched 'EP~Acknrwll1tig!T\ert ofC!)nsin!. . . . . . . . . . .'J certify !hat the wimle minitl)izatiDli $!$lament identified. in 40 CFR 262.27(a} (if I ani a'iarge qu~11Ut',{9iirjera!or}or (b){ff l0'1m a. srnilll 'quahtity geherato Hi.' Discrepancy 1Bb. Alternate Facility (or Generator} Facility's Phone: ale facility (or Generamr) '. 'Manifest Refurer,oe Number: U.S. EPA !tl Number ..D.~-c,.. --.::., . j " Full Rejection Mon!h Day, Year pehfor: CertffiMtion of receipt of 11azardaus 11iaterials covered by the man~est exce. SignaMe. : HFNA-000003523 EPA Inspection Report - Page 1035 of 1969 . ,,/ ...../ \ 9a. 9b. U.S. DOT Description (including Proper Shlpping Name, Hazan:I Class, ID Number, HM and Packing Group (if any)) No. PA 1" X ~ ;~f) &1So. O \l t~:,;:.:, ::01:.:.'.._, ;! '. '. ../ x,J,/ { I'-, /\ ' :fzf: i-f--2-.........+-------- ------------~----~~_/_--f----+-----+- w G I"""-3. =----------------------"""""-"-"""-~""-""----------0-----------"-------~---, : I 4. ; ... ~ ~'\_ ... l,.. ~ q;,_ ~/~ . 15. GENERATCIR'S/OFFEROR'S CERTIFICATION: I hereby t 1 '\:.;- -~ ntenbl of w lh~signmenl are fully and accurately - - - - - - ~ described above by the proper shipping name, an::! - - - - am cla_ssified, par-kaged, - marked and labeleo/placarded, and are in al! mspects in proper condition for lmnspml ;3ccj:1!ding lo ;ippl1cable inlemalianal and national govemmental regulations. !f export shipment and ram file Primary fapmter, I certify !hat the contents of !his cimsign.ment conform tot.he tenns of the atlachea EPAAcknowledgmenl of Consmi. I certify that the waste minimi2ati()n stltemenl identified in 40 CFR 262.27(a) (ff I am a !arg?quantity generator) or (b) (ii I am a small quantify generator) is true. .,.... S/gnatu:r:> ,4 ' Mmfil Day Year //~:1~:;bzrt:o <rr J .::~~i u:r l .3L271.lq 0 Import to~:;: D EKport from u.s: Porl of entry/extt: ffi 17. Transporter Acknowledgment of Receipt of Materials Transporter sign~,ture (!or exports only): ........,............,....,....-------------------D-at_e_la_av_in_,,g'-U-._s._.- - - - - - - - - - - - - - - - - = = = - - l h2 Transporler 1 Printed/Typed Name i ;t,.,:-1/1 r>:: ro f. /L../ i Transporter 2 Plin!edliypeo Name ~ <t... ". \' ' 18 1 Discrepancy - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -..-- 18a.-Discrepancy lnciicalion Spac.e D o....''n"'' "" "'' 0Typv" DR 'd :.... em ue [.....1 pa,~,,aIReJ'ection o ruII Re1.ec1m n !}~w, !4..' f'r,11'.I., ,h.ifl_:;<.tL; ';c.1/.J;.,'-i 'J <;- .. I '.' .. ! !~,, ' i .-J .'. ~<" "''' (. - (. ) ,'j _4, L,J,. r:.;,C'd,.I/ r'-'',,. .,.,',. h/,,., .'.>,__.-- - '- Manifest Reference Number: ::- / J. -~ I '/ i\t ) ~ 16b. Allemate Facilify (or Genenalor) U.S. EPA I[) Number '-# ...J 0 if Facility's Phonai: e- 1~, 1fiw;of1AalenFaecilifym(or:G~ene~rat(or&) (~itori,----------- ~ i'5 -1-9. -Ha-za-rd-ou-s W-a-ste-R-ep-or-t M-a-na-ge-me-nt-M-eth-od-C-od-es-(t-e.-, r,-0d-es-fo-r h-az-ard"ou"s'w"as"te "!rn"alm"ent,-d-ispos-al,-a-nd-re-cy-ciin-g-sy-stem-s)..--..--............... 00 ~, t HFNA-000003524 EPA Inspection Report - Page 1036 of 1969 1,, Wmihiiri iGlJ1)rnb,: Nfd00488i88H B. tf$"tf'bltifi'f8'.U,t)$ff;:g fM.T? C0JNTY ROfa.D@B Nfil8TOWM !'ll(#l'/S Pi,~m; { ~ 242hbLl@ 1, 9~. DOT l,;,s(Jipti<iro (bd1,6ng PNW Shippiii!) ')NM, Hw.ard riM Jn<l hr:Vi,ig GtJ!) (ii a~y)) ; .-1,,--+-=,.".i'"?.,.:-:""1""/"'<~,~~-:.,uu NA0TK'.;1ro0-;-i-}."'6"'.""U""\-,""y-,=~@-1""n-- L! __,__ z _,,,__,,,,,,.____~-2. w. o; - - -..-------,,,,/_--+t-~_-M_._..,,,l,,,,/_,(o"':;~..,;;,,.-- .:), 11: ---------+.-,---4--~----,4-- -www~--W*=--+---- 1 itt itr_ +-~--- I ..,,__J ' l 1~. t fall{c11~ ~1tcllfilb!};3~,,,;1,~,,d Jbv~ by ih pmp,x th)phJ mm~. iliti fff dmf;iiid, pilr:~agM, GGrcdgnmB\ 0:ln1mnt. , :r:0:h::d rmd btuledf;t=~.c;~;Jtd, t~1~;;5 :1rn h ~H rN:;f: E e: x i: ~ ; crtff,: ;;1 ~optr ;::~)nditt:n'for Gfrlify trd Ge (mimb ti:np1x i t a::.::-to )1 :ding tliiJ wnfo,111 h b t1r li n w 0tir.:n~101~< nBiion~[ f l P e ' i ( m ,>~ 1 0f c~f 11\ ~ b rm d m ld E m P h) rng:ib~:(( A :'i~ A , d:mw!m\1H lf 1 0 e x n p t 6f ort f:hiprr:0:it ~rd l ,~rt E11J rnm0ry Ii:;.ir/y baithB wisie min\;;intm stJINmd ldm;1.;1hd in 40 CFR 262.27/a) iii I Bm a large q1;1,i,+; gmBmbr) ,:)r 1/) I)! w1 " :;1111ill qwr%y grrnra!rn) b rn;~.. G$<Ms~ ef:;10fo10r1 PMnl~d/Yy;~:i~eo/~t;'J,> {fl 01mrc,rt ts) U$. ~,,,,;;.--~"---~(f~or~ew-o~rt.i,r;d.:;)_: ,.- . . . .. ~'.~:SignffetJj(QA(?!>,<~-j'.~~~~;~-f1-~-./..->---~--~--,-- 3bf;,rtifirn1JS. :' '"'\,, Pn:td~illl)'M:<it: DlliB !Bav'c,g U.S.: Jq Ywr ~.\ f':;::;-:.. :.:),<<~j ---------------- HFNA-000003525 EPA Inspection Report - Page 1037 of 1969 HFNA-000003526 EPA Inspection Report - Page 1038 of 1969 (fi1tf).A7~4 GerefrdIT's f'h>r;n: 6 !?'rii115W.t~"WASTE SEHV!CES H\!C ,. ' I OMJNi>. 2JS>OC:W 40 JJtc '.t ~~t~""""-....~---"'0._~ _ :: - ~ - - ~ - " - - ~ - - :S.-"""!_ _~""--J~~-,.b,-,_,,..l Q,nnny LJr,w:; 10, J;fr<} pJvt\.iJ '*"">;'"' r""c IIY:,J.t+:; .. ! /j)A ChI;:~ '~>t "S+i HFNA-000003527 EPA Inspection Report - Page 1039 of 1969 >< . 0MB No. Xi50<lfl3il U.S. EPA lG Nwcl1bm N iJ.S.EPA :P Nm,oor }2. '.l. l. : --~~~~}----+---0--i~",,"= .1ik [);$ixrp~Wf lcd!mfon Sp~r.f ' D HFNA-000003528 EPA Inspection Report - Page 1040 of 1969 t;:u >V :::,;~-.v... , r IP:s,r.it0 prt1t1r '.\Ts? 1, :: - 'llMJS&1i~stm . s Rr~cll&B!)f~f@@1tJ\S~l:1:1J;. ' Rt). Bff!HS AA7ES!A %. %. U.S. HM md Pa1:b1J Pmpr 3Hppir,g Nm<1t, h1wd Clim, ID 1 4. I .1 [ ] PsrMI fbt~tiGn ; , ,'- ... \ HFNA-000003529 EPA Inspection Report - Page 1041 of 1969 SERVICES !NC ?tZi1 VOUNYY ROAD GS ROCTSTCfAfW . .. @00) 24.Z.Jili:m i;F..;~:':o:::.'l1ir;:._:'s::P:.hc::r;::tB:::;___~--.:.:':.-----------------------.---=-----c-k----r----,-..- .."---"""' ; . 10. t)::ni3bi;\:-s tti 0 i!ti b,-,~----~---------.. / ,.. UJ 91 4. k=::-:-:;;;::::;'T,;,::::'i2::0:~:-:::'~~~-"'-~~;_;,,,,..------~---"""'.~;;;,i;;"'~'.'7'.""'""".'--:.--------~--""'-r,-;o-d~h!-J""p-y---0 L{ //) "L.;JJ'): ",_.. . . ',J:.'.., HFNA-000003530 EPA Inspection Report - Page 1042 of 1969 ed for use on elite (12-pi!ch) typewriter.) t Ge11emtor,ID Nwmoor ,es _:.. NMP04Blil188'! 7 ::. 2. Page 1 of 1 lhan mailing address) !\IAVAJO NEF!MMG CO , L!...C.. 001 i:::AfilT-W!NN A.lt'fESL#i 6: Tran~porter 1 Company Name $ EJR.rrrHERS V1?\STE Sf;Fi}ii'C"ES !NC 7. Transporter 2.Company Name .. U.S. EPA ID Numbl!f NMROCt00.2:3962 U.S. EPA ID Number ~ ~ ~ ~ ~ 11. l.\dg~e!ild F;:;Gility Name.and.Sit.aAddr~w - - - - - - ~ - - - - - 1 - . ~U,S; EP.AID~NQ,m,b,er,,,,,,,_"""'-""'-- \;. ? EQ;l'.Jt.OGY rex i\S), ING 32.P'Y Cf>HY ROAD 69 . m:w5Tcr,i'#J . . . Facill~ s Phone: ~) ffl:f'.i!:$ -----"-- Sb. U.S. bCirne;criptkm (including Proper Shipping Name, Hazard Class, ID Number, and Packing Group (if any)) . . . nten1sof this consl{Ament are fully and accurately described above by the proper shipping naine, aoo are classified, packaged, ma.ked and labeledlp!acarded; and are in all respeG':S in proper condition far transport accordjng to applicable inlemalional and r,aiional governmental regulations. If export shipmen! and I am the Plimary Exporter, I certify that the contents of this coosignmenl conform to the terms of the.attached EPA Acknowledgment of Consent. . I certlly that the waste minimization sratement idenimoo In 40 CFR 2o2.27(a) (if I am a large quantity generator) or (b) (iii am a small quantity. generator) is true. " !Typed Name " A0w Port of entry/exit: . Daie lem,ing U.S.: Facility's Phone: 18c. Signature Q! Alternate Facility (or Generator) ~ Sign&.di.:\, "'''' ... I )' D TYfte /' D Residue I ' C ,L.J partial Rejection c'"'..>'ftove..,,.t o.et'. ... t..1:.." 1 :..:.. Se~,il ,A< .....,.:..::.r.'.. l 1'1 ci:c ,:: !\::. .-~..::. :,(,:c) ..'.'././..:.;Gt :::'e:':'.itti.xn!f)ehll'.Rec?e.re 1ca ~ u\Cm\b.ie.".":-':"..:.c::-,.:.. ...]Cjr',,:o~"' 10. -rr:.~.....'... ,..... G ~ U.S. EPA ID Number D Full Rejection .''(';1" (i.e., rodes fur hazardous waste treatment, dlspo.sal, and recycling systems) 4. HFNA-000003531 EPA Inspection Report - Page 1043 of 1969 F?iiFORM HAZARlX)UE , WAJTE fs1ANlFEST .. 5, f#WAW#1WNTNflW.tv:f611;WLC. Per sex ARTS:iiHA . MM @42Kt flRT01A ($7%} 7GlHX%J4 i 1 - ,,,::.G;;;,,~;;;;,',t::,:m::,:x;;;,,i,::.'c;;;,P;;;,h;;;,01;;;,'";;;,,:'~ - - - - - - - - - - - - - - - - - - - - - - - , ~ = 8 1 {31M()Tftllil~' ~'10;srs.sERVICE8 7. ~r a: rffl1mndst;'ffl&~1;1rfl1!:% :!i2T? GGUNT\' fh}AU GR HGB@TU'$iV $XW} 3(0.JZ}B ~=;_,_---'------------------------------,,---- 10. Corctili'lers Mo. i 2: "'~ .l .\.:,,,,:.... ~ hdlilv's Hmm: "'~ Wt. S\w~Lrn d !%,milt~ fJdl'tf (rr Gum~mlu) ,__ _ _ _ _ _, . ' -~,,,,........-.-------.~.------"-'-""""'''''..,.,.,._,.~.------k---'---'----l'. 19. Hsz;J~}QU5 V:{t=;k R:_::vin ri..tm,.:(it:611:::rit Mh="K:<l C()ifor (Le,, wcis=r; fo:- ksx;-::rdeu::S\:1&'.:;t:-~ tft\:~~~~~r:t, J!q_ic:%:L imd/tC-Yt:Jr:il iyd1.~r1:~) ,,;,.:,_/;, , HFNA-000003532 EPA Inspection Report - Page 1044 of 1969 5firA~c/1*:ffrr11iRtttfu1~t&. 0:ct vbu AAT0!A ) ;- / " 8ERV!CES [MC u~h,'v'Xtt:Vrtffinli<eyitJEt"t:E*t2 ddiJ,,) ;' WY! EA.Sf MAIN NfTEfiltA U.K t:P/dD Nwm::mr ,.. ~ :-- .,, , . . ISJ ;;;NM!rf?9000-2 : j U.S. EPA\D Numi),,,r, "'! ' ' ,...:~-",,;,,~ ,.-,,~ ll~- ,,J?'{}_;:,~: ~tfr',(; TXOGfl8432240 . -~.""-,''J- ..... ~~~...C--"'"--"-----~-------~,,,.,.,,--------------- ' .-<;LJ rirtl~I R(ec,ia/. HFNA-000003533 EPA Inspection Report - Page 1045 of 1969 : ' -~}::< facilit , Phone: , sit.u:s. DOT Descl/~~n (ilwluding P 1,t\u Packing Grou'~ (ii any)) ~tifrl$t/fj, Mitt:A?06~'7$6t;'!'!;~~<0&0't**0.?m,,~'"i'- 11: 'fotal :,:Typo'. )l1);iniity 13, Waste (',edell *.6 b '. o#. '.3\111 i5; J:lENERAr()R'S/O!'FEROWS CERTlFICATIONi Ihiretly declare that!he c; . .orfsignment are fully and ;~cc,1rately desc'ribetl above by lfa, prnpiif shinplng r1afoe, a am clas,s1fied, packagtd, .. .. . .. . . we in :;-ill respects jn P.ropernaiiticn !or transport acr,ard,~g11o app!icabls'intern.afonalahd riational goverprimrllal re_gulatiomi. if exf,rnfihipineh\aridJ~~l the Prirnarj .. . Icei-/ily u,at th~ 1\iast iJ:,inimlta!iofstiit!i~ilnl identified in 40 Cf'R 262.27/a) (If! arrl' ;i la/ge qUanfify generator, or'(bi (ffl am.a Sinilil qt!mlt/ty ge11~iator) is lr\ie, , n!6mrto'.lhll>'tenn:i cfthe alticlieo EPAAr.know:eagment of Consent . , . . . -- Signature ~--'~-,;,'-~c....--=--~,,,,,,--"--b-<0-~0-,,,- ~, '\ <~"r='''"'-= HFNA-000003534 EPA Inspection Report - Page 1046 of 1969 IN THE UNITED STATES DISTRICT COURT FOR THE DISTRICT OF NEW MEXICO UNITED STATES OF AMERICA, ) ) Plaintiff, ) ) and ) ) STATE OF NEW MEXICO, ) STATE OF MONTANA ) ) Plaintiff-Intervenors, ) ) v. ) ) NAVAJO REFINING COMPANY, L.P. , ) MONTANA REFINING COMPANY ) ) Defendants. ) ) Civil No. CONSENT DECREE EPA Inspection Report - Page 1047 of 1969 after Navajo and/or Montana Refining, as applicable, receives the results of the Third-Party TAB Study and Compliance Review, Navajo and/or Montana Refining, as applicable, shall submit the results to the Applicable Federal and State Agencies. EPA, the Applicable State Agency, Navajo and/or Montana Refining, as applicable, subsequently shall discuss informally the results of the Third-Party TAB Study and Compliance Review. By no later than one-hundred twenty (120) days after Navajo and/or Montana Refining, as applicable, receives the results of the Third-Party TAB Study and Compliance Review, or such other time as Navajo and/or Montana Refining, as applicable, and EPA may agree, Navajo and/or Montana Refining, as applicable, shall submit to EPA for approval a plan that addresses any deficiencies identified in the Third-Party TAB Study and Compliance Review and any deficiencies that EPA brought to the attention of Navajo and/or Montana Refining, as applicable, as a result of the Third-Party TAB Study and Compliance Review. A copy of this plan shall be submitted to the Applicable State Agency. The review and approval of this Plan shall be done in accordance with Paragraph 22.D.iii of this Decree. Certification of Compliance shall be done in accordance with Paragraph 22.D.iv. J. End of Line Sampling (TAB is equal to or greater than 1 Mg/yr but less than 10 Mg/yr). The provisions of this Paragraph 22.J shall apply from the date that the final BWN Compliance Review and Verification Report submitted for any Covered Refinery pursuant to Paragraph 22.C shows that a Covered Refinery's TAB is equal to or greater than 1 Mg/yr but less than 10 Mg/yr, through the earlier of: (1) the time that the Covered Refinery reaches a TAB of 10 Mg/yr or more (in which case, the provisions of Paragraph 22.I shall begin to apply); or (2) termination of the Consent Decree. i. Navajo and/or Montana Refining, as applicable, shall, once per calendar year, conduct sampling, consistent with the requirements of 40 C.F.R. 61.355(c)(1) and (3), of all waste 67 EPA Inspection Report - Page 1048 of 1969 streams containing benzene that contributed 0.05 Mg/yr or more to the TAB set forth in the final BWN Compliance Review and Verification Report or in the previous year's TAB, whichever is later; ii. By no later than ninety (90) days after the date of submitting the final BWN Compliance Review and Verification Report, representatives from EPA and the Applicable State Agency shall meet at the Covered Refinery with representatives from Navajo and/or Montana Refining, as applicable, for the purpose of identifying an appropriate procedure for conducting EOL sampling and measuring EOL benzene quantities at that Covered Refinery. EPA, the Applicable State Agency, and Navajo and/or Montana Refining, as applicable, shall confer about potential EOL sample locations and shall review process and flow information and oil movement transfers. By no later than thirty (30) days after EPA and the Applicable State Agency have met with Navajo and/or Montana, as applicable, at the Covered Refinery, Navajo and/or Montana Refining, as applicable, shall submit a plan to EPA for approval that contains proposed sampling locations and methods for flow calculations to be used in the EOL determination of benzene quantity. A copy of this plan shall be submitted to the Applicable State Agency. Any disputes regarding plan approval under this Paragraph 22.J shall be resolved in accordance with the dispute resolution provisions of this Consent Decree. If, during the life of this Consent Decree, changes in processes, operations, or other factors lead Navajo and/or Montana Refining, as applicable, to conclude that either the approved sampling locations and/or the approved methods for determining flow calculations no longer provide an accurate measure of the Covered Refinery's EOL benzene quantity, Navajo and/or Montana Refining, as applicable, shall submit a revised plan to EPA for approval. A copy of this revised plan also shall be submitted to the Applicable State Agency. 68 EPA Inspection Report - Page 1049 of 1969 January 30, 2018 HOL[)FFRON'IlER" U,S, Environmental Protection Agency Director, Air Enforcement Division Ariel Rios Building 1200 Pennsylvania Avenue, N.W. Mail Code 2242-A Washington, DC 20460 Cenified..Mail/Rernm __ R,~ceipl 7014 3490 0000 6269 7233 Re: Quarterly lm_plemeutatkm Progress Report Pursuant to the CoM.seut Decree entered JVfo.rch 5~ 2002 by the U.S. District Court for the District of New Mexico in Unitt!d States of America et at v. Navajo .Refining Company~ LLC et al. Dear Director; Pursuant to Paragraphs 37 and 23.0 of the subject consent decree, lhis subi.TJ.ittal provides the status of implementation of consent decree requirements through the calendar quarter ending December 31, 20 l 7 frir Hollyfrontier Navajo Refining LLC (formerly Navajo Refining Company, LLC), (Nava,jo's) Artesia and Lovington, NM refineries. As specified by Paragraph 37, a statement of certification is provided on the following page, In accordance ,vith the notice provi skms of Paragraph 91, copies of this report are being mailed to EPA Region 6 (Le,, the Applicable EPA Region) and to both addresses listed for the State of New Mexico. Navajo ts also providing an additional hardcopy to EPA\; contractor and electronic-mail copies to the addresses provided in EPA's letter dated August 1, 2002, provided by electronic mail on January 3 l, 2008, and EPA's electronic e-mail update dated J'vfarch 19, 2013, ff you have any questions regarding this submittaL. please contact me at the address below or by phone at 575-748-3311. Sincerely, Scott M. Denton Environmental Manager HollyFrontier Navajo Refining LLC Holly.FmDtkr Navajo Rdi:afa.g U.,C 501 East Main Artesia, NM 83210 (575) 748-331 l htt:p://www.holl:yfrontier.com HFNA-000001711 EPA Inspection Report - Page 1050 of 1969 By signature bdow, the undersigned hereby ce1tifies to the following: _Statement of Ce1tification I certify under penalty of law that this inforrnation was prepared under my direction or supervision in accordance with a system designed to assure that qualified personnel properly gather and evaluate the inforrnation submitted, Based on my directions and my inquiry of the person(s) who manage the system, or the person(s) directly responsible fr)r gathering the ini(mm1tion, the information submitted is, to the best of my knowledge and belief, tnw, accurate, and complete. .,...,,7 ./.;:~(~/ch;/1:-....t ) / ~ I ~ ;, .(...,.;~ /."--- R~ibert O'Bden Vice President & Refinery Manager HollyFrontier Navajo Refrt1ing LLC Enclosure cc (w/enc.): Bureau Chief Air Quality Bmeau New Mexico Environment Deparlment 525 Camino de los Marquez, Suite 1 Santa Fe. NM 87507 Chi<:f Air, Toxics, illld Inspection, Coordit1at.irn1 Brnnch Environmental Protection Agency, Region 6 l445 Ross Ave1111c Dallas, TX 752.02,2733 General Counsel Otlice of General Counsel New Mexico Envirnnment Dcpanmenl P.O. Box 261 ](I Santa Fe, NM 87502~61 W lJ.S. Environmenwl Protection Agency c:/o Matrix Environmemal & Geutechnical Services Matrix New World E11gineering, lnc. 26 Culnmhia Turnpike Florham Park NJ 07932 Electrot1i;; cc (w/enc ): Envirm1mental File: 1-lollyFrontier: R. O'Brien. B. Romine, J. Stump, I. Jones, T. Wlieelcr, A. Beard Omsent Decree.SuhmRe,p.Quarterly .Reports.2018.01.3() HollyFn::mtki: Navajo Refining LLC 50 l Ea;;t l'vfain ' .i\Jtcsia, NM 882 JO (575) 743-33 I 1 l:)j;j:p://'i\"IVW.hollyfrontier.com HFNA-000001712 EPA Inspection Report - Page 1051 of 1969 New Mexko Envi.rom:ne.nt Depa:rt:ment Air Quality Bureau Compliance and Enforcement Section 525 Camino de los JV[arquez, Stlite 1 Santa Fe, NM 87505 Vern.ion 05.02.13 Phone (505) 476-4300 Fax (505) 476-4375 - '-,, ~p~rDUSE.ONLY--- RE PORTIN(; SUBrvUTTA.L FORIVI NMED USE ONLY :::::::::.. A._::_~:~1--_-_-_-_-.....::::::::::::::::::::::: SECTION IM GENERAL COMPANY AND FACILITY INFORMATION --------v-~~-- A. Company Name: 0. Fadiitv Name: HollyFmntier Navajo Refining LLC HollyFrontier Navajo Refining LLC B.1 Companv Address: PO Box 159 E.1 Facility Address: 501 E.Main St B.2 City: Artesia 13.3@ Skte: IBA Zip: NM 88211-01591- 1 E.2 City: Arteslz E.3 @ State: EA@ Zip: NM 88210 C.1 Compi.my Er111imnmr.mtal Coritact: Scott f\/t Denton C.3@ Phone Number: 575-746-5487 C.5@ Email Address: ---- C.2 Title: F. 1 @ Facility Contact: Environmental Manager Scott fvL Denton C.4 Fax Number:-----------------------,.1-~F-.3-~"_P_h_o_n_e_N_u_n-1b_e_r_:- - - 575-746-5451 575-746-5487 F.5 Email Address; F.2 Title: Environmental Manager F.4@Fax Number: _____ __I 575-746-5451 Scott_Denl.on@hollyfrontier.corn G. Resoonslb!s Official: IT ScottDenton@hollytrontier.com =,'"-----:----,-------------.--========',<~c-,==,e---:---:-----,--------:"'--------,-----------'-------.-----.=~-.-,,-==-~====.,-,-------------------------.---,=----=---=----=---===acl . Title: L Phone Number: 1 J. Fax Number: Robert O'Brien 'ice President & Refinery 575-748-3311 1 575-746--5451 T_-~~;-J~}~~r5e~nlt J --------------------------------------------=-----=---,-=---=----=-~===- naqer _}'rii0_Ai_ Number:________________j\,Jht~~R~ Permit Number:_______ ~=====""====--,=---=----=---=---=----=---=----=----=---=----=----=---=----=----=-------_-___________________L.__________________________._ ____ ------------------------------"'-------------------------= !mme D11te: NP~5~-1~~g~J~:~X~be~: ~8/~2~~1~~rmit ls_sim--~-~-t:~_'._____ ~; ~~po~~~g1j;~~;d: 0 To: 12i31/2017 I I \ -------- ~-~~T.IQ_~__!_l___~__!_'fPE OF SUBMITTAL (?..~-~-9.-~---~-i:i-~__ that applies} A. [----] Title V Annual Compliance .Permit Conditionts}: Dascrlption: Certification a. D Title V Semi-amn.iai Monitoring Report Permit Conciitionis}: Descr\ption: C. [] NSPS Requirement (40CFR.60) ReQulatlon: Sectionfai: --------------------------------------------------------------------------------------------------- Description: o. D MACT Requirement (40CFR63) 'ReQu!ation: Section{s); Descrimion: E. D F. D NMAC Requirement (20.2.KK) or N!2SHAP Requirement {40CFR61) Permit or Notice of Intent (NOi) Requirement Rer.w!ation: Section fa}; Permit No,0: or NO! No.0: Condition(s): Description: Om;cription: Requirement of an Enforcement Action NOV No, [J: or SFO No, [J; Section(s): or CD No. Q: or Other [J; Cl\f--01 1422LH Pam.graphs 37 and 2:3,0 Description: EPA Consent Decree Quarterly Report for HollyFrontier Navajo Refining (Artesia and Lovington) SECTION IV M CERTIFICATION !------------------------------------------------------ --------------------------------------------------------- ------------------------------------------ ------------------------------------ ! iks~~l"lsfole Offai~I for Tlt!e V? [] No Reviewed By: ------------- Date Reviewed: --------------------------------- HFNA-000001713 EPA Inspection Report - Page 1052 of 1969 New Mexico Enviromnernt Depa.rtrnwnt Air Quality Bu..reau. Compliance and Enforcement Section 525 C:amfao ik Jos Marquez, Suite i Santa Fe, NM 87505 PboEJe {505) 476-4300 Fax (505) 476-4375 ~~ j REPORTING SUBMITTAL FORM SECTION I w GENERAL COMPANY AND FACILITY INFORMATION ---------- A, Company Name: !), Fac!!!tv Name: HollyFrontier Navajo Refining LLC HollyFrontier Navajo Refining LLC B,1 @Company Address; PO Box 159 E1@ Fadlity Address: 7406 South Main ----............................... B-2@City: Artesia ~J-,clt!-,'R)c-Scccta,-t~e:~~1!2~)1~~;5gJ r.~~:g~~:t __-_-_-__~~~~~~~~-l,~-J./~....StateT~~ti~Zip: C. 1 Compmy Envlmnmenfai Contact: Scott M. Denton C.3@ Phone Number: 575-746-5487 C.5@ Email Address: Co2Titie: Environmental Manager C.4@ Fax Number: 575-746-5451 .......................................................... F.1@Facl!ltyContact: Scott M. Denton F,3 Phone Number: 575-746-li4ffi' F.5@ Email Address: F.2Tltie; 1 ...1..-~.r_1!1r.:'.12i:11.~~_l:3..1...~anager FA@ Fax Number: 575.745 .. 5451 -----< ~cott Drnton(alhollyfmnli,,r com ScottDentor llyfrontier.com ...................................- ........... . ~,Re~oo~sible Official: /Titlev-'o-n-iv-l:==.=H-.fiti";t-............w== = = = = = ' Number: .!. F""a=x=N7 l=im=,cb=er: I Robert O'Brien Vice President & Refinery 575_74G~!:i451 .................w.........................................,........., .,.=....=....=.....=....J....,.~.. ~ ~ ) g f ~ = = f ' ,==~=====,cc=cc,,cc==b==,,,.w.w.w.w.w......................==..=....=.... = = = 4 IC@ Al Number: L Title V Permit Number: M. Tltie V Permit issrn, Date: N. NSR Permit Number: 0. NSR Permit Issue Dale; 622 P020-R2 07/13/2015 0273-1\/19 05/06/2014 - - - - - - - - ~ - - P, Reporting Period: From: 10/01/2017 fo: 12i31/20'1? SECTION ii - TYPE OF SUBMITTAL (checkone_that_appiies) ............ A.[".] Title V Annual Compliance Permit CondWon{s}: Certification Description: B. D C. [.] D. LJ E, [ ....] Tille V Semi-m1mial Monitoring Report NSPS Requirement (40CFR60) MACT Requirement (40CFR63) NMAC Requirement (20.2,xx) or NESHAP Requirement (40CFR61) Permit Condition/Si: .... Reiwiation: Description: SecUonlsl: Rem.liation: ........ Sectionfol: Requlation: .-........ Sectionlsl: F.O Permit or Notice of Intent (NOi) Requirement Permit No.D: or !110! 1\!o.D: Condition(s): G " [S',J, Requirement of an Enforcement Action I NOV No. D: m SFO No. 0: ISection(s): or CD No, 0: orOtlier 0: Parngrnphs 37 and 23.0 Cl\/"01 1422LH 1 '" -~~ - ..... Description: Description; - DescripUon: - Description: - Description: - EPA Consent Decree C!uarterly Report for HollyFrontier Navajo Refining (Artesia and Lovington) SECTION IV~ CERTIFICATION ----- After reasonable inquiry, I Robert O'Brien ---c(~-~-,rm of rnp~ftl~g ~ffki~I) ---- - - - - - - - - - - - - - --- certiiy that lhe iniormation in this submittal is true, accurate and complete, Cf!) Tit~e; Vice President & Refinery Manager 01/30/2018 Reviewed By: _ _ _ _ _.................................................... Date Reviewed: HFNA-000001714 EPA Inspection Report - Page 1053 of 1969 CALENDAR QUARTERlY REPORT SUBMITTED PURSUANT ro SECTION IX OF THE CONSENT DECREE ENTERED IN UNITED STA TES OF AMERICA ET AL V: NAVAJO REFINING COMPANY, LA, AND MONTANA REFINING COMPANY (ENTERED MARCH 5, 2002} Cumulative from Lodging (December 20, 2001) Through December 31, 2017 Ho!lyFrontier Navajo Refining LLC (formerly Navajo Refining Company, LLC,) Artesia and Lovington, NM Refineries PoOo Box 159 Artesia, NM 8S211~(H59 HFNA-000001715 EPA Inspection Report - Page 1054 of 1969 Calendar Quarterly Re12ort _4th Quarter 2017 Hoi!yFrontier Navajo Refining LLC, Artesia and Lovington Refineries TABLE OF CONTENTS 1 oO INTRODUCTION o, "oo, " ..................... , oo," ........... ".oo, ,,,00,,,.,00," "' ... " ................... 1 :2o0 PROGRESS REPORT ON IMPLEMENTATION OF SECTION V OF THE CONSENT DECREE. o.... 00 oo oo .... 00." o00 ..... , , ,,. " ". 00 00.".,, ,,.". 00 ,, 00 ..... , , ,, ................... 2 3o0 SUMMARY OF ACTUAL OR ANTICIPATED PROBLEMS IN IMPLEMENTING THE REQUIREMENTS OF SECTION Vo o,,,,oo,"ooo,"oo,,,,.oo,"oo,,,,.oo,,,.oo .. ,,.oo,,, ,.".oo,"''''''"''"'21 4.0 SUMMARY OF EMISSIONS DATA ....,...........,....,.............,.............,, .........,,,.0, .. ,0.... ,o..:22 5.0 IMPLEMENTATION OF ENVIRONMENTALLY BENEFICIAL PROJECTfL..o...........,.:26 6.0 OTHER MATTERS ""o .... 00.-,.00, ..... "' ... "' 00.-,.00.-,.00 .... ,00 '" ,oo '"oo " .. oo .... 00.-,,00" ..... ,..,., .... 30 ATTACHMENTS ATTACHMENT 1 - APPENDIX G SUMMARY REPORT ATTACHMENT :2 -APPENDIX H SUMMARY REPORT ATTACHMENT 3 - QUARTERLY EOL SUMMARY ATTACHMENT 4-ANALYTICAL REPORTS EOL SAMPLING ii HFNA-000001716 EPA Inspection Report - Page 1055 of 1969 Calendar Quarterly Regort 1 -4 ri Quarter 2017 HoiiyFrontier Navajo Refining LLC, Artesia and Lovington Refineries CALENDAR QUARTERLY REPORT Cumulative from Lodging (DECEMBER 20, 2001) Through December, 2017 HoilyFrontier Navajo Refining LLC (Navajo} Artesia and Lovington, NM Refineries 1.0 INTRODUCTION In accordance with the requirements of Section IX of the Consent Decree entered in UNITED STA TES OF AMERICA ET AL, D, V.M NAVAJO REFINING COMPANY, LP, AND MONTANA REFINING COMPANY(entered March 5, 2002), Navajo submits the following "calendar quarterly report" for the Artesia and Lovington, NM refineries. Section !X requires that the quarterly report be submitted within 30 days following the calendar quarteL Today's report covers actions through the fourth quarter 2017. For completeness, this report addresses relevant actions or activities not just within the current quarter but anytime after the December 20, 2001 Date of Lodging, The contents of this report include: 1. A progress report on the implementation of the requirements of Section V (Section 2,0) 2. A description of any problems antlclpated with respect to meeting the requirements of Section V (Section 3.0) 3. A summary of the emissions data as required by Section V (Section 4.0); 4. A description of environmentally beneficial projects and SEP implementation activity during this reporting period (Section 5.0); and 5, Such other matters as Navajo believes should be brought to the attention of EPA (Section 6.0). Summaries showing the progress on Consent Decree Appendices G and H are provided as Attachments 1 and 2, respectively. 1 HFNA-000001717 EPA Inspection Report - Page 1056 of 1969 Hol!yFrontier Navajo Refining LLC, rtesia and Lovington Refineries 2.0 PROGRESS REPORT ON IMPLEMENTATION OF SECTION V OF THE CONSENT DECREE A. Section V, Paragraphs 11 and 14: NOx and CO Emission Reductions from FCCUs Paragraph 12: S02 Emission Reductions from FCCUs Paragraph 13: PM Emission Reductions from FCCUs Artesia FCCU (No FCCU at lovinqton): Requirement CD Status/Comment Para.graph -----,+---""--.!L---;f.--------------- Begin baseline period, 11.B Requirement completed. The optimization period perform notices of low- NOx was completed and the optimized addition rate to be promoter and optimization used during the demonstration period was study. Baseline period data submitted to EPA with supporting documentation on collection from 1/1/04 -- 2/24/05, 6/30/04. Optimization period to commence no later than _)une ..30.,...2004................................................................... Commencement of NOx 11.D -r-As-,;-greed-between Nava}oand EPA, the Additive Demonstration Demonstration Period ended 05/31/2006. Navajo Period and reporting submitted proposed concentration-based NOx limits beginning 3/31/05, on 07/27/2006. '--------------"'------..L-------------- 2 HFNA-000001718 EPA Inspection Report - Page 1057 of 1969 -----------------~w--------- Requirement Install/certify CEMS to monitor FCCU NOx and 02 by 12/31/03. CD Paragraph 11 .F Status/Comment ! CEMS installed and certification RATA performed 11/13/03. Report showing initial certification submitted to NMED on 1/7/04. Pursuant to 40 CFR 60 App F, annual RATA performed 02/14 and 02/i 5/06. Report showing certification submitted to NMED on 03/15/06. Pursuant to 40 CFR 60 App F, annual RATA performed 01/24/07. Report showing certification submitted to NMED on 02/22/07, Pursuant to 40 CFR 60 App F, annual RATA performed 01/22/08. Report showing certification submitted to NMED on 02/18/08. Pursuant to 40 CFR 60 App F, annual RATA performed 03/03/09, Report showing certification submitted to NMED on 03/30/09. Pursuant to 40 CFR 60 App F, annual RATA performed 03/02/2010 and 03/03/2010. Report showing certification submitted to NMEO on 04/05/2010, Pursuant to 40 CFR 60 App F, annual RATA performed 03/01/2011. Report showing certificatlon submitted to NMED on 03/28/2011. Pursuant to 40 CFR 60 App F, annual RATA performed Oi /17/2012, Report showing certification submitted to NMEO on 02/17/2012, Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2013, Report showing certification submitted to NMED on 02/07/2013. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2014. Report showing certification submitted to NMED on 02/04/2014, Annual RATA performed Oi/06/2015. Report submitted to NMED on 02/05/2015. Annual RATA performed 01/05/2016, Report submitted to NMED on 02/04/2016. Annual RATA performed 01/03/2017, Report submitted to NMED on 02/04/2017. A review of documentation of QC procedures under 40 CFR 60 App. F was recently undertaken. Documentation of a!I QC procedures in accordance with 40 CFR 60 App. F was completed as of 12/31/2017, 3 HFNA-000001719 EPA Inspection Report - Page 1058 of 1969 Calendar Quarterly Re13ort -4th Quarter 2017 HoliyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirement ----~-- Submit plan to minimize NOx from FCCU during GOHT outages within 180 days of lodqinq Date, Install and operate wet gas scrubber on FCCU to meet 25 ppmv (annual avg) and 50 ppmv (7-day) S02 by 12/31/03.-~----- Install and calibrate S02 GEMS in accordance wlth 40 CFR60,11, 60,13and Part 60 App. F CD Paragraph 11,G 12,8 Status/Comment Submitted 6/18/02, EPA's response letter dated 12/9/04 enumerated the requirements for Navajo to have relief from the short term NOx emission limit -~--~----- Wet gas scrubber installed and operational during 4th Quarter 2003, S02 performance testing done i 0/16/03; report submitted 1/7/04, 12,D CEMS installed and certification RATA performed 11 /13/03, Report showing initial certification submitted to NMED on 1/7/04, Pursuant to 40 CFR 60 App F, annual RATA performed 02/i 4 and 02/15/06. Report showing certification submitted to NMED on 03/15/06, Pursuant to 40 CFR 60 App F, annual RATA ! performed 01/24/07, Report showing certification i submitted to NMED on 02/22/07, Pursuant to 40 CFR 60 App F, annual RATA performed Oi/22/08. Report showing certification submitted to NMED on 02/i 8/08, Pursuant to 40 CFR 60 App F, armuai RATA performed 03/03/09, Report showing certification submitted to NMED on 03/30/09, Pursuant to 40 CFR 60 App F, annual RATA performed 03/02/2010 and 03/03/2010. Report showing certification submitted to NMED on 04/05/2010 0 Pursuant to 40 CFR 60 App F, annual RATA performed 03/01/2011. Report showing certmcation submitted to NMED on 03/28/201 i. Pursuant to 40 CFR 60 App F, annual RATA performed 01/17/2012, Report showing certification , submitted to NMED on 02/17/2012. I Pursuant to 40 CFR 60 App F, annual RATA performed Oi/08/2013, Report showing certification 1 submitted to NMED on 02/07/2013, Pursuant to 40 CFR 60 App F, annual RATA performed 01 /08/20i 4. Report showing certification submitted to NMED on 02/04/2014, Annual RATA performed 01/06/2015, Report submitted to NMED on 02/05/2015. Annual RATA performed 01/05/2016, Report submitted to NMED on 02/04/2016, Annual RATA performed 01/03/2017. Report submitted to NMED on 02/04/2017 See entry for Paragraph 11 .F. regarding 40 CFR 60 A(l[!, F QC procedures, --- 4 HFNA-000001720 EPA Inspection Report - Page 1059 of 1969 Calendar Quarterly Re9ort -4111 Quarter 2017 HoliyFrontier Navajo Refining LLC, Artesia and Lovington Refineries - -------------------------------------------------------------,-----------,----------------------............., Requirement CD Status/Comment P a r a g r a p h - - A - - - - - - ~ ~ ~ - + - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 1 WGS shall achieve 1 lb PM 13.B Wet gas scrubber installed and operational during per 1000 lb coke bum on 3-hr 4th Quarter 2003. basis by 12/31 /03. PM testing completed 11 /13/03 and report submitted 1/7/04. Results of 0.5-0.6 lb PM per 1,000 lb coke bum compared to <1.0 lb PM per 1,000 lb coke bum standard. Additional testing was performed 3/3/04 foHowing repairs to the scrubber. These test results indicate <0.25 lb PM per 1,000 !b coke burn (Le., 25% of standard), 5 HFNA-000001721 EPA Inspection Report - Page 1060 of 1969 Calendar Quarterly Report _4th Quarter 2017 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requfrm"i,r- ctf:s1:afiis1i;"6"inmni" --! - . Meet 500 ppmv CO on 1-hr basis and 100 ppmv on annual avg. by 12/31/03. Install/Certify CEMS for FCCU CO and 02 by 12/31/03. .............Paragraph....i.................................. - -.:::-1 14.B and CO performance testing conducted 10/16/03. CEMS 14.C installed and RATA performed 11/13/03. Report showing certification submitted to NMED on 1/7/04. Pursuant to 40 CFR 60 App F, annual RATA performed 02/14 and 02/15/06. Report showing certification submitted to NMED on 03/15/06. Pursuant to 40 CFR 60 App F, annual RATA performed 01/24/07. Report showing certification submitted to NMED on 02/22/07. Pursuant to 40 CFR 60 App F, annual RATA performed Oi/22/08. Report showing certification submitted to NMED on 02/18/08. Pursuant to 40 CFR 60 App F, annual RATA petformed 03/03/09, Report showing certification submitted to NMED on 03/30/09. Pursuant to 40 CFR 60 App F, annual RATA performed 03/02/2010 and 03/03/2010. Report showing certification submitted to NMED on 04/05/2010. Pursuant to 40 CFR 60 App F, annual RATA performed 03/01/2011. Report showing certification submitted to NMED on 03/28/2011. Pursuant to 40 CFR 60 App F, annual RATA performed 01/17/2012. Report showing certification submitted to NMED on 02/17/2012. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2013. Report showing certification submitted to NMED on 02/07/2013. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2014. Report showing certification submitted to NMED on 02/04/2014. Annual RATA performed 01/06/2015. Report submitted to NMED on 02/05/2015. Annual RATA performed 01/05/2016. Report submitted to NMED on 02/04/2016. Annual RATA performed 01/03/2017. Report submitted to NMED on 02/03/2017. See entry for Paragraph 11.F. regarding 40 CFR 60 App. F QC procedures. 6 HFNA-000001722 EPA Inspection Report - Page 1061 of 1969 Calendar Quarterly Report _4th Quarter 2017 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries EL Section V, Paragraph 15: NSPS Applicability of FCCUs Artesia FCCU No FCCU _at.Lovington): Requirements CD .............................................. Status/Comment ,........------------+------P_aragraph................................................................................................................ NSPS becomes applicable to 15 Wet gas scrubber installed and operational during FCCU for S02, PM, CO and 4th Quarter 2003. PM performance testing, initial opacity on 12/31/03. CEMS cetiification RATA for S02 and CO completed 11/13/03 and report submitted 1/7/04. AMP for opacity submitted 12/31/03; pending wrttten approval. Method 9 readings indicate O - 5/o opacity. Annual PM testing per AMP was performed 2/8/05 indicating 0. 11 lb PM/1000 lb coke. Annual PM testing per AMP was performed 2/15/06 indicating 0.19 lb PM/1000 lb coke. Annual PM testing per AMP was performed 1/24/07 indicating 0.34 lb PM/1000 lb coke. Annual PM testing per AMP was perforrned 1/22/08 indicating 0.13 lb PM/1000 lb coke. Annual PM testing per AMP was performed 3/3/09 indicating 0.47 lb PM/1000 lb coke burned, Annual PM testing per AMP was performed 03/02/2010 and 03/03/201 OJndlcatlng 0.54 lb PM/1000 lb coke burned, Annual PM testing per AMP was performed 03/01/2011 indicating 0.23 lb PM/1000 lb coke burned, Annual PM testing per AMP was performed 01/17/2012 indicating 0.39 lb PM/1000 lb coke burned. Annual PM testing per AMP was performed 01/08/2013, which did not show compliance, and again on 3/04/2013 indicating 0.204 lb PM/1000 lb coke burned. Annual PM testing per AMP performed 01/08/2014 indicating 0,71 !b PM/1000 lb coke burned, Report ------- - - - - - showing certification submitted to NMED on 02/04/2014. Annual PM testing per AMP performed 01/06/2015 indicating 0. 11 lb PM/1000 lb coke burned, Report submitted to NMED on 02/05/2015, Annual PM testing per AMP performed 01/05/2016 indicating 0.35 lb PM/1000 lb coke burned, Report submitted to Nrv1ED on 02/04/2016. Annual PM testing per AMP performed 01/03/2017 indicating 0.03 lb PM/1000 lb coke burned. Report submitted to NMED on 02/03/2017. .... ............................... ........................................... -----------....J 7 HFNA-000001723 EPA Inspection Report - Page 1062 of 1969 Calendar Quarterly Reeort 1 -4 h Quarter 2017 Ho!!yFrontier Navajo Refining LLC, Artesia and Lovington Refineries ......... Co Section V, Parn9meh 16:...N.9~.. !:;.~i.~.~io.~~R~.c.l~s;tigr,i~Jr..?.!!l...!j.1?.t.1?.!~...and Bo_i_!_er_s_ _----. Requirements CD Status/Comment ........... ..............................Paragraph ................................................................................................................................. _ _ _ ____, Install NOx control on B-7 by 16.B.iL and FGR started up on 12/17/2002. CEMS installed 12/31/02 to meet 0.06 16.C.i. and was successfully certified by a RATA lb/MMBtu and operate CEMS performed 12/18/2002. Test results and CEMS on B-7 for NOx and 02. indicate B-7 meets NOx control requirement. Pursuant to 40 CFR 60 App F, annual RATA performed 09/26/2006, 09/13/2007, 09/09/2008, 09/17/2009, 08/24/2010, 08/16/2011, 08/i 5/2012, 08/07/2013. RATA periormed 07/30/2014. Certification report submitted to NMED on 09/11/2014. RATA performed 07/23/20 i 5. Certification report submitted to NMED on 08/20/2015. RATA performed 07/13/2016. Certification report submitted to NMED on 08/05/2016. RATA performed 06/21/2017. Certification report submitted to NMED on 07/20/2017. ; . . . . . . . . . - - - - - - - - - - - + - - - - - ------ Install NOx control on 8-8 by 16-8.!i. and B-8 began actual initial startup and shakedown 12/31/03 to meet 0.06 16.C.i. period on 7/23/03. NOx contmts and CEMS !b/MMBtu and operate CEMS operational. CEMS RATA and B-8 performance on B-8 for NO.x and 02. testing done 10/29/03. Test report submitted 12/8/03. Pursuant to 40 CFR 60 App F, annual RATA performed 09/26/2006, 09/13/2007, 09/09/2008, 09/i?/2009, 08/24/2010 08/i 6/2011, 08/15/2012, 08/06/2013, 07/30/2014. RATA was performed 07/29/2014. Certification report submitted to NMEO on 09/i 1/2014. RATA was performed 07/13/2016. Certificatlon report submitted to NMED on 08/05/2016. RATA performed 06/2i/2017. Certification report submitted to NMED on 07/20/2017. ! - - - - - - - - - - - - - ~ - - -- Install next-generation ultra- 16.B.i., H-601 burners installed. Testing conducted on low NOx control on H-20 and 16.C.tii., and 3/2/04. Report including proposed compliance H-601 at Artesia refinery. Appendix C indicators and permit limits was submitted 5/14/04. Performance test H-20 and H-20 burners installed prior to 12/31/05 deadline H-601. Establish compliance and heater resumed operation 12/29/05. indicators by an initial performance test. H-20 performance test conducted on 02/16/06. Report submitted to NMED on 03/23/06. Permit limit proposed in air perrnit application submitted to NMED on 4/27/06. NMED issued permit 6/23/06. --- 8 HFNA-000001724 EPA Inspection Report - Page 1063 of 1969 Calendar Quarterlx;; Reeort _4th Quarter 2017 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements Install next-generation ultralow NOx control on H-101 at Lovington refinery. Operate CEMS or PEMS on H-101 by i 2/31/05. CD Paragraph 16B.i., 16,C.!L, and Appendix C Status/Comment Heater H-101 was removed from service .............. ~ ....... November 2003, Navajo installed NGULN8s in the new Crude Oil Charge Heater (H-103) that replaced H-i 01. H- 103 was completed during December 2003 turnaround and began operation after 4th Quarter turnaround. As-installed duty of NGULNBs was< 150 MM Btu/hr, but > 100 MM Btu/hr. H-103 initial testing done 03/04/04, Test report, including proposed parametric monitoring plan and permit limits, was submitted 05/14/04. In 02/2009, Navajo installed eight additional NGULNBs in the Crude Oil Charge Heater (H-103) that replaced H-101. As-installed duty of NGULNBs was > 150 MM Btu/hr, so a NOx CEMS was tnstalled. An initial performance test and the NOx CEMS RATA were conducted 05/21/2009. Pursuant to 40 CFR 60 App F, annual RATA performed 05/20/2010, 08/16/2011, 05/24/2012. RATA was performed 05/14/2013, CertificaUon report submitted to NMED on 06/10/2013, RATA was performed 05/13/2014. Certification report submitted to NMED on 06/12/2014. RATA was performed 05/06/2015, Certification report submitted to NMED on 06/04/2015. RATA was performed 05/04/2016, Certification report submitted to NMED on 06/03/2016. RATA was performed 04/25/2017, Certification report submitted to NMED on 05/16/2017, Install next-generation ultralow NOx control on H-600 and 70-H1/H2/H3 at Artesia refinery, Performance test H600, and 70-H1/H2/H3. Establish compliance indicators by 12/31/09. ------- - ---------------------------------------- 16.B.L, 16.C.iiL, and Appendix C See entry for Paragraph 11 .F regarding 40 CFR 60 App. F QC procedures. ------------ H~600: Air permit 0195-M25-R3 authorizing the burner retrofit was issued by NMED on 05/14/08, The retrofit was completed in 02/2009. The performance test was conducted 03/04/09 and the test report submitted 03/30/09. Administrative permit revision 0195-M26-Ri effective 04/14/2009. 70~H1!H2/H3: NGULNBs were installed in CCR Heaters 70-H 1/H2/H3 in May 2006 and heaters resumed operation on 6/2/0EL Performance test conducted 7/11/06 and test report submitted 8/15/06. An application for a proposed permit limit was submitted to NMED 9/28/06, NMED issued permit PSD-NM-0195-!V125 on 12/14/2007, 9 HFNA-000001725 EPA Inspection Report - Page 1064 of 1969 Calendar Quarterly Reeort -4111 Quarter 2017 Hol!yFrontier Navajo Refining LLC, Artesia and Lovington Refineries -------------------------------------------------------- ---------------------------~----~------------------------------------------------------------------- Requirements CO Status/Comment Paragraph ------------ ----------------------------------------------------------+-----=~---- -----------------------------~ Install next-generation ultra- 16.EU., An air permit application proposing the installation of low NOx control on B-SG- i6.CJiL, and NGUlNBs in SG-1101A and SG-1101B was 1i 01A and B-SG-1101 Bat Appendix C submitted to NMED on 12/21/2007. Permit 0273-M? Lovington refinery by authorizing the retrofit with NGULNBs was issued by 12/31 /09. Conduct performance test B-SG1101 A and B-SG-1101B and establish compliance indicators. NMED on 05/06/2008. Navajo subsequently decided to replace the existing boilers with new boilers using NGUlNBs. Permit 0273-M7-R1 authorizing the replacement boilers was issued by NMED on 10/14/2009. Boiler SG-11 OB was permanently shut down on 12/05/2009. its replacement, BO-i 104, began operation on 12/17/2009, Initial performance testing was conducted 01/28/2010 on B0-1104 and the report submitted to NMED on 02/24/2010. Because of initial operating problems with B0-1104, the second boiler, SG-1101A was not permanently shut down until 01/04/2010. Its replacement, B0- 1105, began operation on 01/15/2010. Initial performance testing was conducted 01/26/2010 on B0-1105 and the report submitted to NMED on 2/24/2010_ The B0-1105 initial performance test was conducted on i/26/2010, and the report submitted to the AQB on 02/24/2010. The 80-i 104 initial performance test was conducted on 01/28/2010, and the report submitted to the AQB on 02/24/2010. The burners installed with B0-1105 and 80-1104, were subsequently found to not meet the NGULNB performance specification in the Consent Decree, The installation or NGULNB in B0-1 i05 was completed 06/20/2013, The installation of B0-1104 NGULNB was completed 07/29/2013. BO-ii 05 NOx Pmiormance Test was completed 07/i 2/2013. 80-1104 NOx Perfom1ance Test was completed 09/04/2013. !U HFNA-000001726 EPA Inspection Report - Page 1065 of 1969 Calendar Quarterly Report _4th Quarter 2017 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries -------------------------------------------------------------------------------------------------------------------------------------------------------...., Requirements CD Status!Comment --------------------------------------------------------------------------------------------- Submit proposed NOx permit limits within 120 days of NOx __Paragraph _-------------------------------------------- 16. D Requirement completed. BM7: Proposed B-7 NOx limit submitted to NMED control technology installation. 01/31/03. BMf!: Proposed B-8 NOx limit submitted to NMED 12/8/03. t-MW1: Proposed H-601 NOx limit submitted 5/14/04 in stack test report and permitted in i 95- M17 as issued 12/15/04. H-103 (Lovington Refinery}: Proposed H-103 NOx limit submitted 5/14/04 in stack test report; on 2/21/06 NMED issued 0273-M4 to add the NOx limit After installing additional NGULNBs in 02/2009, the limits were confirmed in the 05/21/2009 test and included in Permit 0273-M7- Ri issued by NMED on 10/14/2009H-20: Proposed H-20 NOx limit submitted to NMED in air permit application on 04/27/06; permit 0195-M24 issued 06/23/06. 70~H1/H2/H3: Proposed 70-H1/H2/H3 NOx limit submitted to NMED in air permit application on 09/28/06; permit PS0-NM-0195-M25 issued 12/14/2007. HM800: Proposed H-600 NOx limit author1zed by NMED air permit administrative revision effective on 04/14/09, B0~1104 and B0-1105: (replacement boilers for B-SG-110A and B-SG-1101 B)_ Proposed 80-1104 and BO-i 105 NOx lirnits submitted to NMED in air permit application on 04/13/201 O; permit 0273-M8 issued 07/19/2010. Submit annual progress 1--------------1-iLE----------------+ l=frsf-i:E;-p;;rt--wa_s___s_i:i"bm"itfea---f~i"h97o"iCThe---;:e-;;-;;ruor________ report on NOx control 1 2003 was submitted 12/29/03 with supp!ementa! technology information provided 1/8/04. 2004 report submitted 12/31/2004. 2005 report submitted 12/31/2005. 2006 report submitted 12/1 1/2006. 2007 report submitted i 2/20/2007. 2008 report submitted 12/19/2008. 2009 report submitted 12/28/2009- 2010 report submitted 12/15/2010_ 2011 report submitted 12/31/2011. 2012 report submitted 12/11 /2012_ 2013 report submitted 12/i 8/2013. 2014 report submitted 12/19/2014. 2015 report submitted 12/31/2015. . 2016 report submitted 12/30/2016 ~~.......................- - - - - - - - - - - - - ~-20-17-re~ ort-su- bm-itte-d -12-/28-/2- 017-. - - - - - ~ 11 HFNA-000001727 EPA Inspection Report - Page 1066 of 1969 Calendar Quarterly Re,,2ort _4th Quarter 2017 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries CL Section V, Paragraph 17: S02 Emissions Reductions from Heaters and Boilers and .....................J'1SPS ~cability Requirements ,_P_a_ra-":q=~-a~p_h----+--------S-ta_t_us_1_c_o_m_m_e_nt--------l. NSPS Subparts A and J 17,B Commenced 12/20/01 become applicable to Heaters and Boilers by Date of See entry for Paragraph i 1.F. regarding 40 CFR 60 App. F QC procedures. Lodging. ----------~~~------~----- E Section V, Paragraphs 18 and 19 NSPS Applicability for SRP and Flari.ng .Pevices ........... Requirements CD Status!Comment ;..............................................................................................................+..... Para.graph SRP shall comply with NSPS 18.C.l. and Commenced 12/20/01. J limit and monitor tall gas 18.CJL See entry for Paragraph 11,F. regarding 40 CFR emissions by Date of 60 App. F QC procedures. Lodging. f------------..J NSPS Subparts A and J Appendix E ------------------------------------------------------------~---~----------j Commenced i 2/20/01, become applicable to Flares The recent implementation of flare monitoring by Date of Lodging. requirements under NSPS Ja resulted in the identification and repair of several relief valves that were leaking to the flare. In addition, three flare gas streams with higher sulfur levels were identified as routed to the Lovington flare. These three streams were rerouted to the fuel gas system. As of November 1i, 2015, ail gas streams currently routed to the flares are monitored for compliance with the NSPS Ja requirements. Excess emission information for the flares at Artesia and Lovington for the semiannual period: January-June 2016 was included in Attachment 4 to the 3rd quarter 20i6 Consent Decree Progress Report The excess emission information for events occurring during the semiannual period: July-December 20i 6 was included in the semiannual NSPS monitoring report submitted on January 30, 2017, and was attached to the 1st quarter 2017 Consent Decree Progress Report, Excess emission information for events occurring during the semiannual period: January-June 2017 was reported in the semiannual NSPS Ja monitoring report submitted on July 28, 2017, and were attached to the 3rc quarter Consent Decree Progress Report The excess emission information for events occurring during the semiannual period: July-December 20i 7 will be included in the semiannual NSPS monitoring report due on January 30, 2018, and will be attached to the 1st ,..............................--------' ...... quarter.201.8..consent ..Decree..Progress Report. 12 HFNA-000001728 EPA Inspection Report - Page 1067 of 1969 Calendar Quarterl:t; Reeort 1 -4 h Quarter 2017 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries ~----------~-~--~~ ----------------------- Requirements CD Status/Comment I Paragraph S-ubmiTAMP---p-iardci"r___Fi"~:i"res---+------A-p_p......,en"'---d-i--'----x-E------+---S-u_b_m_it-te_d_3_/_19_/_0_2__------------------------------------------ FL-400, FL-401, FL-402 and FL-403 within 90 days of Lodging Date. ----------------------- I----------------------------------------------;-------------------------------------------------------------------------------------------------1 NSPS Subparts A and J Appendix E Off-Gas Scrubber system for sweetening sour LPG become applicable to Flare before combusting in flare completed by 12/31/06. FL-1001 at Lovington refinery on 12/31/06. ,-......--------------,--------------------------------------------------+----------------------------------------------------------------------------------------------------------------------------------1 Submit AMP plan for Fla.re Appendix E An approvabie AMP was submitted 02/14/07. AMP i Fl--1001 at Lovington refinery is pending EPA approval. U?_y7/30/07. ________________________________________________- - - - + - - - - - + - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Submit enhanced 18,D Plan submitted on 9/16/02 and updated on Maintenance and Operation 03/24/05, The last revision was completed on pian for SRP (PMO plan) 09/2017 within 270 days of Date of ___ Lodging. _________________________________________________________________ _ Begin optimization study on ----+----------------------------- 18-E Study commenced by 1/1/04 deadline. SRP by 1/1/04. Complete optimization study on SRP and report results by 12/31/04. 10-day prior notice required : for scheduled Duke Energy shutdowns affecting Lovington refinery by Date of Lodging. 18.E 19.E Navajo retained a third party to coordinate performance testing for the optimization study and prepare a report which was submitted to EPA on 12/31/04. Commenced 12/20/01. F. Section V, Paragraphs :20 and 21: Control of Acid Gas Flaring, Tail Gas Incidents and Hydrocarbon Flaring ---------------------------------------------------------------------------------------- - - - - - - - - - " - - - - - - - - - ~ - - - , - - - - - - - - - - - - - - - ------------------------- Requirements CD Status/Comment Paragraph ------- ------------------------------------------------------------------- - ~ - - - - - + - - - - - - - - - - - - - - - Perform root cause analyses 20 Commenced 12/20/01. for acid gas and tail gas incidents beginning on lod in Date. ---~-----~---------------- Perform root cause analyses 21 Commenced 12/20/01. for hydrocarbon flaring incidents beginning on Lodging Date. ------------------------------------------------------ __ J G, Section V, Paragraph 22: Benzene Waste NESHAP 13 HFNA-000001729 EPA Inspection Report - Page 1068 of 1969 Calendar Quarterly Regort _4th Quarter 2017 Ho!lyFrontier Navajo Refining LLC, Artesia and Lovington Refineries ------------------------------ - - - - - - - - - - - - - - - - ~----~~~-----~---- Requirements CD Status/Comment Complete Phase One of the . review and verification of the Paragraph 22.C.i. Completed 09/11/02, ....- ............. -------------------------- TAB by 9/16/02. f - - - - - - - - - - - - - ~ - - - - . . . . . , . . . . . - - , - - .......................................................................................... Submit BWN Phase One 22.CJ, Report of results submitted on 10/09/02. Compliance Review and Verification report for EPA approval by i 0/16/02. Suliinit amended..tA--ccs,--re_p_o_rt---+--2-2-.~D-i.-.....,.....A~m_e_n-de_d_T_A_B_r_e_p_ort_w_a_s-in-ciided.."in..the if BWN Compliance Review shows reporting applied. submittal. 10/09/02 --------- ------------------------------->-----~--------------~------------------------ Establish annual review 22.E Completed as part of Phase One review and is program now ongoing, --------------~~-w----------------------------------- ------------------------------------------------------------------------------ Train employees who conduct 22.G and A training plan was developed on 12/06/02 for the sampling. 22,M.iLa(1) Artesia Refinery (i,e,, since its TAB is greater than 1.0 Mg/yr). The first training session was held 01/07/03 at both the Artesia and Lovington refineries. The second training session for the two refineries was he!d 1/27/04 and 01/28/04, Annual refresher training for the two refineries was performed the weeks of 02/08/05, 03/27/06, 03/05/07, 02/25/08 (Lov), 11/07/08 (Art), 12/18/09, 12/17/10 and 12/20/2011, BWON TAB training was conducted on 11/08/2012 at the Artesia and Lovington refineries BWON sampling training was conducted on 01/14/2013and 04/18/2013, i1/12to 11/14/2013, 05/24/2014, 06/22/2014, 12/12/2014, 3/16/2015, 4/1/2015, 5/15/2015, 2/29/2016, 3/8/2016, 3/17/2016, and 09/25/2017. Submit schematics of ...............:2:i":FLC............ Submitted on 03/19/o"f.....RevEiiicfschematics Waste/Slop/Off-Spec Oil reflecting NSPS QQQ were submitted 04/29104. Management by 03/20/02, Schematics am awaiting approval by EPA --.................................................................................................................... -----1 Conduct annual sampling of 22.J.i. and The annual sampling was performed in February waste streams which the 22.M.ii.a(2) 2005. The results were in Attachment 4 to the first BWN Compliance Review quarter 2005 report, and Verification Report Annual sampling performed in February 2006. The showed to be 0.05 Mg/yr or results were in Attachment 4 of the first quarter greater. 2006 report Annual sampling was prniormed in September and December 2007, The results were submitted in attachment 4 of the first quarter 2008 report as required by 1f22.M.iLa(2), Annual sampling was performed in December 2008. The resu!ts were in attachment 4 of the first quarter 2009 report as required by 1f22.MJLa(2). Annual sampling was performed in December _...L....2,._ 009_ . _ Th_ e r_ esu_ lts_ w_ ere_ su_ bm_ itt_ ed _ in _ attachme _..............nt........ 4............., 14 HFNA-000001730 EPA Inspection Report - Page 1069 of 1969 Calendar Quartertx; Report _4t", Quarter 2017 Ho!lyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements CD Status/Comment Paragraph ------------------~- ---------------------------------------------------------- of the first quarter 2010 report as required by ,T22.MJi.a(2)_ Annual sampling was performed in December 2010. The results were in attachment 4 of the first quarter 201 i report as required by ,I22.MJLa(2), Annual sampling was performed in December 201 i, The results are in Attachment 4 of the first quarter 2012 report as required by 8'122.M.iLa(2), Annual sampling was performed in December 2012. The results were submitted in Attachment 4 of the first quarter 2013 report as required by ,T22JvLia(2). Annual sampling was performed in December 2013. The results were submitted in Attachment 4 of the first quarter 2014 report as required by 1[22.M.iLa(2), Annual sampling was performed in December 2014. The results were submitted in Attachment 4 of the f"t quarter 2015 report as required by 1f22.M.!La(2). Annual sampling was performed in December 2015. The results were included in Attachment 4 of the 1st quarter 2016 report as required by ,T22. M, iLa(2). Annual sampling was performed in October 2016. The results were included in Attachment 4 of the 1st quarter 2017 report as required by 1f22.M.iLa(2). Annual sampling was performed in December 2017. The results will be included in Attachment 4 of the 1st quarter 2018 report as required by f------------------------------------------------ ___________________________JJ22.M.ii.a(2). ------------------------------------------- Meet with NMED and EPA at 22.J.ii Navajo was notified by NMED and EPA via email the refinery and submit an dated 12/9/02 that the ,I22.J.ii visit by the agencies annual end of line (EOL) would not occura Navajo met the deadline by sampling p!an - applicable to submitting the EOL sampling plan on 2/6/03. Artesia Refinery (Le., TAB is Conditional approval of the plan was received from equal to or greater than i EPA by letter dated 1/23/04. Navajo responded by Mg/yr but less than 10 Mg/yr)- submitting a revised EOL sampling plan by letter dated 3/31 /04. ---~------------------------------------------- 15 HFNA-000001731 EPA Inspection Report - Page 1070 of 1969 Ho!lyFrontier Navajo Re ining LLC, Artesia and Lovington Refineries Requirnmonts ------ Conduct quarterly EOL sampling and submit the results to EPA in quarterly report -~----~--- CD Status/Comment Paragraph --+-----+----- 22.J.HL and These requirements are not applicable until EPA 22,MJLa(3) approves the sampling plan, Although EPA has not approved or commented on the revised sampling plan submitted 03/31/2004, Navajo conducted its first EOL sampling during the week of 3/22/2004. The EOL benzene quantity (BO) for the fourth quarter of 2004 was 0.8 Mg (projected annual< 10 Mg}. The annual TAB, submitted 4/05 was 4.9 Ma for Artesia and 1.5 Mg for Lovington. The 1"\ 2n~ 3rd, and 4tr, quarter 2005 EOL BQs were each <25 Mg. The 1'"', 2nd, 3rd, and 4th quarter 2006 EOL BQs were each <2.5 Mg. The 1st, 2nd, and 3rd quarter 2007 EOL BQs were each <2.5 Mg. The 4,n quarter 2007 EOL BQ result was greater than2.5 Mg. The rsr quarter 2008 EOL BQ result was less than 2.5 Mg. The 2"ct and 3rd quarter 2008 EOL BQ results were both greater than2.5 Mg. The EOL BQ for the 4th quarter of 2008 was <2.5 Mg and the projected 2008 TAB was <iO Mg/yr. The EOL BQ for the 1"\ 2rn:i, 3rd and 4th quarters of 2009 was <2"5 Mg and the projected 2009 TAB was < i O Mg/yr. The EOL BQ for the f\ 2'\ 3rd, and 4th quarters of 2010 was <25 Mg and the projected 2010 TAB was <10 Mg/yr. The EOL BQ for the f"', 2nd, 3rd and 4th quarters of 201 i was <2.5 Mg and the projected 2011 TAB was < 10 Mg/yL The EOL BQ for the 13', 2m\ 3rd and 4th quarters of 2012 were each <2.5 Mg and the projected 2012 TAB was <10 Mg/yr. The EOL BQ for the 18\ 2nd, 3rd, and 4th quarters of 2013 were each <2.5 Mg and the projected 2013 TAB was <iO Mg/yr. The projected 2013 TAB was < 10 Mg/yr. The EOL BQ for the 1"1, 2nd, 3rd, and 4th quarters of 2014 were each <2.5 Mg and the projected 2014 TAB was <10 Mg/yr. The EOL BQ for the 13\ znd, 3rd, and 4th quarters of 2015 were <2,5 Mg and the projected TAB for 2015 was <10 Mg/yr, The EOL BQ for the 1st quarter of 2016 was <2-5 Mg and the projected TAB for 2016 was <10 Mg/yr. The EOL BQ for the 211d quarter of 2016 was <2.5 Mg and the projected TAB for 2016 was <iO Mg/yr" The EOL BQ for the 3rd quarter of 2016 exceeded 25 Mg" As required by paragraph 22.JJv, Navajo --~-_L,______ ....?..l:1.~.r.r.1J.t.t.90....?....P.!.?..0...:0.'./JJ.1_J_t_).~..fq.l:J.n.b quarter Conser..it........... 16 HFNA-000001732 EPA Inspection Report - Page 1071 of 1969 Calendar Quarterlx: Re9ort -4th Quarter 2017 Ho!lyFrontier Navajo Refining LLC, Artesia and Lovington Refineries ' Requirements ---------~~--- ------------------------------ CD Paragraph ............... Status/Comment ---------------------~ ------------------ Decree report that identified the specific actions to be taken and the schedule for such actions to ensure that the TAB does not exceed 10 Mg in the calendar year. The EOL BQ for the 4th quarter of 2016 was <2.5 Mg and the projected TAB for 2016 was <iO Mg/yr. The EOL BQ for the 1st quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BO for the 2nd quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BO for the 3,d quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BO for the 4th quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. 17 HFNA-000001733 EPA Inspection Report - Page 1072 of 1969 Calendar Quarterl.:t: Reeort _4th Quarter 2017 HoHyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Develop and maintain written 23.A facility-wide LOAR compliance program by 04/19/02. LDAR Training within 1 year --;z"3"j(f of Date of Lodging. Completed before 4/i 9/02. Newly assigned personnel (both 310 party and Navajo) are receiving training. On going training programs have been implemented. P-er_fo_r_n_1-in-it-ia_l_L_D_A_R_3_r_d_ ;i:fcanci-l--3r~a-p-a-rty-a-ud-i-ts_f_o_r_A_rt_e_si-a--a.._nd_L_o_vi_n_g-to_n_w_e_r_e----i party/internal audits by 12/20/02 and correct deficiencies. Repeat audits every two years. 23.D conducted on 10/2002 and deficiencies were corrected per Paragraph 23.D. 3rd party audits for Artesia and Lovington were performed during 12/2004, 01/2007, 01/2009, and 01/2011. The Artesia and Lovington refineries underwent maintenance turnaround from January to March, 2013. The 2013 LOAR 3rd party audit was conducted from 09/16 to 09/20/2013, after the refinery was back ontine normal operation data has been collected for 1 complete quarter for comparative monitoring. A copy of the 2013 LOAR 3rd party audit report and resolutions were ' submitted in Attachment 5 of the 1st Quarter 2014 I report. 3rc party audits for Artesia and Lovington were performed during the week of October 5th to : 1 9 h, 2015. A copy of the 2015 LOAR 3rd party audit : i report and resolutions are included in Attachment 5 of the 1st Quarter 2016 report The 2017 LOAR 3rd party audit was conducted from 05/17 to 05/18/201 T A copy of the audit report was attached to the 3rd Quarter Consent Decree Progress Report. The audit resolutions will be included as Attachment 4 to the 1st Quarter reprni. r------------......+-----+-------------- Valves use 500 ppm leak ' 23.E.i. Completed prior to 12/20/03, : definition by 2 years after ! i Date of Lodginn i i --------- \ NSPS Subpart;::iGGG i -2-3-E. -,-iii--+-C-o-rr1_p_re_s_s_o_r_s_e_a_!s-y-s-te_m_w_a_s_u_p_g_r_a-de_d_d_u-rin__ g _--j i becomes applicable to FCCU 2003 FCCU turnaround. Operational beginning wet gas compressor on December 2003. 12/31/03 . ....... ............................................................. - + - - - - - - j - . - - - - - - - - - - - - - - - - - Pump monitoring using 23.E.ii.a., b., List of pumps comprising >85/o was developed internal leak definition of and c. and these pumps are using the 2,000 ppm leak : 2,000 ppm in accordance with definition for all monitoring subsequent to 12/20/03. phased-in schedule - i.e., Ail pump monitoring using internal leak definition of Ji 50%, by 6/20/03, 85% by 2,000 ppm after 4/20/05. -----------------'------..L.....---------------~--- 18 HFNA-000001734 EPA Inspection Report - Page 1073 of 1969 Calendar Quarterly Report _4th Quarter 2017 ..... "',,. HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements 12/20/03, and 100/o by \ 4/20/05 - - - - - - - - - - - - - - - - ................................................ CD Status/Comment Paragraph ---<------------------------------------- .......................................................................................................... -------------------- NSPS Subpart GGG 23.E!ii becomes applicable to Crude vent compressor at Lovington refinery as of Date of -------------- This was completed upon CD lodging, Crude Vent Compressor (C-150A/B) is now included in the LOAR monitoring program. ..lodging. --- ............................................................................................. ................................................ First attempt at repairs on 23.G i Commenced with January 2002 valves that have voe reading I monitoring. > 200 ppm within 90 days of ~ I ...l..o.....d....n.~i.n....nn ...D.....a....t..e................................................................tI,.......... ............................ ................................ . -- Quarterly monitoring of valves 23.H.iL Completed by i 2/20/01, - no Skip Period by Date of quarterly Lodging~_ _ -------<--- .................................................................... LOAR database to include 23.1.i, Commenced with May 2002 monitoring, date, time, operator, and instrument within 6 months of -----------~ L. Date of Lodging. - ......................................................................................................................................................... Submit operational 23.1.iL, and Submitted 6/19/02. spedfications designed to 23.0.Lb . minimize non-electronic data collection and transfer within 6 months of Date of Lod. in. Develop/ implement .;........................................... 23.J Procedure developed on 3/19/02 and included as procedure for LOAR data an appendix in the written LDAR program. QA/QC within 90 days of ..Lodginfl_.Date,_............................................................................................................................................................................................................ Establish accountable LDAR 23.K Completed by 12/20/0i. personnel by Date of Lodging. . .................................. Establish tracking program for 23.L adding new pumps and valves to LDAR program within 120 days of Date of This program was established by 4/i 9/02 and is described in the written LOAR program, .. lodginn.... -----+------ Conduct calibration/drift assessments of monitoring instruments at the end of each shift by the Date of ........................................................................................................................................................ Commenced on i2/20/01, ...Lodging ........................................................ : More stringent delay of repair 23.N.ii. Com meneed on 12/20/0i. requirements including drill and tap for valves reading >10,000 ppm by Date of Lodging. '-~-------------------' i9 HFNA-000001735 EPA Inspection Report - Page 1074 of 1969 .aiendar Quarterly Report 1 -4 h Quarter 2017 Ho!lyFrontier Navajo Refining LLC, Artesla and Lovington Refineries --------- Requirements CD Status/Comment Paragraph ---------- ........................ - - Submit written facility-wide 23.0.i.2t I Submitted 05/i 3/2002. LOAR compliance program b 5/19/02. ----------------------------------------+--------+--------------- Submit LOAR report with 23. O,iLc. The monitoring results were incorporated into the MACT Periodic reports. periodic reports submitted pursuant to 40 CFR 63.654 on: 3/15/02, 9/13/02, 3/15/03, 9/i 5/03, 3/15/04, 9/15/04, 3/14/05 (3/15/05 for Lovington), 9/i 3/05 (9/15/05 for Lovington), 3/17/06, 9/13/06 (9/06/06 for Lovington), 3/16/07, 09/14/07, 3/17/08, 9/12/08, 03/16/09, 08/27/09, 03/16/2010, 09/13/2010_, 03/16/2011, 03/09/2012 and 09/06/2012 (09/06/2012 for Lovington), 03/15/2013, 09/16/2013, 02/25/2014 (Artesia), 08/26/2014 (Lovington), 02/26/2015 (Artesia and Lovington), 08/27/2015 (Artesia and Lovington), 02/18/2016 (Artesia and Lovington), 08/29/2016 (Artesia and Lovington), 02/28/2017 (Artesia and Lovington), and 08/29/2017 (Artesia and Lovington). ~---------~--- L .......~1.~ti.?.~...Y.\..F..?E.?.SE.i:!P.~?4: Incorporate CD Requirements into Enfon::eabl~..:P..~.r..~.it~....................... Requirements CD Status/Comment ---- .....Parngrnph Within 180 days of Date of 24.A -----------------------------------------------------~ Applications to revise the NSR permits for the Lodging, submit an Artesia and Lovington refineries were submitted \ application for Federally enforceable NSR permit to II 5/28/02. Permit r. evision issued for Lovington on 10/15/03. Permit revision for Artesia issued incorporate of limits, 12/15/04. standards, or schedules effective on the Date of Lodging. Submit applications within 30 24.B Navajo's understanding is that 'fri6 NOx limits for days of the effective date or : boilers and heaters, which require permit establishment of limits, application filing within 120 days after start-up standards, or schedules under 1T16.D, are not subject to ,I24$. No other pursuant to the CD. limits under Section V have occurred to date. L..L------------~-----'------- Section V, Paragraph 25: Obtaining Construction Permits ..... ------~-~----- r Requirements CD Status/Comment Paragraph -- ---------+------+------------ Utilize best efforts to obtain 25 Requirement Completed, construction permits to implement control projects The 5/28/02 NSR permit revision application for the : required by the_C_D_._ _ _ _~ - - - - - __!2rtesia_refinery represented_the ..instal!ation.of.the..... 20 HFNA-000001736 EPA Inspection Report - Page 1075 of 1969 Calendar Quarterly Reeort -4'h Quarter 2017 HoliyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements ----------------------~~~. CD Status/Comment Paragraph ------------------------------------------------------------------------------------------------------------------------t--------------------- FCCU wet gas scrubber, Navajo submitted an application to NMED on 4/9/03 to install a new crude heater (H-103) at the Lovington refinery. The permit was issued 10/15/03. H-103 began operation in 12/03. Since heater H-103 replaced H-101 (Le., the existing crude heater whlch requires burner retrofit by 12/05 under the CD) and uses NGULNBs, this effectively achieves early implementation of the NOx emission reductions sought by the CD, In order to retrofit heater H-20 with NGULNB by 12/31/05, Navajo submltted a significant revision air permit application to NMED on 04/12/05. Since NMED had not completed the application review, a waiver allowing limited construction activities to begin was granted on 10/i 1/05. Permit 0195-M21, authorizing NGULNB for H-20, was issued by NMED on 11/18/05. An air permit application proposing the installation of NGULNBs in 80-1105 (formerly SG-1101A) and B0-1104 (formerly SG-1 i 018) was submitted to NMED on 12/21/2007. Permit 0273-M? authorizing the NGULNBs in SG-1101A and SG-1101 B was issued by NMED on 05/06/2008. Navajo subsequently decided to replace the mdstlng boilers with new boilers using NGULNBs. Permit I 0273-M7-R1 authorizing the replacement boilers ' was issued by NMED on 10/14/2009. The installation of NGULNB in B0-1105 was completed 06/20/2013. The installation of B0-1104 NGULNB was completed 07/29/2013. ~~~n~;t~~;rt1~::~~;~~~:ri1 ~~j~~o~~ I___________________________________________________________________________________________________________________________ H-600: - - .. Air permit Oi95-M25-R3 authorizing the 051 ~--~~-~-~-:_____________ 3.0 SUMMARY OF ANTICIPATED PROBLEMS IN IMPLEMENTING THE REQUIREMENTS OF SECTION V. None at this time. 21 HFNA-000001737 EPA Inspection Report - Page 1076 of 1969 Calendar Quarterly Regort 1 -4 ti Quarter 2017 HollyFrontier Navajo Refining LlC, Artesia and Lovington Refineries 4J) SUMMARY OF EMISSIONS DATA @ The Boiler B-7 initial performance stack test and CEfV1S RATA was conducted on 12/18/2002 and the results submitted to the NMED on Oi/31/2003. @ The Boiler B-8 initial performance stack test and CEfV1S RATA was conducted on i 0/29/2003 and the results submitted to the NMED on 12/08/2003. @ The Heater H-601 initial performance stack test was conducted on 03/02/2004 and the results were submitted to the NfV1ED on 05/14/2004. @ The Heater H-103 (replacement for H-101) initial performance stack test was conducted on 03/04/2004 and the results were submitted to the NMED on 05/14/2004. @ Data was collected for reporting pursuant to Paragraph 11 (e.g., FCCU NOx optimization and demonstration period data.) NOx Additive Demonstration Period report with proposed NOx concentration-based limits submitted 07/27/2006. @ The FGCU Regenerator Scrubber GEMS RATA was conducted on February i 4 and i 5, 2006 and the results were submitted to the NMED on 03/i 5/2006. * The FGCU Regenerator Scrubber annual PM test was conducted on 02/15/2006 and the results were submitted to the NMED on 03/15/2006< * Heater H-20 was retrofit with NGULNBs in December 2005. A peiformance stack test was conducted on 02/16/2006 and the results were submitted to the NMED on 03/23/2006. * Heaters H-352, H-353, and H-354 (formerly identified as 70-Hi/H2/H3) were retrofit with NGULNBs in June 2006. A performance stack test was conducted on 07/11/2006 and the results were submitted to the NMED on 08/15/2006. @ The Boller B-7and Boiler B-8 annual GEMS RATAs were conducted on 09/26/2006 and the results submitted to the NMED on 10/17/2006. * The FCCU Regenerator Scrubber GEMS RATA was conducted on 01/24/2007 and the results were submitted to the NMED on 02/22/2007. @ The FCCU Regenerator Scrubber annual PM test was conducted on 01/24/2007 and the results were submitted to the NMED on 02/22/2007. @ The Heater H-20 annual pe1iormance stack test was conducted on 01/25/2007 and the results were submitted to the NMED on 02/22/2007. The Boiler B-7and Boiler B-8 annual CEMS RATAs were conducted on 09/13/2007 and 09/12/2007 respectively, and the results submitted to the NMED on i0/1 i/2007. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/22/2008 and the results were submitted to the NMED on 02/18/2008. * The FCCU Regenerator Scrubber annual PM test was conducted on 01/22/2008 and the results were submitted to the NMED on 02/18/2008, @ The Heater H-20 annual performance stack test was conducted on 01/23/2008 and the results were submitted to the NMED on 02/i 8/2008. @ The Boiler B-7and Boiler B-8 annual CEMS RATAs were conducted on 09/09/2008 and the results submitted to the NMED on 10/09/200!3- $ The FCCU Regenerator Scrubber GEMS RATA was conducted on 03/03/2009 and the results were submitted to the NMED on 03/30/2009. @ The FCCU Regenerator Scrubber annual PM test was conducted on 03/03/2009 and the results were submitted to the NMED on 03/30/2009, Heater H-600 was retrofit with NGULNBs in 02/2009. The Heater H-600 initial performance stack test was conducted on 03/04/2009 and the results were submitted to the NMED on 03/30/2009, 22 HFNA-000001738 EPA Inspection Report - Page 1077 of 1969 Calendar Quarterly Report _4th Quarter 2017 Ho!lyFrontier Navajo Refining LLC, Artesia and Lovington Refineries @ The Heater H-20 annual performance stack test was conducted on 03/05/2009 and the results were submitted to the NMED on 03/30/2009. @ After adding additional burners, the Heater H-103 (replacement for H-101) performance stack test and NOx CEMS RATA was conducted on 05/21/2009 and the results were submitted to the NMED on 06/22/2009. @ The Boller B-?and Boiler B-8 annual CEMS RATAs were conducted on 09/17/2009 and the results submitted to the NMED on 10/14/2009. 1111 The B0-1105 (replacement boiler for Lovington boiler BSG-110iA) initial performance testing was conducted 01/26/2010 and the report submitted to NMED on 02/24/2010. 1111 The B0-1 i 04 (replacement boiler for Lovington boiler BSG-1101 B) initial performance testing was conducted 01/28/2010 and the report submitted to NMED on 02/24/2010. 1111 The FCCU Regenerator Scrubber CEMS RATA was conducted on 03/02 and 03/2010 and the results were submitted to the NMED on 04/05/2010, e The FCCU Regenerator Scrubber annual PM test was conducted on 03/02 and 03/2010 and the results were submitted to the NMED on 04/05/2010, e The Heater H-20 annual performance stack test was conducted on 03/04/2010 and the results were submitted to the NMED on 04/05/2010. @ The Heater H-103 (replacement for H-101) NOx CEMS RATA was conducted on 05/19/2010 and 05/20/2010, and the results were submitted to the NMED on 06/16/2010. @ The Boiler B-7and Boiler B-8 annual CEMS RATAs were conducted on 08/24/2010 and the results submitted to the NMED on 09/14/2010, @ The FCCU Regenerator Scrubber CEMS RATA was conducted on 03/01/201 i and the results were submitted to the NMED on 03/28/2011, @ The FCCU Regenerator Scrubber annual PM test was conducted on 03/01/2011 and the results were submitted to the NMED on 03/28/2011. @ The Heater H-20 annual performance stack test was conducted on 03/02/2011 and the results were submitted to the NMED on 03/28/2011, @ The Boiler 8-7and Boiler B-8 annual CEMS RATA's were conducted on 08/16/2011 and the results submitted to the NMED on 09/16/201 i. @ The Heater H-103 (replacement for H-101) NOx CEMS RATA was conducted on 05/3/2011 and the results were submitted to the NMED on 05/31/2011, 1111 The Heater H-20 annual performance stack test was conducted 011 01/19/2012 and the results were submitted to the NMED on 02/27/2012. 1111 The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/17/2012. Report showing certification submitted to NMED on 02/17/2012. e The FCCU Regenerator Scrubber annual PM test was conducted on Oi/17/2012, Report showing crniification submitted to NMED on 02/17/2012, e The Heater H-i03 (replacement for H-i01) NOx GEMS RATA was conducted on 05/24/2012, and the results were submitted to the NMED on 06/20/2012, @ The Boller B-7and Boiler 8-8 annual CEMS RATA's were conducted on 08/15/2012 and the results subrnitted to the NMED on 09/13/2012, @ The Heater H-20 annual performance stack test was conducted on 01/09/2013 and the results were submitted to the NMED on 02/07/2013, @ The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/08/2013. Report showing certification submitted to NMED on 02/07/2013, @ The FCCU Regenerator Scrubber annual PM test was conducted on 01/08/2013. Report showing certification submitted to NMED on 02/07/2013. @ The Heater H-103 (replacement for H-101) NOx and CO CEMS RATA was conducted on 05/14/2013, and the results were submitted to the NMED 011 06/10/2013. 23 HFNA-000001739 EPA Inspection Report - Page 1078 of 1969 Calendar Quarterly Report _4th Quarter 2017 Ho!lyFrontier Navajo Refining LLC, Artesia and Lovington Refineries The FCCU Regenerator Scrubber annual PM was retested on 03/05/2013. Report showing certification submitted to NMED on 04/0i/20i3. The Boiler B-7annual GEMS RATA's was conducted on 08/07/2013 and the results submitted to the NMED on 09/17/2013. The Boiler B-8 annual CEMS RATA's was conducted on 08/06/2013 and the results submitted to the NMED on 09/17/2013. The Heater H-20 annual petformance stack test was conducted on 01/09/2044 and the results were submitted to the NMED on 02/04/2014, The FCCU Regenerator Scrubber annual PM was tested on 01/08/2014. Report showing certification submitted to NMED on 02/04/2014. The FCCU Regenerator Scrubber CEMS RATA was conducted on Oi/08/2014. Report showing certification submitted to NMED on 02/04/2014. e After the instaHation of NGULNB was completed, the B0-1105 (replacement boiler for Lovington boiler 8SG-1101A) initial performance testing was conducted 07/12/2013 and the report submitted to NMED on 08/06/2013. e After the 1nstal!ation of NGULNB was completed, the BO-i 104 (replacement boiler for Lovington boiler BSG-11018) 1nitial performance testing was conducted 09/04/2013 and the report submitted to NMED on 12/05/2013. e The Heater H-103 (replacement for H-10i) NOx and CO GEMS RATA was conducted on 05/13/2014, and the results were submitted to the NMED on 06/12/2014. * The Boiler B-7annual CEMS RATA's was conducted on 07/30/2014 and the results submitted to the NMED on 09/11/2014. * The Boiler B-8 annual CEMS RATA's was conducted on 07/29/2014 and the results submitted to the NMED on 09/11/2014. @ The Heater H-20 annual performance stack test was conducted on 02/17/2015 and the results were submitted to the NMED on 03/09/2015. @ The FCCU Regenerator Scrubber annual PM was tested on 01/06/2015. Report showing certification submitted to NMED on 02/05/2015. The FGCU Regenerator Scrubber CEMS RATA was conducted on 01/06/2015. Report showing certification submitted to NMED on 02/05/2015. The Heater H-103 (replacement for H-101) NOx and CO CEMS RATA was conducted on 05/06/2015, and the results were submitted to the NMED on 06/04/2015. The Boiler 8-7 annual CEMS RATA's was conducted on 07/23/2015 and the results submitted to the NMED on 08/20/2015. The Boiler 8-8 annual CEMS RATA's was conducted on 07/22/2015 and the results submitted to the NMED on 08/20/2015. The Heater H-20 annual performance stack test was conducted on 01/07/2016 and the results were submitted to the NMED on 02/05/2016. e The FCCU Regenerator Scrubber annual PM was tested on 01/05/2016, Report showing certification submitted to NMED on 02/04/2016, e The FCCU Regenerator Scrubber GEMS RATA was conducted on 01/05/2016. Report showing certiflcatlon subrnitted to NMED on 02/04/2016. * The Heater H-103 (replacement for H-101) NOx and CO CEMS RATA was conducted on 05/04/2016, and the results were submitted to the NMED on 06/03/2016. @ The Boiler B-7 annual CEMS RATA's was conducted on 07/13/2016 and the results submitted to the NMED on 08/05/2016. The Boller 8-8 annual GEMS RATA's was conducted on 07/13/2016 and the results submitted to the NMED on 08/05/2016, The Heater H-20 annual performance stack test was conducted on 01/05/2017 and the results were submitted to the NMED on 02/03/2017. 24 HFNA-000001740 EPA Inspection Report - Page 1079 of 1969 Calendar Quarterly Reeort _4th Quarter 2017 HoliyFrontier Navajo Refining LLC, Artesia and Lovington Refineries "' The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/03/2017. Report showing certification submitted to NMED on 02/03/2017 "' The FCCU Regenerator Scrubber annual PM was conducted on 01/03/2017, Report showing certification submitted to NMED on 02/04/2017. The Boiler B-7 annual CEMS RATA's was conducted on 06/21/2017 and the results submitted to the NMED on 06/20/2017 The Boiler B-8 annual CEMS RATA's was conducted on 06/21/2017 and the results submitted to the NMED on 06/20/2017, The Heater H-103 (replacement for H-101} NOx and CO CEMS RATA was conducted on 04/25/2017, and the results were submitted to the NMED on 05/16/2017, Consistent with past reports, any emissions excursions from Consent Decree llmits have generally been reported to NMED pursuant to the NSPS, MACT and/or Title V programs semiannually (as well as pursuant to NMED's excess emissions reporting program} We are in this report identifying emissions excursions that occurred in the 4th quarter 2017 for the emission limits and units below. For the flares at Artesia and Lovington, excess emission information for events occurring during the semiannual period: July-December 2017 will be reported in the semiannual NSPS Ja monitoring report due on January 30, 2018, and will be attached to the 1st quarter 20i 8 Consent Decree Progress ReporL Consent Decree Condition V.13.B FCCU PM Emission Umits 1 lb PM/ 1,000 lb Coke Bum 3-hr average ------------------------- . Maximum recorded 3-hour Start Time End Tirne average (lb PM/ '1,000 lb Coke f-.--------------- Bum) 20'17-1 i-i i '19:00 2017-11-12 06:00 7,54 ~---+--------~--------- 2017-11-24 10:00 20'17-11-25 04:00 6BJ4 Consent Decree Condition V.14.B FCCU CO Emission Limits CO 500 ppm 1-llr average 'e":',ta,,,.. r1rne ,,._.,.,..,.nd i--irn""' Excess Emissions per Event f--------- ..........(lbs) ... 2017-11-ii '18:00 2017-11-12 06:00 3,584.31 f---_2_-0_17_-i_i_-2_.8_07_:0_0_ _2017.1.128.08:00............1.................................. 0.68 2017-12-28 18:00 2017.12-29 20:00 56.48 Consent Decree Condit.ion V.18. B: SRU S02 Emission Hmits SRU-2 SOZ 250 ppm 12hr average - 1 I Start Time End Time Excess Emissions per Event lbs ----------+-----..,__..,___ _ __ 2017-10-07 13:00 20171008 08:()0 186.19 25 HFNA-000001741 EPA Inspection Report - Page 1080 of 1969 Calendar Quarterlx:; Report-4th Quarter 2017 HoiiyFrontier Navajo Refining LLC, Artesia and Lovington Refineries 5. Implementation of ENVIRONMENTAllY beneficial Projects [Changes from Prior Quarter Italicfzed] Paragraph 35 requires certain information to be submitted for each project which has been completed, The projects for Paragraphs 30 and 32 have been completed, The foHowing summarizes the status of the completed and ongoing projects, and highlights actions taken thus far: E ~ i r ~ ~ ~ : . , " ; , . ~ i y " : ~ ~ : ' ~ = 29: 1 _Re~~ery-wide Compliance ~=t~:i~~!~~r:;rt Q Q Q ] L____ Pro~rj_,e_c_ t _ _ _-----+_P_a_r_agrnph _____ ----------------------------------------------------------------! I Submit Compliance Pian 29.A The plan was submitted on I I within 180 days of CD Date of May 29, 2002 i I Lodging. -----+------------------------------------------ ' NSPS QQQ becomes 2flB Prior to 12/31 /03, Navajo began operation of the applicable to Artesia and new covered wastewater separator, completed the Lovington individual drain bypass of the South Plant AP!, installed covers on systems, oil-water separators, Junction boxes and initiated drain inspections for and aggregate facilities by the Artesia refinery. Junction boxes at the 12/31/03 Lovington refinery were also covered and the routine inspection of drains (to assure proper water sea!) was begun, Navajo otherwise ceased the use of an open culvert for draining oily process wastewater into the sewer. !nearly September 2010, it was discovered that the storm water catch basin of the A!kylation Unit Tar Pit could still receive some oily-water and therefore could be considered as a junction box, A cover for the storm water basin was designed, constructed, and installed by 11/12/2010, !n July 2014, it was discovered that visual inspections were not conducted initially and semiannually as required by 40CFR 60.692-2 (07/11/2014 self-disclosure letter to NMED, Certified Receipt Number: 70073020000030288246). A recent third party review of the QQQ program indicated that there may be a potential issue regarding certain aspects of the drain systems at the refinery. This is currently under further evaluation, 26 HFNA-000001742 EPA Inspection Report - Page 1081 of 1969 HoHyFrontier Navajo Refining LLC, Artesia and Lovington Refineries EL Section V, Paragraph 30: Operation of the 40 LTPD SRU {SRU1} on Standby Artesia SRP (No SRU at Lovington): -----"- - - - - - ......................................................................... ,........................................................................................................................................... Environmentally Beneficial CD Status/Comment _ _ _ _P_ro~j_ec__ t _ _ _-+-Paragraph..... ,......................................................................................................................................................................... Complete installation of 30 i SRU1 was started up again on 5/10/03 operating at equiprnent on SRU 1 to allow I a reduced rate in backup service. operation in standby service A new i 00 long ton per day sulfur recovery unit by 12/31/03 (SRU3) began operating 05/11/2009, The combined capadty of SRU2 and SRU3 provides excess sulfur recovery capacity. Therefore, as an energy and emissions conservation measure, SRU1 is no ion er operatqci in standby sery_ig~.:.................. Complete study plan on how 30 Acid Gas Flaring and TGU Excess Emissions to limit excess TGLJ Study Pian submitted 2/27/04. Pursuant to the emissions and Acid Gas plan, Navajo completed the study and submitted a Flaring by 2/28/04 3/24/05 summary of the study including actions taken and recommendations. The study results were used to update the PMO plan with the modified PMO plan included with the 3/24/05 submittal. C, Section V, Paragraph 31: !nstaiiation of Spare FCCU Wet Gas Compressor .........................Artesia..FCCU.(No __FCCUJ:lt.Lovington): Environmentally Beneficial CD ................................................................................... Status/Comment Project Paragraph ----------- ------------------------------- Complete installation of spare 31 A spare wet gas compressor was installed during wet gas compressor by the 4th Quarter of 2003 FCCU turnaround. 12/31 /03. Operate so as to On 01 /07/201 '1, Navajo's outside legal counsel minimize the duration of AG submitted a request to modify or remove this or HC flaring incidents during paragraph, Operating procedures to minimize the outages of the original duration of AG flaring were updated 04/30/2015. compressor. A preventive maintenance plan for the spare compressor C-0950 was completed on 05/11/2015. 1..................................................................................................... 27 HFNA-000001743 EPA Inspection Report - Page 1082 of 1969 falendar,,Oqg[):er!y Report _4th Quarter 2017 HollyFrontier Navajo Refining L.lC, Artesia and Lovington Refineries CL Section V, Paragraph 32: Supplemental Environmental Project (SEP) Benefiting the ________Artesia__Com_m__u_n_i~ty~--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- ----------------------------------- Environmentally Beneficial CD Status/Comment Project Paragraph _..,______________ Complete implementation of 32 Navajo completed the community SEP prior to the SEP to benefit the Artesia revised 9/29/03 deadline and submitted cost community by June 30, 2003 -certification data on 9/23/03 pursuant to Paragraph 9i. The SEP installed mechanical mixers to replace air mixers on nine asphalt storage tanks to reduce odors. The tanks were T-0110, T-0404, T-0405, T- 0406, T-0409, T-0410, T-0428, T-0431, and T- 0432. T-0404, T-0405, T-0406, and T-0409, and T-0428 ~-----------------------'--""'------------------------------------------------have_been __permanent!y __removed __from__ se_rv_ic_e_._--------' E Section V, Paragraph 33:____EMS_Base!_ine_Assessment__for_Artesia___Refinery ____ Environmentally Beneficial CD ' Status/Comment Project Paragraph - --- Obtain NMED approval for 33.C ~---------------------------------------------- Completed via letter from NMED dated 4/19/02. Independent Contractor to perform the baseline assessment Execute contract with -------+------.-------------------------------------------------------------------------------------------------------------------------------------------------------------------33.D Completed as of 4/15/02 ___!ndependent__Contractor -+----------,...------------------------------------------------------------------------------------------------------------------------------------------------------------ Baseline Assessment Report 33.E I Navajo received the baseline assessment report on \ to be received by Navajo 1 7/17/02. within 2i Odays of Date of Lodging Navajo to implement I i 33_F Navajo has accepted the recommendations and . recormnendatlons in schedule deadlines provided in the baseline report accordance with the baseline (the 8 recommendations are numbered in report schedule parenthesis in the discussion below). For the two (i.e., 1A and 5) recommendations with 10/1/02 deadlines, Navajo implemented both on time (i.e., prior to the deadline). The report to file requked by . CD 1[33.F.H was completed 12/27/02. l---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- 28 HFNA-000001744 EPA Inspection Report - Page 1083 of 1969 Calendar Quarterly Report _4th Quarter 2017 Ho!lyFrontier Navajo Refining LLC, Artesia and Lovington Refineries ----~-- ---------------------------------------- Environmentally Beneficial CD Status/Comment Project Paragraph r--------------f...--- --------------------------------------------------------c--c---c---cc----cc-c--~----- Navajo to implement 33.F Navajo did the roll-out of the refinery environmental recommendations in policy (1 B) and put environmental responsibilities accordance with the baseline (3) into a new specifically developed operator's report schedule manual prior to the baseline report - Cont'd recommendation deadline (i.e., 2/i/03 and 3/1/03, respectively). ---------- Navajo to implement recommendations in accordance with the baseline report schedule -Cont'd - - - + - - - - - - - - - - - - - - - - -------------------------------- 33.F The position descriptions (6) which were recommended for Navajo's Environmental Affairs Department staff were prepared and distributed prior to the 7/1/03 deadline. An independent consultant performed an on-site evaluation of Navajo's implementation of the recommendations and prepared a 6/23/03 evaluation report prior to the 6/30/03 deadline. ------<----- --------- --------------------- Navajo to implement 33. F Per the independent consultant's June 2003 recommendations in evaluation report, the 9/1/03 original deadline for accordance with the basel!ne the recommended CBT training module (2) was report schedule revised to 3/1/04. - Cont'd f - - - - - - - - - - - - - -------------------------------- Navajo to implement Work commenced in November 2003 on recommendations in developing the CBT training module (2). The CBT accordance with the baseline module was completed and rolled out on 2/27/04, report schedule thus meeting the 3/1/04 deadline. The decision -Cont'd was made to implement (7) via the electronic option (6/1/04 deadline). Recommendation No. 8A, "Develop Environmental Records Retention Policy and Document Control Procedures"' was implemented prior to the 12/1/03 deadline. Navajo to implement recommendations in 33.F Completed the evaluation of the LOAR program, process and procedures (4) on 6/3/04 and accordance with the basel!ne determined that the program is working as report schedule -Cont'd intended. Integrated compliance requirements calendar (7) was implemented prior to the 6/1/04 deadline, Completed work to implement the environmental records management system (SB) during May 2004 with the aid of an outside consultant. The records management system is in place and working, An independent consultant conducted the implementation evaluation presented in a June 30, 2004 report, thus meeting the deadline. A final closure letter on the EMS improvement recommendations was issued September 30, 2004 by the consultant concluding no remaining EMS improvement actions for Navajo. _ _ _. . . J . __ _ _ _ _ _ _ _ _ _ _ --------- ------------------------------------------------------------- 29 HFNA-000001745 EPA Inspection Report - Page 1084 of 1969 Calendar Quarterly Reeort 1 -4 h Quarter 2017 HoilyFrontier Navajo Refining LLC, Artesia and Lovington Refineries 6Jl OTHER MATTERS The recent implementation of flare monitoring requirements under NSPS Ja resulted in the identification and repair of several relief valves that were leaking to the flare. In addition, three flare gas streams with higher sulfur levels were identified as routed to the Lovington flare. These three streams were rerouted to the fuel gas system. As of November 11, 2015, all gas streams currently routed to the flares are being monitored for compliance with the NSPS Ja requirements. Excess emission information for the flares at Artesia and Lovington for the semiannual period: January-June 2016 was included in Attachment 4 to the 3'0 quarter 2016 Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: July-December 2016 was included in the semiannual NSPS monitoring report submitted on January 30, 2017, and was attached to the 1st quarter 2017 Consent Decree Progress Report. Excess emission information for events occurring during the sernlannual period: January-June 2017 was reported in the semiannual NSPS Ja monitoring report submitted on July 28, 2017, and was attached to the 310 quarter Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: July-December 2017 wrn be included in the semiannual NSPS monitoring report due on January 30, 2018, and will be attached to the 1"1 quarter 2018 Consent Decree Progress Report Pursuant to CD Paragraph 20A.viH, Navajo is submitting a follow-up for those corrective actions that were identified in the following Hydrocarbon Fladng and Tail Gas Incident Reports and that have since been completed, ,--------------.,------------------------------------------------------ Incident Ending r HCI/ TGI Corrective Actions Identified in Status/Comment HCI/TGI Reports e-----------------i----------------1---------------------------------------------------------------------------------------------------......___...._......--......_.._i___________.........._..________ 07/27/201(3 HCI i. Establish Tower top minimum Items 1 and 2 were temp to drive salt and dew point out completed on 06/29/2017 of tower, Establish dynamic dew and 12/15/2016, point calculator on DCS for low respectively and were alarm. Set tower top temp LL at 350 previously reported. Item F until then. 2, Monitor and report 4 completed on salt point and dew point on monthly 01/23/2017. Item 5 was unit report and ensure top temp is completed on 08/29/2017. above salt and dew point 3. The completion of items 3 Evaluate oil/water separation in D- and 6 ls scheduled for 3405 and D-3411. 4. Create 07/22/2018. inspection plan for stripper tower to monitor if corrosion is occurring. 5. Evaluate need for inspection of the lower at next cat change. 6. Complete comparison with sister units. 30 HFNA-000001746 EPA Inspection Report - Page 1085 of 1969 08/25/2046 ..... Hci" ............ i . Create Matrix to provide guidance on conserving H2, BFW, and steam. 2. Identify potential capita! improvements to steam system. 3. Install governor to better control P-831 speed. i Corrective act\"onsfZ:ncf"2 were completed on 12/21/2017. !t~rn 3 was completed during the last unit turnaround, on 03/34/2017. 31 HFNA-000001747 EPA Inspection Report - Page 1086 of 1969 ATTACHMENT 1 APPENDIX G SUMMARY REPORTS HFNA-000001748 EPA Inspection Report - Page 1087 of 1969 Ho11yFrontier Navqjo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 4th QCARTER 2017 STAlTS REPORT APPENDIX G STATUS SFMMARY REPORT REPORTS, PLANS AND CERTIFICATIONS UNDER THE BENZENE WASTE NESHAP ENHANCED PROGRAJ\f PROVISIONS OF PARA.GR4.PH 22 OF THE CONSENT DECREE JN UNITED STATES ET AL, V, NAVA,JO REFINING CO. ET AL 1 Name or Summary of the Report Plan, or Certification BWN Compliance Rcvicv,; and Verification Report CD SubPara No, C.L Rqd. ("R") v. Contingent (- ~ " C- -"- /1. One~Time (''l")v. Quarterly or w/ 63.654 Reports ("> l ") R Due Date 270 days after Lodging ! Revicvr completed 09/11/2002. Report submitted 10/0912002 Status Amended B WN Cii. C 1 Compliance Review and Verification Repmi 90 days after completing additional sampling requested by EPA Not Yet Applicable. EPA has not requested additional sampling. Amended TAB Repmi I)j C 60 days after completing B\\lN Compliance Revie,v and Verification Report A.n 1-\mcnded Reporl for the itrtesia Refinery(> 1 Mg, <10 Mg) ,vas Submitted 10/09/2002 with the Verification Report l Flan to comply \VI 6 BQ D.ii; ,(' 1 if Tl\B equals or is J.vi. greater than 10 I "Tl z :r- 0 0 0 0 .0.... -..,J .i:,,. (!) 180 days after completing BVv'N Compliance Review and Verificalion Report Not Applicable unless the .4.rtesia or Lovington Refinery exceeds l OMg/yr in the annual TAB report Pagel of 12 EPA Inspection Report - Page 1088 of 1969 HoHyFrontier Navajo Refining LLC Artesia and Lovin6Ji:on Refineries ATTACHMENT 1 TO 4th QUARTER 2017 STATUS REPORT APPENDIX G STATUS SU1Vf\fARY REPORT Name or Summary of the Report, Plan, or Certification Compliance Ce11ification CD SubPara No. ID.iv !Rqd. One-Time (''R") (''] '') V. v. Cont- Quarterly Due Date ingcn! orw/ ("C") i R63.654 iReports I"> 1" } i ~ ... iC ' 5() days atter completing a11 actions necessary to come into compliance 'vVaste/Slop/Off-Spec Oil IU. R Schematics 90 days aikr Lodging Submit revised H.i. C Waste/Slop/Off-Spec Oil Schematics reflecting agreement 'Nith EPA on comments. Mntna!iy-agreed upon time between Navajo and/or Montana Refining and EPA Status Not Applicable unless the Artesia or Lovington Refinery exceeds 10 Mg/yr in the annual TAB report Submitted on 03/! 9/2002. Revised plan reflecting plant modifications submitted 04/29/2004. Schcrnatics arc mvaiting vnitten approval by EPA. Not Applicable until EPA confors with Navajo on the \VashdSlop/Off-Spcc Oil Schematics. Schedule to complete ltii. C installation of controls on waste management units handling organic benzene \'i./asic ! Plan to quantify Riv. ! R uncontrolled ,vastcislop/off-spec oil movements I "Tl z :r- 0 0 0 0 .0.... -..,J 01 0 Mutually-agreed upon time bchvccn Navajo andior Montana Refining and EPA., not to exceed 2 years 90 days r;ftcr EPl\has approved schematlcs Not Applicable unless the Artesia or Lovington Refinery exceeds 10 ivfg/yr in the annua1TAB report INot Applicable u~til EI;~\ provides wriUcn approval of the Wastc/Slop/C:ff . Spec 011 Schematlcs. Aithough EPA has not commented on or approved the schematics submitted under paragraph 22.1-Li, Navajo has quantified the uncontrolled waste/slop/off.spec oil rnovements in the annual NTSHAP Subpart FF Total /umual Benzene {Ti\B) report. Page 2 of 12 EPA Inspection Report - Page 1089 of 1969 HollyFrnntier Nav11jo Refining LLC Artesia and Lovin&,.ii:on Refineries ATTACHT\'lENT l TO 4th QUARTER 2017 STATUS REPORT APl1'ENDTX G STA'TlTS SUMMARY REPORT Name or Sumrnary of the CD Rqd. Onc~Timt: Renort, ..Plan, qr CertiJkat ion SubPara ("R"') ("1 '') V. v. Cont- Quarkrly ingent or 1vi 63.654 Due Date Status 1 Reports ("> l") +++"' +....,..,....,.....,...,.,...,.,...,.,,.,._,__,__. EOL Sampling Plan Li; C 2 months afrer the EOL Sampling Plan submitted on 02/06/:?00:t J.ii 22.D.iii Certification (if TAB is 10 mg/yr or greater); 90 days after submitting final B\VN Review and Verification Report (if TAB is 1 Mg/yr or more but kss than 10) EOL Revised Sampling LiL C Plan .LiL As needed If and when Naw~jo and/or Montana Refining become aware of factors Revised EOL Sampling Pian submitted 03/31 plan no longer accurately reflects EOL benzene quantity Applicable after refinery Lvii; C As 30 days aikr the (md Not Applicable unless the Artesia or Lovington Refinery exceeds 10 TAB exceeds 10 Mg!yr - needed of the quarter in which in the annual TAB reporL Plan to ensure that the pr~jected calendar I uncontrol)ed benzene "Tl does not equal or exceed, z :r- 6 Mg/yr or that it is 0 0 minimized 0 0 0 ->. --.J 01 ->. year benzene quantity is equal to or greater ; than 6 Mg. I - Page 3 of] 1 EPA Inspection Report - Page 1090 of 1969 HollyFronticr Navajo Refining LLC Artesia and Lovin61:on Refineries ATTACHMENT 1 TO 4th 01JARTER 2017 STATUS REPORT APPENDIX G STATUS SUIVlMARY REPORT Name or Summary of the CD Rqd. One-Time Report, Plan, or Certification Sub.Para No, (''R") (" 1'') V, v. Cont- Quarterly ingen1 Ior ,v/ ("C") ; ~63 .654 Due Date Status Reports C>t') Applicable if refinery TAB is > 1 but< l 0 J.iv- C J.v Mg/yr - Plan to ensure that uncontrolled benzene docs not cqua1or exceed, as applicable, l O Mg./yr or that it is rninimiz.cd As needed 30 days after the end of the quarter in 1,vhich the projected calendar year benzene quantity is equal to or greater than 10 !:Vlg. 1 ' The 2007 4 h quarter EOL benzene quanlity exceeded 2.5 Iv1g, but the calendar year 2007 TAB did NOT exceed JO Mg. Because the calendar year is over, and the 'L\B did not exceed 10 J'vig in the calendar year, submittal of a plan to prevent the calendar year TAB from exceeding 10 Mg, as required under 1[ 22J ,iv, becomes moot As required by 11 22.M.ii.a(3), Navajo specifically soughl EPA\; concmTcnce with this interpretation but no response has been received. The FOL BQ for the 1" quarter of 2003 was <2,5 Mg and the projected 2003 TAB was < 10 Mg/yr so no plan was required. The EOL BQ for the 2"d quarter of 2008 was> 2.5 Mg and the projected tab was > 10 lvlg/yr. The required plan was included as a supplement lo ilie 2nd quarter report Navajo specifkaUy sought EPA's concurrence with this plan but no response has been received, The FOL BQ for the 3rd quarter of 2003 \Vas> 2.5 Mg and the projected tab was> 10 lvig/yr (sec Attachment 3). The required plan was included as a supplement to the 3"' quarter report As required hyT 22JvLii.a(3), Navajo specifically sought EPA's concurrence with this plan but no response has been received. The EOL BQ for the 4th quarter of 2008 was <2.5 ?vig and the prc:jected 2008 TAB was< 10 Mg/yr so no plan was required. The EOL BQs i(X the 1"1, 2"'\ J'd and 4;h quarters of 2009 were <2-5 fv1g and the projected 2009 TAB 1,vas < 10 Mglyr so no plan was required. The EOL BQ for the 1si, 211d, 3", and 4th qua._rters of 2010 was <2.5 Mg and the projected 2010 TAB ,vas < 10 Mg/yT so no plan was required. I The EOL BQ for the 1", 2nd, 3'd and 4ih quarters of 2011 was <2.5 Mg and "Tl z the projected 2010 TAB was< i OMg/yr so no plan is required. :0r- 1"n' e "E'~{.)L B'-'-<'' i.or th. e 'i"', 2''ct, ,_,1,ct and 4' th quarters o f"2fJ 1'L"' was <1'".'..1" 111v~:tg am1 0 0 the projected 2010 TAB was< 10 Mg!yr so no plan is required. 0 0 -..,J --"' Pao0 e 4 of 12 01 N EPA Inspection Report - Page 1091 of 1969 HoHyFrnntier Navajo Refining LLC J\1tesia and Lovington Refineries ATTACHMENT 1 TO 4th QUARTER 2017 STATUS REPORT APPENDIX G STATUS SUMl\iARY REPORT Name or Sumrn.ary of the CD Rqd. One-Time Report P1an, or Certification Sub- ("R") (" l ") V Fara v. Cont- Quarterly Due Date Status No. ingent or \V/ ("C") 63.654 Reports ('"> 1") I.n, e EO L BQ c t. ,or tJJe 1,: , rd 2 , ' 3'' and 'I 4 q u a r t e r s , . o! 2013 were each <2.:~i Mg and the projected 2012 L\B was< 10 Mg/yr so no plan was required. T1 'ne E'()LB. QJ t.,or t.,ne 1,,, and"L'"d quarters OT''"L"t/14 was <2,)--l.V..,1.g anu1 tl1e proj1xtcd 2014 L\B \Vas <_10 MglyT so no p1an 'Nas required. ".l'he CD (..)I. IJ3C',), f'or t1ne i,'',,''K --.lr,s.<1 d, anu..:14ln quarters oi""L"O14 \vere <.;,.,<_..:,;N,,1f.g anc] the projected 2014 TA..B was < 10 Mgiyr so no plan 1Nas required. The EOL BQ fr1r the rstquarter of 20I5 v,as <2.51\.-ig and the projected 2015 TAB was< 10 Mg/yr so no plan was required. The EOL BQ fr)r the 2"'; quarter of 2015 s:vas <2.5 Mg and the projected 2015 L\B was< 10 Mg/yr so no plan was required. The FOL BQ for the 2nd quarter of 2015 was <2.5 Mg and tbe projected 2015 TAB was< 10 tvig/yr so no plan ,vas required. The EOL BQ for the 3rd quarter of 2015 was <2.5 :tvig and the projected 2015 TAB ,.vas < i OMg/yr so no plan \Vas required. The EOL BQ for the 4th quarter of 2015 was <2.5 Mg and the projected 2015 TA.B was< 10 Mg/yr so no plan was required. The EOL BQ for tbe 1st quarter of 2016 was <2.5 Mg and the pn..'.iected 2016 TAB was < 10 1vigl}T so no plan was required. The EOL BQ for the 2nd quarter of 2016 was <2.5 Mg and the projected 2016 TAB was< 10 Ivig/yr so no plan was required. The EOL BQ for the 3rd quarter of 2016 exceeded 2.5 }-/l.g bu1 the calendar year 2016 TAB did NOT exceed 10 }'v:i g. As the first two quarters of 2016 indicated significa.:.'1tly lower concentrations of benzene in the wastewater, I the projected TAB remained below 10 lvig f(X the calendar year, and as "Tl z such no specific actions need to be taken to ensure the T.AB docs not exceed :r- I0Mg. Regardless of that, however, Navajo developed a plan of targeted 0 0 monitoring to help identi(y and address the benzene contributions during 0 0 0 the thirdquarter. The plan was jmplf:mf:12t~fl_by N_o_vemh~t, 2016 ..... -..,J Page 5 of 12 01 (,) EPA Inspection Report - Page 1092 of 1969 HoHyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHlVlENT 1 TO 4th QUARTER 2017 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or Certification CD SubPara No. Rqd. ("R") v. Contingent ("C") One-Time ("l'') V. Qum1erly orw/ 63.654 Reports ("> J") ' i Due Date Status I (aHaduncnt 4). The EOL BQ for the 4th quarter of 2016 was <2.5 Mg and lhc projected TAB for 2016 was <10 Mg/yr. The EOL BQ fr,r the 1st quarlcr of 2017 was <2.5 Mg and the projected TAB for 20 l 7 was < 10 Mgiyr. The EOL BQ for the 2nd quarter of 2017 was <2.5 h'Ig and the projected TAB fr)r 2017 was <!O Ivig!yr. The EOL BQ fr.1r the 3rd quarter of 2017 was <2.5 f;1Ig and the prc:iected TAB i()f 2017 was <10 rvfg/yr. The EOL BQ for the 4th quai1er of 20 I7 vms <2.5 :Mg and the projected TAB for 2017 was <10 J\1g/yr, ! I "Tl z :r- 0 0 0 0 .0.... --.J Page 6 of 12 01 .i:,,. EPA Inspection Report - Page 1093 of 1969 HoUyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHlV[ENT 1 TO 4th QUARTER 2017 STATUS REPORT APPENDIX G STATUS SU1VflVIARY REPORT Name or Summary of the Repori, Plan, or Certification CD SubPara No. Rqd. ("R") v. Contingent ("C') One-Time (" l ") V. Quarteriy or w/ 63 .654 Reports (''> 1_") Due.Date Status Proposal for Third-Party TAB Study and Compliance Review 1-viii; I C J.vi Third-Party TAB Study I- C and Compliance Review v1u; J.vi Last day of 4' Quarter Not i\.pplicablc unless refinery cannot take actions to keep TAB be!mv l 0 as Mg./yr, set forth in ~[ I. viiL (if TAB is IO mg/yr or greater); As agreed hy EPA and Navajo and./or Montana Refining (if TAB is 1 Mgiyr or more but less than 10) 30 -~~y_s after receipt of INo_-_:_ Applicable unless refinery cannot take actions to keep TAG belmv l 0 the Third-Party Study Mg/yr. and Compliance Revinv Plan to implement the I J.vi; C l results ofthe Third-Party TAB Study and Cornpliance Revie\v 120 days after receipt of the Third-Party T./\B Study and ! Compliance Review l Not Applicabk unless refiriery cannot take actions to keep TAG beknv 10 rvlgiyr. I "Tl z :r- 0 0 0 0 .0.... --.J Page 7 of 12 01 01 EPA Inspection Report - Page 1094 of 1969 HolJyFrontier Navajo Refining LLC Artesia and Lovington Refineries A1"fAC[IIV[ENT 1 TO 4th QUARTER 2017 S1'ATLS REPORT APPENDIX G STATUS SFMMARY REPORT Name or Summary of the Reporc Plan, or Certification I CD I Sub~ Pam No. Report on training done CU- in that Quarter iii.; Mii- a(l) Rqd. One-Time ("R'.) (" !'') V, v. Cont-! Quarterly ingcnt or w/ C'C~'J 63.654 Rcporls ('>l'J C Q Due Date Each Quarterly Report due under the Consent Decree Status A training plan -,vas developed 12/6/02 for the Artesia Refinery (i.e., since its TAB is greater than 1.0 rvfg/yr). The first training session was held l/7/03 at both the Artesia and Lovington refineries. The second training session for the two refineries was held l/27i04 and 1/28/04. A.1111ual refresher training perfrlrmed the weeks of 2/8/05, 3127/06, 3/5/07, 2125108 (Lov), 11/07/08 (Art), 12/18/09, 12/17/2010 and 12/20/2011, 11/08/2012, 01i14/2013, 04/18/2013 11/12 to 11/14/2013, 05/24/2014, 06/19/2014, 06/20/2014, 12/02/2014, 3/16/2015, 4/1/2015, 5/15/2015, 2/29/2016, 3/812016, 3/17/2016 (Art and Lov), 02/2812017 (Artesia and Lovington) and 08/29/20! 7 (Artesia and Lovington), I "Tl z :r- 0 0 0 0 .0.... -..,J Page 8 of 12 01 0) EPA Inspection Report - Page 1095 of 1969 HollyFrontier Nav:rjo Refining LLC Artesia and Lovin&:>ton Refineries ATTACH1VIENT 1 TO 4th QCARfER 2017 S1ATUS REPORT APPENDIX G STATUS SCMlV[ARY REPORT Resu1ts of annual I J.i; C () sampling of >0<05 Mg/yr Mii- benzene streams a(2) I "Tl z :r- 0 0 0 0 .0.... -..,J 01 -..,J In the first Quarterly Report for the first calendar quarter of eachyem The annual sampling was performed in February 2005. The results were presented \vith the first quarter 2005 report Annual sampling was performed in February 2006. The results were presented in Attachment 4 \Vith the first quarter 2006 report i\.nmwl sampling was performed in September and December 2007, The resu1ts were submitted in attachment 4 of the first quarter 2008 report as required by 1i22.1vLii.a(2)< Annual sampling was perforrned in December 2008. The results were submitted in attachment 4 of the first quarter 2009 report as required by 122.M. ii.a(2). Annual sampling was perfon11ed in December 2009< The results were submitted in Attachment 4 of the first quarter 2010 report as required by t'i2i -".>c.l"Y"1' . 10 1' . '( h ';;), ) < Annual samp1ing was performed in Decernher 2010. The results \Vere submitted in Attachrnent 4 of the first quarter 2011 report as required by 922.M.ii.a(2). iumual sampling v:as perfrnmed in December 2011. The results were submitted in Attachment 4 of the first quarter 2012 report as required by Ii.'.:Y:..,,);.. ":\-!;1f ; ~ i c,/1 .~... ,.;.... ) ~ Annual sampling was performed in December 2012< The results were submitted in Attachment 4 of the first qumter 2013 report as required by 92LM.iia(2). Annual sampling was performed in December 2013. The results were subrnitted in Attachment 4 of the first quarter 2014 report as required 1Oy; ~11?"?"~-JrY-1.l,.Lt' (~)}\- Annual sampling was perfonned in December 2014. The results were submitted in Attachment 4 of the l 5'quarter 2015 report as required by ~)') r,, 1 '' , '')\ , ll""'"''JY <1Ld\"'} I Page 9 of 12 EPA Inspection Report - Page 1096 of 1969 Hollyfrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHlV[ENT 1 TO 4th OUA.RTKR 2017 STATUS REPORT APPENDIX G STA'l'US SlJMlViARY REPORT Results of annual J.i; C Q sampling of >0.05 Mg.!yr Mii- benzene streams a(2) I ''' ' In the first Ouarterlv Report for the first calendar quarter of each year 1 ! Annual sampling \Vas performed in December 2015, The results \Vere included in Attachment 4 of the 1'\1uarter 2016 report as required by 422JvULa(2), Annual sampling was perfonned in October 20! 6, The results \Vere included in Altachn1ent 4 of the 1st quarter 2017 report as required by T22JvLii .a{2), Annual sampling was perfrm11ed in December 2017. The results \VU! be included in Attachment 4 of the 1st quarter 2018 report as required t1y-9p,:;-,,i,,ML' ,l"L U(.'L1) . Results of Quarterly EOL J.iii: C Q Sampling iVUL a(3); Mji~ b{2) Each Quarterly Report due under the Consent Decree (after written EPA approval ofEOL sampling plan) 2004: Under the assumption that the sampling plan \Vas accepted by EPA upon the 03/31/2004 submittal of the revised EOL Sampling Plan, Navajo conducted its first EOL sampling during the 1,,veek of 3/22/04, The anmm1 TAB, submitted 4/05 was 4,9 Mg for Artesia and 15 ?vig for Lovington, 1 2005: The FOL benzene quanti;,, (BQ) for the 1"\ 2"'1, J"\ and 4 b q~mrter of 2005 1,,vere each -<2.5 Mg. 200. 6: Th, e E\O.I , B. Q .for t11e I'', 2"d, .yc1, and 4'1, quarters of ,";,l()()(, were each <2.5 Mg. ",.007 Th-i;; 1't, Lesml, a' nd _,.,,,d tl,B, rter 200.. 7 E-,0.1 , B_Q. s were eacl1 ~-.. "' ' 5 1M'. g. Tl1e 2007 1 4" quarter EOL benzene quantity exceeded 2.5 Mg, but the cakndar year 2007 TAB did NOT exceed 10 iv1g. 2008: The EOL BQ for the 1st quarter of 2008 was <2.5 Mg and the projected 2008 TAB was < l OlV[g/yr. The EOL BQ for the 2"d quarter of 2008 was> 2,5 Mg and the projected tab was> 10 T:Vfg/yr. TI1e EOL BQ for ' the 3"' quarter of 2008 was> 2.5 Mg and the projected t.ab was> 10 Mg/yr. ' ' The FOL BQ for the 4th quarter of 2008 ,vas <2.5 Mg and the projecte<l 2008 ' II Tlill was < 10 MgiyL 2009: The EOL BQ for the 1"1, 2'"1, 3"5and 4'h quarters of 2009 were <2,5 I I "Tl z :r- 0 0 0 0 .0..... -..,J 01 OJ Mg and the projected 2009 'LAB was< 10 Mg/yr so no plan was required. 2010: The EOL BQ for the 1'', 2nd, 3', and 4th quarters of 2010 was <2.5 :fvig and the projected 2010 TAB was< l OMg/yr so no pfan was required. 2011: The EOL BQ for the 1'',2nd, 3rd and 4th quarters of 2011 was <25 : Mg and the projected 20 l OTAB was < l OMg/yr so no plan is required. Page 10 of 12 EPA Inspection Report - Page 1097 of 1969 HoUyFrontier Nav"t\jo Refining LLC Artesia and Lovington Refineries ATTAC'HIV[ENT 1 TO 4th QUARTER 2017 STATUS REPORT APPENDIX G STATUS SU1VINIARY REPORT i :r-I "Tl z 1 0 0 0 0 !.............................................................................. 0 ...... -..,J 01 (!) 2012: The EOL BQ for the l '', 2"d, 3rd and 4th quarters of 2012 was <2.5 Mg and the projected 2012 TAB vvas < 10 Mg/yr so no plan is required. J-t<u'<.iJ,, Td' e~ Lr:,')L' .DoQ, i"or .t1i.1.c.' 1~st, -')nd, 1.,"'.,Lr, lj 4'h q. uark."rs 0.1r. -".J?f;l3,,\.a, :,.,., <.".:,":.; }n.,1.6,, and the projected 2012 TAB was< 10 rv1g/yr so no plan is required. , ~ .~,-.. <.::t.pd r?, .th 1...., '"' 2014: The EOL BQ 1:or the 1 , 2 , 3~ and 4 quarters or 2014 were <2.) .\Jg and the projected 2014 TAB was< IO Mg/yr so no plan was required. 2015: The EOL BQ for the l st quarter of 2015 was <2.5 Mg and the projected 20 i 5 TAB was < 10 Mg/yr so no plan was required. The EOL BQ for the 2'"1quarter of 2015 "l'vas <2.5 Mg and the projected 2015 Ti\.B was < 10 Mg/yr so no plan was required. The EOL BQ for the 3"5quarter of20I5 v.as <2.5 Mg and the projected 2015 TA.B was < 10 Mg/yr so no plan was required. The EOL BQ for the 4'"quarter of2015 was <2.5 Ivfg and the projectcd2015 TAB 'NHS< 10 Mgiyr so no plan v,ras required. 2016: The EOL BQ for the 1st quarter of 2016 was <2.5 Mg and the projected 2016 TA.B was< 10 Mg!yr so no plan vrns required. The FOL BQ for the 2nctquarter of2016 was <2.5 .rv'fg and the projected 2016 TAB was < 10 Ivlgiyr so no plan was required. Th.,...,.. EO--- L BO-...: 1l.,1 tl1t":: ,1,__~rd c1.;,.;.,".ar,1.,,l,:,L.. u"f "..;;'.,0._, 16<.. ev__.,.ct":et1t,v,cl"?,,~.) VL '-,t,,t.-,. r"\._:-:,', r"Vci."~1ret-l bj" paragraph 22.J.iv, Navajo submits the following plan that identifies the specific actions that wilI be taken, and the schedule fr1r such actions, to ensure the TA.B does not exceed 1OMg in the calendar year As the first t,;vo quarters of 2016 indicated significantly lower concentrations of benzene in the \vastcwatcr, the projected TAB remained below 10 Mg !i)r the calendar year, and as such no specific actions need to be taken to ensure the TAB does not exceed 10Mg. Regardless ofthat, however, Navajo developed a plan of targeted monitoring to help identify and address the benzene contributions during the third quarter. The plan was implemented by November 4, 2016 (attachment 4). The EOL BO~ frir the 4th a_,;.uarter of 2016 \Vas <2.5 fvfo0 and the 1t ;ro,...iected TAB for 2016 \VRS <l OMg/yr, 2017: The EOL BQ for the 1" quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 i'v1g/yr. The EOL BQ for the 2"" quarter of 2017 was <2.5 Mg and the prnjeded TAB for 2017 was <l OT'v1g!yr_ Page 11 of 12 EPA Inspection Report - Page 1098 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHlVJENT 1 TO 4th QUARTER 2017 STATUS REPORT APPENDIX G STATUS SUivIMARY REPORT I The EOL BQ fr)r the :31a quarter of 2017 was <2.5 Mg and the projected TAB i for 2017 was <10 Mg/yr. The EOL BQ fr,r the 4th quarter of2017 was <2.5 Mg and the prqjected TAB for 2017 was <10 Mg/yr. I "Tl z :r- 0 0 0 0 .0.... -..,J Page 12 of 12 0) 0 EPA Inspection Report - Page 1099 of 1969 ATTACHMENT 2 APPENDIX H SUMMARY REPORTS HFNA-000001761 EPA Inspection Report - Page 1100 of 1969 Ho11yFrontier Navajo Refining LLC Artesia and Lovington Refineries /\l'TACHMENT .2 TO 4th Q!lARTER 2017 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT REPORTS, PLANS AND CERTIFICATIONS lJNDFR. THE LDAR ENHANC:CO PROGRAM PROVISIONS OF PARAGRAPH 23 OF THE CONSENT DECREE IN UNITED STATES, ET AL V. NAVA,JO REFINING co.~ ET AL. Name or Summary of the Repmt, Plan, or Ceniflcation CD Sub-,t Nos. Written RefineryWide LOAR Progrnm UpdaLed RefineryWide LDAR Program A:. Cha A ~~~- Rqd. ("R'') v. Cont- ingent C'C'J R C One-Tirne (''I") v. Quarterly orw/ 63.654 Reports C.'? l '') I 1 Due__Date Status 150 D after Lodging --~----~ As needed Prepared by 4/19/02 and Submitted 5/13/02 LDAR plan updated l I/19/2009, 0 l /05/20 l l , 04128/2014 (approved 7/2212014). Page 1 of 9 HFNA-000001762 EPA Inspection Report - Page 1101 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMEN'f 2 TO 4th QUARTER 2017 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-,I Report on training Ri; for new LDAR personnel O.ii- c(l) RqcL ("R") v, Contingent (.'(:.'] R One-Time ("1")v. Quarterly or w/ 63.654 Reports t'.2:.1..''.) >1 Due Date In each Section 63.654 Report Training addressed in 63.654 Repmt suhm itted 9/13/02, 3/15/03, 9115/03, 3! 15/04, 9/ 15/04, 3/14/05 (3/15/05 for Lovington), 9/13/05 (9/15/05 fix Lovington), 3/17/06, 9/13/06 (9/6/06 for Lovington), 3/16/07, 09/14/07, 03/17/08, 09/12/08, 03/16/09, 08/27/09, 03/16/2010, 09/13/2010, 03/16/2011 06/0EV201l, 07/10/2012, 09/10/12, l 1/06/2012, 12/11/2012, 01/13/2013, 05/02/2013, 05/08/2013, 05/15/2013, 02/08/2013 03/09/2013 and 09/ l6/2014 (tt1r A.ttesia and Lovington). New hire training was conducted 06/08/2011, 07/10/2012, 09/10/12, 11/06/2012, 12/11/2012, 01/13/2013, 05/02/2013, 05/08/2013, 05/15/2013, 02/08/2013, 12/9/2013, 03/22/2014, 03/3112014, 04/01/2014, 06/18/14, 06/ 19/14, and 06/20/2014. Anrmal LOAR Computer Based Training (CBT) implemented during the frimth quarter 2014 for all refinery and contractor personnel. First training completed befrJre 12/31i2014. /umual LDAR Computer Based Training (CBT) for new personnel completed during 2015. Annual CBT completed du.ring 2016, and also on 4/23/2016, 05/11/2016. Training completed on 01-1/13/2017, 04/25/2017, 05/20/2017, and 12/01/2017 _ - - - - - - - - ~ - - - - ----- _ ___,_ _ _ _-L....,_______________________ ------------------------------------- ~-------------------------------------- Page 2 of 9 HFNA-000001763 EPA Inspection Report - Page 1102 of 1969 Ho11yFrcntier Navajo Refining LLC A1iesia and Lovington Refineries ATTACH1VIENT 2 TO 4HB QUARTER 2017 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-,I Nos, Rqd, ("R'') v, Cont- ingent C.'.C~) One-Tirne (''l")v, Quarterly orw/ 63,654 Reports (">l.") Due..Date Report on annual Rii; R training for LOAR personnel O.ii- c(l) ,,,,,,,,,,,,,,,,,,,,,_,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, ---'- >l In each Training addressed in 63.654 Section Report submitted 9/13/02, 3/15/03, 63,654 9/15/03, 3115/04, 9/15/04, 3/14/05 Report (3/15/05 for Lovington), 9/13/05 (9/15/05 for Lovington), 3/17/06, 9/13N)6 (9/6/06 for Lovington), 3/16/07, 09/14/07, 03/17/08, 09/12/08, 03/16/09, 08/27/09, 03/16/2010, 09/13/2010, (for Artesia and Lovington),1\ru1ual training was conducted on the following dates by the on-site LDAR contractor: 06!29/2011, 06/14/2012, 06/24/2013, 06/26/2013, 11/12 tol 1/14/20143, 01/12/2014, 01/16/2014, OJ/20/2014, 01/21/2014, 02/08/20 l 4, 02/10/2014, 6/18/2014, 6/19/2014, and 06/20/2014. Annual LDAR Computer Based Training (C'BT) implemented during the fourth qnarler 2014 for a11 refinery and contractor personnel, Annual LDAR (CBT) conducted during 2015, Annual LDAR (CBT) conducted during 2016. Additional 2016 training held on 1/3/2016, 1/6/2016, 1/14/2016, and 1/19/2016, 1/31/2016, 04/28/2016, 05/11/2016, 09/2016, l 0/2016, 11/201 6, and 12/2016. Training completed on 04/13/2017, 04/25/2017, ________ 05/20/2017, and 12/01/2017. ---'----~-,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,............, ....,., ,,,,,,,,,,,,, Page 3 of9 HFNA-000001764 EPA Inspection Report - Page 1103 of 1969 HollyFrontier Nav,:~jo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO 4tn QUARTER 2017 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or Certific,1!:imi CD Sub-~ Nos. Rqd. (''K') v. Contingent ("C") One-Time ("l'') V. Quarterly orw/ 63.654 Reports {"> l ") Due Date Status Report on LD/\.R Riii; R >1 training fix refinety and operations O.iic(l) personnel who hold positions relevant to LDAR ~-~-~ In each Section 63.654 Repent Initial training program implemented. Training addressed in 63.654 Report submitted 9/13/02, 3/15/03, 9/15/03, 3/15/04, 9/15/04, 3/14/05 (3/15/05 for Lovington), 9/13/05 (9/15/05 for Lovington), 3117/06, 9/13/06 (9/6/06 for Lovington), 3/16/07, 09/14/07, 03/17/08, 09/12/08, 03/16/09, 08/27/09, 03/16/2010, 09/13/2010, 03/16/2011, 03/14/2012 and 09/16/2013. Training was conducted on the following dates frir refinery environmental personnel: 11/06/2012, 08/13 08/15/2013, 05/19- 5/2I/20l4, 8/21/2014, 10/02/2014. Annual LDAR Computer Based Training (CBT) implemented dudng the fourth quarter 2014 for all refinery and contractor personnel. Annual LDAR (CBT) conducted during 2015. Annual LO.AR (CBT) conducted during 2016. Additional 2016traininghddon 1/3/2016, 1/6/2016, 1/14/2016, and 1/19/2016, 1/31/2016, 04/28/2016, and 05/11/2016. Training completed on 04/13/2017, 04/25/2017, 05!20/2017, and 12/01/2017. ... Page 4 of 9 HFNA-000001765 EPA Inspection Report - Page 1104 of 1969 HoUyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTA_{]lMENT 2 TO 4m QUARI'~!{2017 STATUS REPORT APPENDIX H STATUS SlJMlVI.ARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-TI Nos, Rqd. (''K') v. Contingent _(''C") One-Time ("] ") V. Quarterly orwi 63.654 Reports f'> l") Due_Date Status LDAR audit D; R reports and records O.ii-b. of corrective actions. Audits are required every Hvo vears. >1 In the Included in the 1st Qtr 2003 report Quarterly (submitted 04/17/2003) as Report Attachment 3. 3rd party audits for for the 1" Artesia and Lovington were calendar perfrmned during December 2004, Quarter January 2007.. January 2009, and of each year January 2011. Included in the r:i Qtr 2012 report a copy of the Ol/201 J Audit Repmt and the comxtive actions taken were included with the 1''1 Quarter 2012 report as Attachment 5. The 2013 3rd party audit was conducted from 09/16 to 09/20/2013, after major refinery turnaround, and a complete quarter worth of normal operation data has been collected for comparative monitoring, A copy of the audit rep(nt and resolutions were presented in the 1';1 Quarter 2014 reprni. yet party audits frn- Artesia and Lovington were performed during the week of October 5u1 to ~f, 2015. A copy of the 2015 LDA.R 3rd party audil report and resolutions are included in Attachment 5 of the 1st Quarter 2016 report. The 2017 LDAR 3'11 party audit was conducted fiom 05/l 7 to 05/18i201 7, A copy of the audit report was attached to the 3rd Quarter Consent Decree Progress Report, The audit resolutions ,vm be included as Attachrnen1 4 to the ~----------------'-----'---------------'-----~-1_st_(~)_uc_ar_te_''r_2 _O\?._re,.,,.;,_o_r_.t._ _ _ _......., Page 5 of9 HFNA-000001766 EPA Inspection Report - Page 1105 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTA.CHMENT 2 TO 4th QUARTER 2Q17 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary of the Report Plan, or Certification CD Sub-11 No~,. Certification of G; implementation of O.iithe first attempt at a(l) repair program Rqd. ("R") v. Com- i.ngent e.G'.) R One-Ti.me (''l ") V. Quarterly orw/ 63.654 Reports t'?:J5 l .... Operational I.ii.; R l specifications fr)r electronic LDAR O.i-b data colledi.on and transfer - - - - ....~- Certification of J: R implememation of O.iiQAJQC a(2) procedures for review of data generated by LDAR monitoring technicians ...... 1 ~ .. Due_Date Statg_~ In the first Qtdy report due under the CD or the first Qtrly report in which the rqmL becomes due 6 mos. afler Lodging for Navajo; l yr. after Lodging for Montana Refining In Lhe first Qtrly report due under the CD or the first O., trl,v report in which the rqmL becomes due. Provided with Initial Quarterly Status Report submitted fi.1r 2"J Quarter 2002 on July 30, 2002 .. Submitted 06/19/2002 --- Provided with Initial Quarterly Status Report submitted for 2"d Quarter 2002 on July 30, 2002. -- - Page 6 of9 HFNA-000001767 EPA Inspection Report - Page 1106 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHJUENT 2 TO 4m QUARTER 2017 STATUS REPORT APP.EN.DIX H STATUS SUMIVIARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-,T Nos. Rqd. ("K') v. Contingent ('_'C') One-Time ("l ") v. Quarterly orw! 63.654 Reports C'> 1"} Due_Date Status Identification of each Refinery's LDAR ''point" person. K R ' O.ii- a(3) ...... Certification of the L; R development of a tracking program for new valves and O.iia(4) pumps ~--~~-~-----~ l l ~-- In the Provided with Initial Quarterly first Qtdy Status Report submitted frn- 2nd report Quarter 2002 on July 30, 2002 due under the CD or the first Qtrly report in which the rqmt. becomes due . ....... .. ln the first Qtr!y report due under Provided with lni1ial Quarterly Status Report submitted frr 2"d Quarter 2002 on July 30, 2002 the CD or the first Qtdy report in which the rqmt becomes due -- ................... Page 7 of9 HFNA-000001768 EPA Inspection Report - Page 1107 of 1969 HoliyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHl\fENT 2 TO 4th QUARTER 2017 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary ofthe Report, Plan, or Certification CD Sub-11 Nos. Certification of M: implementation of O.ii- calibration drift a(5) assessment procedures Certification of implernentation of Lhe 'delay of repair'' procedures N; ()ji- a(6) Rqd. ("R'') v, Contineas;";_n_ t ("'C. ") R ... R ~-- One-Time ('' J") V. Quarterly orw/ 63.654 Reports ("> l ''} l 1 Due Date Status In the first Qtrly report due under the CD or the first Qtrly report in which the requirem ent becomes due In the first Qtrly report due under the CD or the first Qtrly report in which the requirem ent becomes due Provided with Initial Quarterly S,. tatm; Repon su t,nu.tted for".-',nd Quarter 2002 on July 30, 2002 ~ Provided with hlitial Quarterly Status Report submitted for 2nd Quarter 2002 on July 30, 2002 ~-- Page 8 of9 HFNA-000001769 EPA Inspection Report - Page 1108 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO 4th QUARTER20l7 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-1'[ Nos. LDitR monitoring O; report submitted with MAGI O.ii- periodic reports c(2) RqcL C'R'') v. Contingent e.(.'.') R ... One-Time (''] ") V. Quarterly orw/ 63.654 Reports C?..L'.') >1 Due Date Status In each Section 63.654 Report Provided in MA.CT 63.654 Reports submitted: 3/15/02, 9/13/02, 3/15/03, 9/15/03, 3/15/04, 9/15/04, 3/14/05 (3/15/05 for Lovington 9/13/05 (9/15/05 for Lovington), 3/17/06, 9/13/06 (9/6/06 for Lovington), 3116/07, 09/14/07, 03/17/08, 09/12/08, 03/16/09, 08/27/09, 03/16/2010, 09/13/2010, 03/16/2011, 09/15/2011, 03/09/2012, 0/06/2012 (09/06/2012 frff Lovington), and 03/15/2013, 09/16/2013, (Lovington and i-\Jtesia) 02/25/2014 (.Artesia), 08/26/2014 (Lovington), and 02/26/2015 (Ariesia and Lovington), 08/27/2015, 2/18/2016 (Artesia and Lovington), 08/29/2016 (A1tesia and Loving1on}, 02/2812017 (Artesia and Lovington), and 08/29/2017 (Artesia and Lovington). Page 9 of9 HFNA-000001770 EPA Inspection Report - Page 1109 of 1969 ATTACHMENT 3 QUARTERLY EOL AND SAMPUNG RESULTS (Paragraph 22JV!.ii.a(3}) HFNA-000001771 EPA Inspection Report - Page 1110 of 1969 HollyFrontier Navajo Refining LLC Artesia, NI\i Refinery End of Line Sampling Report 4th Quarler 2017 A'fTACHI\TENT 3 TO 4th 0UARTER2017 STATUS REPORT OUAUTERLY END OF LINE SAl\iPLING RESULTS On October Hi\ October 191, November 2nd, and December 1 5\ 2017, Navajo Refining's Artesia facility perfonned the End of Line (EOL) sampling pursuant to the Consent Decree, following the protocol described in Navajo's EOL sampling plan that was revised by a letter dated March 31, 2004, except as noted below for Cement Ki1n Fuel (S-4). Due to changes in our wastewater systern, the slop oiI frorn our Alky API is diverted through the new wastewater APL Therefore, that stream is now factored into the calculations for the Wastewater APL As a result, Navajo has identified six (6) sampling points that were monitored during the EOL sampling. This included three representative samples for each sampling site, volume measure1nents, and specific gravity values, collected once a month during the quarter where applicable. Three representative samples of API sludge material generated during the 4th Quarter of 2017 were collected on 12/19/2017, and the test results are included in this report The fi.,llowing calculations estimate the quarterly FOL and calendar year benzene quantities; Oil from \:Vastewater APT FOL (Mg/qtr} weeks/quarter x Oil Volmne (gal/wk) x lbs. water/gallon x Specific Gravity of oil (dimensionless) x average benzene concentration in oil (ppmw) x grams/lb --,- 1fl-' g/Mg Oil from 'Wastewater API EOL (l'v1g/qtr) ,-,,. 13 \Vks/qtr x 46,109 gals/wk x 8,34 Tbs)gaUon x: (t99 (dimensionless) x 10.8 lb/106 x 454 g/1b --,-- 1(/' g/Mg Oil front Wastewater API EOL = 0.02 lVl.g/qtr 'Wastewater - EOL (Mg/qtr) = days/qtr x A.verage Flow (gaJ/day) x Water Density (1bs. water/gal) x Average Benzene Concentration in wastewater (ppmw) x grams/lb ;- 106 g/\{g \Vaste'fi'ater - EOL (Mg/qtr) = 92 days/qtr x 720,000 gal/day x 8.34 lbs/gal x 0.70 lb/106 }b X 454 ~ 2:/}b , l 0 ~ 6 g/Mg<:.r \Vastewater - EOL = 0.18 Mg/qtr Cement KUrn Fuel Product EOL (J'v1g/qtr) = Amount of cement kiln fuel shipped m quarter (lbs/qtr) x Average Benzene Concentration (ppnn:v) x g/lb + t06 g/Mg Cement Kiln. Fuel Product EOL (Mg/qtr) ,-,,, 17,940 (lbs/qtr) x 5.0 lb/Hf' x 454 g/1b -,-106 g/Mg Cement Ki.In. Fuel Product EOL = 0J)9 Mg/qt.r N:\Cmscnt Decree\Subm-Resp\Quarterly Reports\2017 4QT- Att3-EOL Repo1t.d.Jc Page 1 of3 HFNA-000001772 EPA Inspection Report - Page 1111 of 1969 BOllyfrontier Navajo Refining LLC A.rtesia, NM Refinery End of Line Sampling Report 4th Quarter 2('.) 17 ATTAClilVlENT 3 TO 4tti QUARTER 2017 STATUS REPOR'l' QUARTERLY END OF LINE SAMPLING RESl.JLTS Aqueous \Vaste ~austic EOL (l\rfg!qtr) = Amount of aqueous \vaste caustic shipped in the quarter (total of Tanks 40 and 41) (gal) x lbs/gal x Average Benzene Concentration (ppmw) x g/lb 0- Hi g!Mg Aqueous ,vaste Caustic EOL (Iv1g/qtr) = 18,759 gal/qtr x 9,64 lbs/gal x OJ;,25 lb/106 lb x 454 g/lb-;- 1(}1' g/Mg Aqueous ,vaste Caustic EOL = 2.0 E (-6) Mg/qt/ \Vaste Caustic Uvdrocarl:wn EOL (!vfg!qtr) = days/qtr x avg flow (gal/day) x water density (lbs/ gal) x Specific Gravity (dimensionless) x Average Benzene Concentration (ppmw) x g/lb + l 06 g!Mg Waste Caustic Hvdrncarbon EOL (Mg/qtr) = 92 days/qtr x 42 gal/day x 8.34 1bs/ga1 x I. I7 (dimensionless) x 023 lb/Hi lb x 454 g/1b ' H/' g/Mg Waste Caustic :n:vdrncarbon EOL = 4.0 E(-6) l'Hg/qtr Therefore, estimated total quarterly benzene equals benzene in Oil fro.m \Vastewater AP'I (Mg/qtr) + benzene in \Vastewater (Mg/qtr) + benzene in Cement Kiln Fuel Product (Iv1g/qtr) + benzene in Aqueous \Vaste Caustic (Mg!qtr) + benzene in \Vaste Caustic Hydrocarbon (Mg/qtr). Estimated Total Quarterly Benzene= 0.02 Mg/qtr + o.rn Mg/qtr + 0.09 Mg/qtr + 2.0 E (- 6) lVig/qtr-'- 4.0 E(-6) Mg/q_tr Estimated Quarterly EOL Benzene= 0,29 :Vig/qtr Therefore, the Artesia Refinery's quarterly EOL benzene quantity did not exceed 2.5 Mg!qtr. Estirnate~LA@V.i.t.LB._enzene {AB) Quantitv_..f~\L~:.?l~!.mJ?.T.Y01:lf 2016 Estimated 2017 TAB== [(1 5lQ + 2116Q+3rdQ+4th QT)/ 4] * 4 = [(0,84 + OJO+(U l-'-0.29) / 4] * 4 Estimated 2017 TAB = 1.34 Mg The Artesia Refinery's projected calendar year 2017 total annual benzene quantity does not exceed IO Mg/yr. The above calculations ,,:vere determined using the values from the frJl1owing table and the attached analyses. Page:2 of 3 HFNA-000001773 EPA Inspection Report - Page 1112 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery ATTACHMENT 3 TO 4m QUARTER 2017 STATUS REPORT QUARTERLY END OF LINE SAMPLING RESULTS End of Line Sampling Report 4th Quarter 20 l 7 TABLE 1 QUARTERLY EOL SAMPLING NAVAJO REFINING Sampling Point Oil from W astcwaler APl (S-1) Volume 46,109 gal/wk Test results Sample Co1kctcd 10/03/2017 27.00 ppm Test results Sample Collected 11/02/2017 5.50 ppm Tesl results Sample Collected 12/05/20 !7 M~ + (),()LJ ppm Test results Samples Collected 12/19/2017 NA Average of '['''''''''''S''''p'''e''c'''i'fic1 Samples Gravity or I Density I 10.84 ppm ' 0.99 ' Wastewater Tanks (S-3) Cement Kiln Fuel (S-4)'" 720,000 gal/day 17,940 His 0.58 ppm NA 1.50ppm NA OJ)25ppm NA. NA S4 (1) = 4.76 ppm S4 (2) = 4.85 ppm S4 (3) = 5.39 ppm 0.70 ppm 5.00 ppm Aqueous Wasle Caustic Tank 40 (S-5) -- 18,759 gal/qtr 0.025 ppm 0.024 ppm-c+ 0.024 ppm NA 0.024 ppm Aqueous Waste Caustic Tank 41 (S-6) "' (),()24 ppm++ e--------""""""""""---+-------+----- ""1' '" Avernge of Aqueous \Vastc Caustic Tanks * 0.025ppm . (S-5 and S-6) ! Wastc Caustic i f_ _fiydrocarbon (S-7) / 42 gal/dav / , 0.23# 0.025 ppm 0.025 ppm 0.23ii . 0.02)- ppm+ 0.025 ppm 0.23 11 NA 0.025 ppm NA 0.25 ppm NA I 0.23# I *The volume for Caustic Tank 41 is ref1ected in the value assigned to Tank 40. Tiie quantity assigm:d to Tank 40 is ,he rnmbined volume from BOTH tanks that was shipped o.;t in lhe quarter. 'The Benzene result was below the method detection limit (MDL) of0.025 ppm. 11,c MDL wa, used as a rnnservative aproach. -T'nt Benzene result was below the method dekclion limit (MDL) of0.024 ppm. The MDL was used as a conservative aproach. "No sample C(mld be collected because the hydro0arhon layer was between ,he sample point draws on the tank. The l QT average Benzene of 0.23 ppm, spccitfo gravity of l 17 was used. "'*Benzene srnnpks w;;,re collected at less than th<! 24-hour rninimum interval brtwccn samples specified in the EOL sampling plan, 1.00 NA U3 1.14 Ll4 l.171' :r-I "Tl z N.',Coris~~nt Df:n:~e'-Subm-Resp'Quart~ly Rcport;;\2017 ,JQT - At!:3-FOL Rr;pmi do;:0 0 0 0 0 ...... -..,J -..,J .i:,,. Page 3 of3 EPA Inspection Report - Page 1113 of 1969 ATTACHMENT 4 ANALYT!CAL REPORTS EOL SAM PUNG HFNA-000001775 EPA Inspection Report - Page 1114 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 October 13, 2017 Tyler Turner (Cons. Aqua Microbics) Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling (EOL) Dear Tyler, Work Order: HS17100323 ALS Environmental received 9 sample(s) on Oct 05, 2017 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, Generated By: Dayna.Fisher Nicole Edwards Project Manager Right Solutions Right Partnu www.a!sg!obaLcom Pagel of27 HFNA-000001776 EPA Inspection Report - Page 1115 of 1969 ALS Group USA, Corp Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100323 lab Samp ID HS17100323-01 HS17100323-02 HS17100323-03 HS17100323-04 HS17100323-05 HS17100323-06 HS17100323-07 HS17100323-08 HS17100323-09 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Matrix Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Date: 13-0ct-17 SAMPLE SUMMARY TagNo Collection Date 03-0ct-2017 09:29 03-0ct-2017 09:51 03-0ct-2017 09:01 03-0ct-2017 09:05 03-0ct-2017 09:35 03-0ct-2017 10:04 03-0ct-2017 10:26 03-0ct-2017 00:00 040417-71 03-0ct-2017 00:00 Date Received 05-0ct-2017 08:25 05-0ct-2017 08:25 05-0ct-2017 08:25 05-0ct-2017 08:25 05-0ct-2017 08:25 05-0ct-2017 08:25 05-0ct-2017 08:25 05-0ct-2017 08:25 05-0ct-2017 08:25 Hold D D D D D D D D D Page 2 of27 HFNA-000001777 EPA Inspection Report - Page 1116 of 1969 ALS Group USA, Corp Date: 13-0ct-17 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100323 GCMS Volatiles by Method SW8260 Batch ID: R303074 CASE NARRATIVE The test results meet requirements of the current NELAP standards, state requirements or programs where applicable. Batch ID: R302973 Sample ID: S-5 (T-40) (HS17100323-03}, S-6 (T-41) (HS17100323-04) Lowest practical dilution for HS17100323-03, 04 due sample matrix. Surrogates failure also due to sample matrix. Batch ID: R303290 Sample ID: HS17100423-01 MS MS is for an unrelated sample Page 3 of27 HFNA-000001778 EPA Inspection Report - Page 1117 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (API HC) 03-0ct-2017 09:29 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 27 91.2 101 93.1 100.0 Method:SW8260 0.25 REPORT LIMIT 2.5 70-126 73-120 70-130 82-121 Date: 13-0ct-17 ANALYTICAL REPORT Work0rder:HS17100323 Lab ID:HS17100323-01 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 500 %REC 500 %REC 500 %REC 500 %REC 500 Analyst: WLR 09-0ct-2017 17:23 09-0ct-2017 17:23 09-0ct-2017 17:23 09-0ct-2017 17:23 09-0ct-2017 17:23 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of27 HFNA-000001779 EPA Inspection Report - Page 1118 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 03-0ct-2017 09:51 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.58 96.5 92.2 93.0 102 Method:SW8260 0.030 REPORT LIMIT 0.25 70-126 81-113 77-123 82-127 Date: 13-0ct-17 ANALYTICAL REPORT Work0rder:HS17100323 Lab ID:HS17100323-02 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: PC 12-0ct-2017 16:00 12-0ct-2017 16:00 12-0ct-2017 16:00 12-0ct-2017 16:00 12-0ct-2017 16:00 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of27 HFNA-000001780 EPA Inspection Report - Page 1119 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 03-0ct-2017 09:01 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.025 91.7 93.8 55.1 96.4 Method:SW8260 0.025 s REPORT LIMIT 0.25 70-126 73-120 70-130 82-121 Date: 13-0ct-17 ANALYTICAL REPORT Work0rder:HS17100323 Lab ID:HS17100323-03 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 09-0ct-2017 16:17 09-0ct-2017 16:17 09-0ct-2017 16:17 09-0ct-2017 16:17 09-0ct-2017 16:17 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of27 HFNA-000001781 EPA Inspection Report - Page 1120 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-6 (T-41) 03-0ct-2017 09:05 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.024 90.0 97.0 58.5 96.2 Method:SW8260 0.024 s REPORT LIMIT 0.24 70-126 73-120 70-130 82-121 Date: 13-0ct-17 ANALYTICAL REPORT Work0rder:HS17100323 Lab ID:HS17100323-04 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 09-0ct-2017 16:54 09-0ct-2017 16:54 09-0ct-2017 16:54 09-0ct-2017 16:54 09-0ct-2017 16:54 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of27 HFNA-000001782 EPA Inspection Report - Page 1121 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Field Blank 03-0ct-2017 09:35 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 85.4 105 91.4 90.1 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 81-113 77-123 82-127 Date: 13-0ct-17 ANALYTICAL REPORT Work0rder:HS17100323 Lab ID:HS17100323-05 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 1O-Oct-2017 05:47 10-0ct-2017 05:47 10-0ct-2017 05:47 10-0ct-2017 05:47 10-0ct-2017 05:47 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 8 of27 HFNA-000001783 EPA Inspection Report - Page 1122 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 1 03-0ct-2017 10:04 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 85.7 103 91.5 90.4 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 81-113 77-123 82-127 Date: 13-0ct-17 ANALYTICAL REPORT Work0rder:HS17100323 Lab ID:HS17100323-06 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 10-0ct-2017 06:12 10-0ct-2017 06:12 10-0ct-2017 06:12 10-0ct-2017 06:12 10-0ct-2017 06:12 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 9 of27 HFNA-000001784 EPA Inspection Report - Page 1123 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 2 03-0ct-2017 10:26 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 85.0 102 91.7 89.0 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 81-113 77-123 82-127 Date: 13-0ct-17 ANALYTICAL REPORT Work0rder:HS17100323 Lab ID:HS17100323-07 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 1O-Oct-2017 06:36 10-0ct-2017 06:36 10-0ct-2017 06:36 10-0ct-2017 06:36 10-0ct-2017 06:36 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 10 of27 HFNA-000001785 EPA Inspection Report - Page 1124 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Duplicate 03-0ct-2017 00:00 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.58 102 97.9 102 98.3 Method:SW8260 0.030 REPORT LIMIT 0.25 70-126 81-113 77-123 82-127 Date: 13-0ct-17 ANALYTICAL REPORT Work0rder:HS17100323 Lab ID:HS17100323-08 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: PC 12-0ct-2017 16:27 12-0ct-2017 16:27 12-0ct-2017 16:27 12-0ct-2017 16:27 12-0ct-2017 16:27 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 11 of27 HFNA-000001786 EPA Inspection Report - Page 1125 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Trip Blank 03-0ct-2017 00:00 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 84.7 103 91.6 90.6 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 81-113 77-123 82-127 Date: 13-0ct-17 ANALYTICAL REPORT Work0rder:HS17100323 Lab ID:HS17100323-09 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 1O-Oct-2017 05:22 10-0ct-2017 05:22 10-0ct-2017 05:22 10-0ct-2017 05:22 10-0ct-2017 05:22 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 12 of27 HFNA-000001787 EPA Inspection Report - Page 1126 of 1969 ALS Group USA, Corp Client: Navajo Refining Company Project: BWON Monthly Sampling (EOL) WorkOrder: HS17100323 Batch ID: 1978 SamplD HS17100323-01 HS17100323-03 HS17100323-04 Method: VOLATl LES BY SW8260C Container Sample Wt/Vol 5.051 (g) 5.034 (g) 5.107 (g) Final Volume 5 (ml) 5 (ml) 5 (ml) Weight Factor 0.99 0.99 0.98 Container Type Bulk (5030B) Bulk (5030B) Bulk (5030B) Date: 13-0ct-17 WEIGHT LOG Page 13 of27 HFNA-000001788 EPA Inspection Report - Page 1127 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100323 Sample ID Client Samp ID Collection Date TCLP Date Batch ID R302973 Test Name : VOLATILES BY SW8260C HS17100323-01 HS17100323-03 HS17100323-04 S-1 (API HC) S-5 (T-40) S-6 (T-41) 03 Oct 2017 09:29 03 Oct 2017 09:01 03 Oct 2017 09:05 Batch ID R303074 Test Name: VOLATILES- SW8260C HS17100323-05 HS17100323-06 HS17100323-07 HS17100323-09 Field Blank EQ Blank Port 1 EQ Blank Port 2 Trip Blank 03 Oct 2017 09:35 03 Oct 2017 10:04 03 Oct 2017 10:26 03 Oct 2017 00:00 Batch ID R303290 Test Name : VOLATILES - SW8260C HS17100323-02 HS17100323-08 S-3 (API Water) Duplicate 03 Oct 2017 09:51 03 Oct 2017 00:00 Date: 13-0ct-17 DATES REPORT Prep Date Analysis Date DF Matrix: Liquid 09 Oct 2017 17:23 500 09 Oct 201716:17 50 09 Oct 2017 16:54 50 Matrix: Liquid 10 Oct 2017 05:47 10 Oct 2017 06:12 10 Oct 2017 06:36 10 Oct 2017 05:22 Matrix: Liquid 12 Oct 201716:00 50 12 Oct 201716:27 50 Page 14 of27 HFNA-000001789 EPA Inspection Report - Page 1128 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100323 Date: 13-0ct-17 QC BATCH REPORT Batch ID: R302973 Instrument: VOA8 Method; SW8260 MBLK Client ID: Analyte Sample ID: MBLKW1-100917 Units: ug/Kg Analysis Date: 09-0ct-2017 09:08 Run ID: VOA8_302973 SeqNo: 4255067 Prep Date: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 25 2389 2329 2440 2430 250 0 2500 0 2500 0 2500 0 2500 0 95.6 76 - 125 0 93.1 83 - 120 0 97.6 80 - 119 0 97.2 81 - 118 LCS Client ID: Analyte Sample ID: VLCSW1-100917 Units: ug/Kg Analysis Date: 09-0ct-2017 08:21 Run ID: VOA8_302973 SeqNo: 4255066 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 47.91 5.0 50 44.55 0 50 48.74 0 50 49.83 0 50 50.73 0 50 0 95.8 75 - 124 0 89.1 76 - 125 0 97.5 83 - 120 0 99.7 80 - 119 0 101 81 - 118 MS Client ID: Analyte Sample ID: HS17091520-14MS Units: ug/Kg Analysis Date: 09-0ct-2017 14:19 Run ID: VOA8_302973 SeqNo: 4255867 Prep Date: OF: 1000 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 56900 60950 65050 63630 70350 6900 0 0 0 0 69000 69000 69000 69000 69000 0 82.5 70 - 130 0 88.3 70 - 126 0 94.3 72 - 120 0 92.2 70 - 130 0 102 82 - 121 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 15 of27 HFNA-000001790 EPA Inspection Report - Page 1129 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100323 Date: 13-0ct-17 QC BATCH REPORT Batch ID: R302973 Instrument: VOA8 Method; SW8260 MSD Client ID: Analyte Sample ID: HS17091520-14MSD Units: ug/Kg Analysis Date: 09-0ct-2017 14:46 Run ID: VOA8_302973 SeqNo: 4255868 PrepDate: OF: 1000 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene 64570 6900 69000 0 93.6 70 - 130 56900 12.6 30 Surr: 1,2-0ichloroethane-d4 60090 0 69000 0 87.1 70 - 126 60950 1.43 30 Surr: 4-Bromofluorobenzene 65260 0 69000 0 94.6 72 - 120 65050 0.321 30 Surr: Dibromofluoromethane 63880 0 69000 0 92.6 70 - 130 63630 0.39 30 Surr: Toluene-dB 70500 0 69000 0 102 82 - 121 70350 0.219 30 The following samples were analyzed in this batch: ~f_s_17_1_0_03_2_3_-0_1_ _ _H_S 1_71_ 003_ 23-_ 03 _ _ _H_Sl_ 710_ 032_3-0_4 _ _ _ _ _ _ _ _ _ _ _ _~ Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 16 of27 HFNA-000001791 EPA Inspection Report - Page 1130 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100323 Date: 13-0ct-17 QC BATCH REPORT Batch ID: R303074 Instrument: VOA6 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-171009 Units: ug/L Analysis Date: 09-0ct-2017 23:08 Run ID: VOA6_303074 SeqNo: 4256840 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 42.63 0 50 51.73 0 50 46.04 0 50 45.38 0 50 0 85.3 70 - 123 0 103 82 - 115 0 92. 1 73 - 126 0 90.8 81 - 119 LCS Client ID: Analyte Sample ID: VLCSW-171009 Units: ug/L Analysis Date: 09-0ct-2017 22:18 Run ID: VOA6_303074 SeqNo: 4256839 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 57.94 5.0 50 41.77 0 50 51. 18 0 50 45.48 0 50 44.85 0 50 0 116 74 - 120 0 83.5 70 - 130 0 102 82 - 115 0 91.0 73 - 126 0 89.7 81 - 119 MS Client ID: Analyte Sample ID: HS17100061-09MS Units: ug/L Analysis Date: 10-0ct-2017 00:23 Run ID: VOA6_303074 SeqNo: 4256842 Prep Date: OF: 100 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 5422 4244 5179 4596 4518 500 5000 0 5000 0 5000 0 5000 0 5000 0 108 70 - 127 0 84.9 70 - 126 0 104 81 - 113 0 91.9 77 - 123 0 90.4 82 - 127 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 17 of27 HFNA-000001792 EPA Inspection Report - Page 1131 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100323 Date: 13-0ct-17 QC BATCH REPORT Batch ID: R303074 Instrument: VOA6 Method; SW8260 MSD Client ID: Analyte Sample ID: HS17100061-09MSD Units: ug/L Analysis Date: 10-0ct-2017 00:48 Run ID: VOA6_303074 SeqNo: 4256843 PrepDate: OF: 100 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene 5489 500 5000 0 110 70 - 127 5422 1.23 20 Surr: 1,2-0ichloroethane-d4 4218 0 5000 0 84.4 70 - 126 4244 0.614 20 Surr: 4-Bromofluorobenzene 5157 0 5000 0 103 81 - 113 5179 0.428 20 Surr: Dibromofluoromethane 4574 0 5000 0 91.5 77 - 123 4596 0.498 20 Surr: Toluene-dB 4543 0 5000 0 90.9 82 - 127 4518 0.564 20 The following samples were analyzed in this batch: ~f_s_17_1_0_03_2_3_-o_s_ _ _H_S 1_71_ 003_ 23-_ 06 _ _ _H_Sl_ 710_ 032_3-0_7 _ _ _H_ S17_10_ 032_ 3-0_ 9 _ _ _ _~ Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 18 of27 HFNA-000001793 EPA Inspection Report - Page 1132 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100323 Date: 13-0ct-17 QC BATCH REPORT Batch ID: R303290 Instrument: VOA1 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-171012 Units: ug/L Analysis Date: 12-0ct-2017 12:23 Run ID: VOA1 - 303290 Result PQL SPKVal SeqNo: 4261076 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 46.67 0 50 52.57 0 50 47 0 50 51.26 0 50 0 93.3 70 - 123 0 105 82 - 115 0 94.0 73 - 126 0 103 81 - 119 LCS Client ID: Analyte Sample ID: VLCSW-171012 Units: ug/L Analysis Date: 12-0ct-2017 11:30 Run ID: VOA1 - 303290 Result PQL SPKVal SeqNo: 4261075 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 53.69 5.0 50 48.93 0 50 49.02 0 50 45.12 0 50 47.29 0 50 0 107 74 - 120 0 97.9 70 - 130 0 98.0 82 - 115 0 90.2 73 - 126 0 94.6 81 - 119 MS Client ID: Analyte Sample ID: HS17100423-01 MS Units: ug/L Analysis Date: 12-0ct-2017 13:44 Run ID: VOA1 - 303290 Result PQL SPKVal SeqNo: 4261079 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene 43.8 5.0 50 0 87.6 70 - 127 Surr: 1,2-0ichloroethane-d4 47.69 0 50 0 95.4 70 - 126 Surr: 4-Bromofluorobenzene 58.67 0 50 0 117 81 - 113 s Surr: Dibromofluoromethane 44.29 0 50 0 88.6 77 - 123 Surr: Toluene-dB 54.73 0 50 0 109 82 - 127 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 19 of27 HFNA-000001794 EPA Inspection Report - Page 1133 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100323 Date: 13-0ct-17 QC BATCH REPORT Batch ID: R303290 Instrument: VOA1 Method; SW8260 MSD Client ID: Analyte Sample ID: HS17100423-01 MSD Units: ug/L Analysis Date: 12-0ct-2017 14:10 Run ID: VOA1 - 303290 Result PQL SPKVal SeqNo: 4261080 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene 51.24 5.0 Surr: 1,2-0ichloroethane-d4 49.87 0 Surr: 4-Bromofluorobenzene 52.16 0 Surr: Dibromofluoromethane 46.85 0 rs Surr: Toluene-dB 47.99 0 The following samples were analyzed in this batch: 17100323-02 50 50 50 50 50 HS 17100323-08 0 102 70 - 127 0 99.7 70 - 126 0 104 81 - 113 0 93.7 77 - 123 0 96.0 82 - 127 43.8 47.69 58.67 44.29 54.73 15.6 20 4.47 20 11.8 20 5.61 20 13.1 20 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 20 of27 HFNA-000001795 EPA Inspection Report - Page 1134 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100323 Date: 13-0ct-17 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND O P R S U Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL/SOL Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SOL TRRP Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Unit Reported mg/Kg mg/L Description Milligrams per Kilogram Milligrams per Liter Page 21 of27 HFNA-000001796 EPA Inspection Report - Page 1135 of 1969 ALS Group USA, Corp Agency Arkansas California Illinois Kentucky Louisiana North Carolina North Dakota Oklahoma Texas Date: 13-0ct-17 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number 17-027-0 2919 2016-2018 004112 123043 03087 2017-2017 624-2017 R193 2017-2017 2017-088 T104704231-17-19 Expire Date 27-Mar-2018 31-Jul-2018 09-May-2018 30-Apr-2018 30-Jun-2018 31-Dec-2017 30-Apr-2018 31-Aug-2018 30-Apr-2018 Page 22 of27 HFNA-000001797 EPA Inspection Report - Page 1136 of 1969 ALS Group USA, Corp Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100323 Lab Sarnp ID HS17100323-01 HS17100323-02 HS17100323-03 HS17100323-04 HS17100323-05 HS17100323-06 HS17100323-07 HS17100323-08 HS17100323-09 Client Sample ID S-1 (API HG) S-3 (API Water) S-5 (T-40) S-6 (T-41) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Action Login Login Login Login Login Login Login Login Login Date 10/6/2017 11:10:12 AM 10/6/2017 11:10:12 AM 10/6/2017 11:10:12 AM 10/6/2017 11:10:12 AM 10/6/2017 11:10:12 AM 10/6/2017 11:10:12 AM 10/6/2017 11:10:12 AM 10/6/2017 11:10:12 AM 10/6/2017 11:10:12 AM Person CL CL CL CL CL CL CL CL CL Date: 13-0ct-17 SAMPLE TRACKING New Location VOA120 VOA120 VOA120 VOA120 VOA120 VOA120 VOA120 VOA120 VOA120 Page 23 of27 HFNA-000001798 EPA Inspection Report - Page 1137 of 1969 ALS Group USA, Corp Client Name: Work Order: Navajo Refining HS17100323 Date/Time Received: Received by: Date: 13-0ct-17 Sample Receipt Checklist 05-0ct-2017 08:25 JRM Checklist completed by: Cesar A. Lira 6-0ct-2017 -e,:-S,-ig_n_a,-tu-re--------.---,D=-a..,.t_e_ _ Reviewed by: Nicole Edwards eSignature 9-0ct-2017 Date Matrices: liquid. oils Carrier name: Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Chain of custody present? Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? TX1005 solids received in hermetically sealed vials? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler( s )/Kit( s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ .8c/3.1c UC/C IR11 10/5/2017 19: 00 Yes 4 Yes D Yes D No D No D No D No D No D No D No D No D No D No D No D No D No No D No D D Not Present D Not Present Not Present ~ N/A ~ IR11 No VOA vials submitted N/A ~ N/A ~ Login Notes: fsamples refrigerated prior to login. Client Contacted: Date Contacted: Person Contacted: Contacted By: Comments: Regarding: Corrective Action: Page 24 of27 HFNA-000001799 EPA Inspection Report - Page 1138 of 1969 Chain of Custody Form Page _1_ of _L_ D Cincinnati, OH +l 513 733 5336 D Everett, WA +l 425 356 D 2600 D +1616 399 6070 Holland, Ml D +l 281 530 5656 Houston, TX D Middletown, PA +l 717 944 5541 D +l 801 266 Salt lake City, UT 7700 D Spring City, PA +1610948 D 4903 Enuironmental << wciri< orcier :::-::::~-,::::::::: } :)::nm~aiiy~a!Tle Navajo Refining Company LLC Tyler Tumer Gabi Combs I :: P.O. Box 159 I< :/ :>:: :~,~i$4i~elZ/p Artesia, NM 88211-0159 I> / >Phone (575) 748-3311 : : j='~it (575) 746-5451 ALS Project Manager: Erica Padilla :::: : :::: :::P.fojeitlnfottriati6n:::-.. . P.rojei.t ~afu.~ BWON Monthly Sampling (EOL) . . . .... . .. ElillJo C{)mpany Holly Frontier Navajo Refining LLC /:: 501 East Main <}){t:il:yJStatetZip Artesia, New Mexico 88210 / <:<: :\ P~~~a (575) 748-3311 I> > : ::::::: . :f::a~ (575) 746-5451 Work Order#: <A VOLATILES (8260) Benzene - <E. HS17100323 - Navajo Refining Company - BWON Monthly Sampling (EOL) - :H: - : I_< 111111111111 H 11111111 lffl - .:)Jo:_;_:. . . . . :-: : :;,:~~~;;:.:-::.: . ... ....... : ?oaie:<: :: : T1rii{< ... : Matriii:: :_: Pres:: 1Hioti1i/s< : >a .. C: i< E) iF ... G:: <ii : : i :<j .._H_o__id_:_:. ....,.,..,.,..,.,..,---._---._._.__':'._"'.'_'-1-'.'.:".'.__-._..__.._._-.._._.._..._ _ _.___.."_.._ _ _ _ _ _ _ _"_-----+----+----;1----+---+---+--t----t---+---;----;----;---i-----1 ." S-1 (API HC) 10/03/17 9:29 AM Liquid Neat 1 X :i:::::2 : S-3 (AP! Water) S-5 (T-40) 10/03/17 9:51 AM Liquid HCI X 10/03/17 9:01 AM Liquid Neat X :f S-6 (T-41) 10/03/17 9:05AM Liquid Neat X ~ Field Blank f EQ Blank Port 1 10/03/17 9:35AM Liquid HCI X 10/03/17 10:04AM Liquid HCI X 1 i / EQ Blank Port 2 10/03/17 10:26AM Liquid HCI X <:: :~ : Duplicate >>9< Trip Blank <:10: Temperature Blank 10/03/17 10/03/17 10/03/17 XXX Liquid HCI X XXX Liquid HCI 2 X Liquid 1 Relinquished by: Br~~ flvbbJlrJ? (J(9,,,,.JJ. rza~ :/ !Shipment Method: Date: Time: J(J.s/7 Received by: ! I Required Turnaround Time: D STD 10 Wk Days 0 5 Wk Days Notes: Oother _ _ __ D 2 Wk Days D 24 Hour r ...... .. . . Relinquished by:/ Date: Time: Received by (Laboratory): CoolerTemp, Gl~P:ackagii:(~hec:k!3oJ(Bel~wv: :: . " " . , , Level ll: Standard QC jTRRP-Checklist ~~gtid Dl4 ',' / > ' ll\t&: f' . l"ililt: .. . . .i r~~tj!t~b!lritto~j; ., ._. . ,~ ~ { : :_:'/,,., ., .. , . " ., . - i . " ". . ' ., .:" .. " ". ... f ..fl).l'/> . a4c1eure-esc 9-$035 . '. ' Note: Any changes must be made in writing once samples and coc Form have been submitted to ALS Laboratory Group. Level III: Std QC+ Raw Data Level IV: SW846 CLP-Like ITRRP Level IV Other: Copyright 2009 by ALS Laboratory Group Page 25 of27 HFNA-000001800 EPA Inspection Report - Page 1139 of 1969 Seal Broken Sy: Page 26 of27 HFNA-000001801 EPA Inspection Report - Page 1140 of 1969 Use of this system constitutes your agreement to the service conditions in the current FedExSer.Jice Guide, available on fedex.com. FedEx wlll not be responsible for any claim in excess of $100 per package, whether the result of loss, damage1 delay, non-delivery, m!sdelivery, or misinformation, unless you declare a higher value, pay an additional charge, document your actual loss and file a timely claim. Limitations found in the current FedEx Service Guide apply. Your right to recover from FedEx for any loss, including Intrinsic value of the package, loss of sales, income interest, profit, attorney's fees, costs, and other forms of damage whether direct, !ncidental, consequential, or special is limited to the greater ot $100 or the authorized declared value. Recovery cannot exceed actual documented loss. Maximum for items of extraordinary value is $1,000, e.g. jewelry, precious metals, negotiable instruments and other items listed in our Service Gulde. Written claims must be fl!ed within strict time !lmits, see current FedEx Service Guide . ~fter pnnt111g this label: CONSIGNEE COPY PLEASE PLACE IN FRONT OF POUCH i. Fo;d ~t,e dnii:Ci page along the harizon!ei line. 2. Place label in 5hipping pouch :,rid affix it tc your shipment en)> fw~ d"" OJ -a Q c.o (,;) Q 00 G) 01 c.o 0 Al ~ .s:,. )> Page 27 of27 HFNA-000001802 EPA Inspection Report - Page 1141 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 October 12, 2017 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling (EOL) Dear Gabriela, Work Order: HS17100324 ALS Environmental received 4 sample(s) on Oct 05, 2017 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, Generated By: Jumoke.Lawal Nicole Edwards Project Manager Right Solutions Right Partnu www.a!sg!obaLcom Pagel of25 HFNA-000001803 EPA Inspection Report - Page 1142 of 1969 ALS Group USA, Corp Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100324 lab Samp ID HS17100324-01 HS17100324-02 HS17100324-03 HS17100324-04 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Matrix Liquid Liquid Liquid Liquid Date: 12-0ct-17 SAMPLE SUMMARY TagNo Collection Date 03-0ct-2017 09:29 03-0ct-2017 09:51 03-0ct-2017 09:01 03-0ct-2017 09:05 Date Received 05-0ct-2017 08:25 05-0ct-2017 08:25 05-0ct-2017 08:25 05-0ct-2017 08:25 Hold D D D D Page 2 of25 HFNA-000001804 EPA Inspection Report - Page 1143 of 1969 ALS Group USA, Corp Dale: 12-0cl-17 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100324 Work Order Comments CASE NARRATIVE The analysis for Specific Gravity was subcontracted lo ALS Environmental in Holland, Ml. Final report attached. Page 3 of25 HFNA-000001805 EPA Inspection Report - Page 1144 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (API HC) 03-0ct-2017 09:29 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS Miscellaneous Analysis See Attached Method:NA 0 REPORT LIMIT Date: 12-0ct-17 ANALYTICAL REPORT Work0rder:HS17100324 Lab ID:HS17100324-01 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED 12-0ct-2017 09:05 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of25 HFNA-000001806 EPA Inspection Report - Page 1145 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 03-0ct-2017 09:51 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS Miscellaneous Analysis See Attached Method:NA 0 REPORT LIMIT Date: 12-0ct-17 ANALYTICAL REPORT Work0rder:HS17100324 Lab ID:HS17100324-02 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED 12-0ct-2017 09:05 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of25 HFNA-000001807 EPA Inspection Report - Page 1146 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 03-0ct-2017 09:01 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS Miscellaneous Analysis See Attached Method:NA 0 REPORT LIMIT Date: 12-0ct-17 ANALYTICAL REPORT Work0rder:HS17100324 Lab ID:HS17100324-03 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED 12-0ct-2017 09:05 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of25 HFNA-000001808 EPA Inspection Report - Page 1147 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-6 (T-41) 03-0ct-2017 09:05 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS Miscellaneous Analysis See Attached Method:NA 0 REPORT LIMIT Date: 12-0ct-17 ANALYTICAL REPORT Work0rder:HS17100324 Lab ID:HS17100324-04 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED 12-0ct-2017 09:05 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of25 HFNA-000001809 EPA Inspection Report - Page 1148 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100324 Sample ID Client Samp ID Collection Date TCLP Date Batch ID R303247 Test Name : SUBCONTRACTED ANALYSIS HS17100324-01 HS17100324-02 HS17100324-03 HS17100324-04 S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) 03 Oct 2017 09:29 03 Oct 2017 09:51 03 Oct 2017 09:01 03 Oct 2017 09:05 Date: 12-0ct-17 DATES REPORT Prep Date Analysis Date DF Matrix: Liquid 12 Oct 2017 09:05 12 Oct 2017 09:05 12 Oct 2017 09:05 12 Oct 2017 09:05 Page 8 of25 HFNA-000001810 EPA Inspection Report - Page 1149 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100324 Date: 12-0ct-17 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND 0 p R s u Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SOL TRRP Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL/SOL Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Page 9 of25 HFNA-000001811 EPA Inspection Report - Page 1150 of 1969 ALS Group USA, Corp Agency Arkansas California Illinois Kentucky Louisiana North Carolina North Dakota Oklahoma Texas Date: 12-0ct-17 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number 17-027-0 2919 2016-2018 004112 123043 03087 2017-2017 624-2017 R193 2017-2017 2017-088 T104704231-17-19 Expire Date 27-Mar-2018 31-Jul-2018 09-May-2018 30-Apr-2018 30-Jun-2018 31-Dec-2017 30-Apr-2018 31-Aug-2018 30-Apr-2018 Page 10 of25 HFNA-000001812 EPA Inspection Report - Page 1151 of 1969 ALS Group USA, Corp Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17100324 Lab Sarnp ID HS17100324-01 HS17100324-02 HS17100324-03 HS17100324-04 Client Sample ID S-1 (API HG) S-3 (API Water) S-5 (T-40) S-6 (T-41) Action Login Login Login Login Date 10/6/2017 11:10:28 AM 10/6/2017 11:10:28 AM 10/6/2017 11:10:28 AM 10/6/2017 11:10:28 AM Person CL CL CL CL Date: 12-0ct-17 SAMPLE TRACKING New Location Sub Sub Sub Sub Page 11 of25 HFNA-000001813 EPA Inspection Report - Page 1152 of 1969 ALS Group USA, Corp Client Name: Work Order: Navajo Refining HS17100324 Date/Time Received: Received by: Date: 12-0ct-17 Sample Receipt Checklist 05-0ct-2017 08:25 JRM Checklist completed by: Cesar A. Lira 6-0ct-2017 -e,:-S,-ig_n_a,-tu-re--------.---,D=-a..,.t_e_ _ Reviewed by: Nicole Edwards eSignature 9-0ct-2017 Date Matrices: Carrier name: Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Chain of custody present? Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? TX1005 solids received in hermetically sealed vials? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler( s )/Kit( s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ .8c/3.1c UC/C tyrofoam cooler 10/05/2017 1900 Yes ;# Yes D Yes D No D No D No D No D No D No D No D No D No D No D No D No D No No D No D D Not Present D Not Present Not Present ~ N/A ~ IR11 No VOA vials submitted N/A ~ N/A ~ Login Notes: fsamples refrigerated prior to login. Client Contacted: Date Contacted: Person Contacted: Contacted By: Comments: Regarding: Corrective Action: Page 12 of25 HFNA-000001814 EPA Inspection Report - Page 1153 of 1969 A Enuironmental pJfcha' .s.,e.:,o.r..t.i.~i-' wi)riiorcier ~P:rripa~(Naine Navajo Refining Company LLC Tyler Turner Gabi Combs P.O. Box 159 ::/<:> 9ifY.1!5tatel~ip Artesia, NM 88211-0159 . .. Phone (575) 748-3311 r >> > > F~~ (575) 746-5451 .....e<;.M.a11<.A:dd.r<e:s<s>.ttume.r.am@gmail.com . . .. ..-.. . . ........ . Gabnela. Combs'""hol!llvf,ronber.com Chain of Custody Form I Page _1_ I of --1.__ O Cincinnati, OH +1 513 733 5336 D Everett, WA +1425 356 D 2600 D +1616 3996070 Holland, Ml D +1 281 530 5656 Houston, TX D Middletown, PA +1 717 944 5541 D +1801256 Salt Lake City, UT 7700 D Spring City, PA +1610 948 D 4903 ALS Project M~nager: Erica Padilla Work Order#: ....... PfoJee:t:111tormatfon .. ... < ParameterlMetnc:;d REfoifo:sttor.Anah;sit{ . //Pr6j~cfNa,rie BWON Monthly Sampling (EOL) "' Specific Gravity -----+-'4--------------------------1 : >p~~J~tjtr-i~~i a < BiffT:o Company Holly Frontier Navajo Refining LLC .o. - I 501 East Main HS17100324 >j:::. Navajo Refining Company > Cii:y)SfafolZii> Artesia, New Mexico 88210 ....... ............ }iio~~ cs15> 14a.3311 . .....;;,.;;~ L > : : '':'~ (575) 746-5451 ... .....cc.....c... >>.e.:.;M.:.a.1.1:.Ad.:.a.:.rn.:.s.s.Suzanne.Aguilar@hollyfrontier.com :..J BWON Monthly Sampling (EOL) - II 1111111111111111 IIIIII -- No/ .. :............. s..~.m.:.P..l.e. o..e.s..t.n. ;P..u.o..n.. .. . . . .. ri;;t.. . >: <t /: ,~~'.". . 1. Thno ... .u"~ . . >.>N.i(itr:U C. >.>p.re..s,.........iii/t:l!~::s\>. ../. . >i::i .; < .. ,,. ~ : ..:.: I=. 1 . . . >:r.. >:V j. >7>> r. . 1.:.:c ,'...J..i./ .: :.:. j . . Rold . . I ... S-1 (API HC) 10/03/17 9:29AM liquid Neat X [ { S-3 (API Water) 10/03/17 9;51 AM Liquid Neat X , <:( S-5 (T-40) i >,( S-6 (T-41) 10/03/17 9:01 AM Liquid Neat X 10/03/17 9:05AM Liquid Neat X rrt~r(s)::sr~?tf:s~f~Ifs~ !Required Turnaround Time: Oother _ _ __ .. JShipment Method: 0 STD 10 Wk Days 0 5 Wk Days 0 2 Wk Days O 24 Hour Relinquished by: lfri!<Ry HvJ6,;,rJI ,,;r:_ .. 1'1. ~..f!,:._,./? .I Date: /O.J.{7 Time: 'lfJ()O fM Received by: Notes: Relinquished by: / Date: Time: I/5 /!? 0 ~ ::;.. S Received by (Laboratory): .::J;v..,1 Cl,')Olet1'e111p; :a~ S:,:atj~ilgEl:(Cf!ei;k 13~~ EIE!~Ow).: > / , . LevelII: Standard QC .. .. :. TRRP-Checklist TRRP Level IV Note: Any changes must be made in writing once samples and COC Form have been submitted to ALS Laboratory Group. Page 13 of 25 Copyright 2009 by ALS Laboratory Group HFNA-000001815 EPA Inspection Report - Page 1154 of 1969 Use of this system constitutes your agreement to the service conditions in the current FedEx Service Guide, available on fedex,com. FedEx will not be responsible for any claim in excess of $100 per package, whether the result of loss, damage, delay, non--de!ivery, misde!ivery, or misinformation, unlessvou declare a higher value, pay an additional charge, document your actual loss and file a timely dalm. limitations found tn the current FedEx Service Guide apply. Your right to recover from FedEx for any loss, induding intrinsic value of the package, loss ot sales, income interest, profit, attorney's fees, cost:., and other forms of damage whether direct, incidental, consequential, or special is limited to the greater of $100 or the authorized dedared value. Recovery cannot exceed actual documented loss. Maximum for items of extraordinary value ;s $1,000, e.g. jewelry, precious metals, negotiable instruments and other items listed in our Service Guide. Written claims must be filed within strict time limits, see current FedEx Service Guide. ft.Jter printing this labei. CONSIGNEE COPY PLEASE PLACE IN FRONT OF POUCH '1. Foh::i ~ile p1 t. 1i1::d p~ge a:or1g the honzonlal !in~, 2. Place label in shipping pouch and affix it to your shipment. ---- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ > I"':,:, """' ....... DJ 0 U) w CJ) 0 G) ClO (J'I U) 0 ~ ~ ~ "0 ' = = =~ Page 14 of 25 540C3/PB99/727F HFNA-000001816 EPA Inspection Report - Page 1155 of 1969 Seal Broken By: JM Page 15 of 25 HFNA-000001817 EPA Inspection Report - Page 1156 of 1969 12-0ct-2017 Erica Howard ALS Environmental 10450 Stancliff Rd Suite 210 Houston, TX 77099 Re: HS17100324 Dear Erica, Work Order: 1710534 ALS Environmental received 4 samples on 07-0ct-2017 09:30 AM for the analyses presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Sample results are compliant with industry accepted practices and Quality Control results achieved laboratory specifications. Any exceptions are noted in the Case Narrative, or noted with qualifiers in the report or QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained from ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. The total number of pages in this report is 10. If you have any questions regarding this report, please feel free to contact me. Sincerely, Electronically approved by: Chad Whelton Chad Whelton Project Manager Certificate No: MN 998501 Report of Laboratory Analysis HFNA-000001818 EPA Inspection Report - Page 1157 of 1969 ALS Group, USA Client: Project: Work Order: ALS Environmental HS17100324 1710534 Lab Samp ID Client Sample ID 1710534-01 HS17100324-0l 1710534-02 HS l 7100324-02 1710534-03 HS17100324-03 1710534-04 HS17100324-04 Date: 12-0ct-17 Matrix Liquid Liquid Liquid Liquid Work Order Sample Summary Tag Number S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Collection Date 10/3/2017 09:29 10/3/2017 09:51 10/3/2017 09:01 10/3/2017 09:05 Date Received 10/7/2017 09:30 10/7/2017 09:30 10/7/2017 09:30 10/7/2017 09:30 Hold Page 17 of25 Sample Summary Pagel of 1 HFNA-000001819 EPA Inspection Report - Page 1158 of 1969 ALS Group, USA Client: Project: WorkOrder: ALS Environmental HS17100324 1710534 Date: 12-0ct-17 QUALIFIERS, ACRONYl\1S, UNITS Qualifier ** a B E H J ND 0 p R s u X Description Value exceeds Regulatory Limit Estimated Value Analyte is non-accredited Anal)1e detected in the associakd Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte is present at an estimated concentration between the MDL and Report Limit Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPD above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL Analyte was detected in the Method Blank between the MDL and Repo1ting Limit, sample results may exhibit background or reagent contamination at the observed level. Acronvm Description DUP Method Duplicate LCS Laboratory Control Sample LCSD Laboratory Control Sample Duplicate LOD Limit of Detection (see MDL) LOQ Limit ofQuantitation (see PQL) MBLK Method Blank MDL Method Detection Limit MS Matrix Spike MSD Matrix Spike Duplicate PQL Practical Quantitation Limit RPD Relative Percent Difference TDL Target Detection Limit TNTC Too Numerous To Count A APHA Standard Methods D ASTM E EPA SW SW-846 Update III Units Reported none Description Page 18 of25 QFPage 1 o/1 HFNA-000001820 EPA Inspection Report - Page 1159 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS17100324 HS 17100324-01 10/3/2017 09:29 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 12-0ct-l 7 Result Qual Report Limit WorkOrder: 1710534 Lab ID: 1710534-01 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.980 D5057-90 none Analyst: RZM 10/11/2017 04:38 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 19 of25 Analytical Results Page l of 4 HFNA-000001821 EPA Inspection Report - Page 1160 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS17100324 HS l 7100324-02 10/3/2017 09:51 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 12-0ct-l 7 Result Qual Report Limit WorkOrder: 1710534 Lab ID: 1710534-02 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.00 none Analyst: RZM 10/11/2017 04:38 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 20 of25 Analytical Results Page 2 of 4 HFNA-000001822 EPA Inspection Report - Page 1161 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS17100324 HS l 7100324-03 10/3/2017 09:01 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 12-0ct-l 7 Result Qual Report Limit WorkOrder: 1710534 Lab ID: 1710534-03 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.13 none Analyst: RZM 10/11/2017 04:38 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 21 of25 Analytical Results Page 3 of 4 HFNA-000001823 EPA Inspection Report - Page 1162 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS17100324 HS l 7100324-04 10/3/2017 09:05 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 12-0ct-l 7 Result Qual Report Limit WorkOrder: 1710534 Lab ID: 1710534-04 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.13 none Analyst: RZM 10/11/2017 04:38 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 22 of25 Analytical Results Page 4 of 4 HFNA-000001824 EPA Inspection Report - Page 1163 of 1969 ALS Group, USA Client: ALS Environmental Work Order: 1710534 Project: HS17100324 Date: 12-0ct-17 QC BATCH REPORT Batch ID: R222011 Instrument ID WETCHEM Method: D5057-90 DUP Sample ID: 1710534-02A DUP Client ID: HS17100324-02 Run ID: WETCHEM_1710110 Units: none SeqNo: 4692983 Analysis Date: 10/11/2017 04:38 PM Prep Date: OF: 1 Analyte Result SPK Ref PQL SPKVal Value %REC Control Limit RPO Ref Value %RPO RPO Limit Qual Specific Gravity 1.006 0 0 0 0 0-0 1.003 0.279 20 The following samples were analyzed in this batch: 1710534-01A 171 0534-04A 1710534-02A 1710534-03A Note: See Qualifiers Page for a list of Qualifiers and their explanation. Page 23 of25 QC Page: 1 of 1 HFNA-000001825 EPA Inspection Report - Page 1164 of 1969 10450 St:andlff Rd, Ste 210 Houston, TX. 77099 T: +1 281 530 5656 F: +1 261 530 5687 www.alsglobal.com Subcontract Chain of Custody COC ID: 7733 SUBCONTRACT TO: ALS Laboratory Group 3352 UBth Ave. Holland, MI 494249263 Phone: +1 616 399 6070 CUSTOMER INFORMATION: Company: ALS Houston Contact:: Address: _?h__oj1e: Erica Howard 10450 Stancliff Rd, Ste 210 +1 281 530 5656 E:_maH: Alternate Contact Email: _erlca. l}o'!"ard@alsglobal ,com Jumi:Jke M. Lawal jumoke.lawal@alsglobal.com ~NVOICE . INFORMATION: Company: ALS Houston Contact Address: Phone: R, .ec f e r e- n c- e : TSR.: Accounts Payable 10450 Standlff Rd, Ste 210 + 1 2"8"" 1 - 5c 3 0 < 5 <" 6 5 6 H. S1-7 1.0..0-3.2. 4 Houston House Acct 1. HS17100324-01 S-1 (API HC) Specific Gravity sub to ALS Holland 2. HS17100324-02 S-3 (API :Wat~r) Specific Gravity sub to ALS-Holland 3. HS17100324-03 S-5 (T-40) Specific Gravity Sub to ALS Holland 4. HS17100324-04 s-6 {T-41) Specific Gravity sub to ALS Holland Uquld Liquid UquldUquld 03 Ocl: 2017 09:29 12 Oct 2017 03 Oct: 2017 09:51 12 Oct 2017 03 Oct: 2017 09:01 12 Oct 2017 03 Oct: 2017 09:05 12 act 2017 Comments: Please analyze for l:he analysis listed above. Send report to the emails shown above. QC level: STD (Laboratory Standard QC: method blank. and LCS required) :::::::"::, By,~1Y t: Cooler ID(s): Date/Time: Date/T]me: :>el-- c;4 2<J '[7 / {A) 1al1 l \] 093 a Temperature(s): <; f2'"L l-2-: t. HFNA-000001826 EPA Inspection Report - Page 1165 of 1969 ALS Group, USA Client Name: Work Order: ALS - HOUSTON 1710534 Sample Receipt Checklist Date/Time Received: Received by: 07-0ct-17 09:30 Checklist completed by _LlULK</ '-c;',e'-""" 09-0ct-17 ------------~----- e Signature Date Matrices: Carrier name: Reviewed by: eSignature Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Yes [i,] Yes [i,] Yes No Not Present D No Not Present D No Not Present [i,] Chain of custody present? Yes [i,] No Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Yes [i,] Yes [i,] Yes [i,] Yes [i,] No D No D No D No Sufficient sample volume for indicated test? Yes [i,] No All samples received within holding time? Yes [i,] No Container/Temp Blank temperature in compliance? Yes [i,] No Sample(s) received on ice? Temperature(s)/Thermometer(s): Yes [i,] No Cooler(s)/Kit(s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? rfo/9/2017 10:43:40 AM Yes No VOA vials submitted [i,] Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Yes Yes D No N/A No D N/A Login Notes: 09-0ct-17 Date Client Contacted: Contacted By: Comments: Date Contacted: Regarding: Person Contacted: CorrectiveAction: ~agc=of'.15~ SRC Page 1 of 1 HFNA-000001827 EPA Inspection Report - Page 1166 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 November 10, 2017 Tyler Turner (Cons. Aqua Microbics) Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling (EOL) Dear Tyler, Work Order: HS17110177 ALS Environmental received 9 sample(s) on Nov 03, 2017 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, Generated By: Dayna.Fisher Nicole Edwards Project Manager Right Solutions Right Partnu www.a!sg!obaLcom Pagel of26 HFNA-000001828 EPA Inspection Report - Page 1167 of 1969 ALS Group USA, Corp Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110177 lab Samp ID HS17110177-01 HS17110177-02 HS17110177-03 HS17110177-04 HS17110177-05 HS17110177-06 HS17110177-07 HS17110177-08 HS17110177-09 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Matrix Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Date: 1O-Nov-17 SAMPLE SUMMARY TagNo Collection Date 02-Nov-2017 09:55 02-Nov-2017 09: 18 02-Nov-2017 08:45 02-Nov-2017 08:50 02-Nov-2017 09:06 02-Nov-2017 09:41 02-Nov-2017 09:41 02-Nov-2017 00:00 02-Nov-2017 00:00 Date Received 03-Nov-2017 09: 1O 03-Nov-2017 09: 1O 03-Nov-2017 09: 1O 03-Nov-2017 09: 1O 03-Nov-2017 09: 1O 03-Nov-2017 09: 1O 03-Nov-2017 09: 1O 03-Nov-2017 09: 1O 03-Nov-2017 09: 1O Hold D D D D D D D D D Page 2 of26 HFNA-000001829 EPA Inspection Report - Page 1168 of 1969 ALS Group USA, Corp Dale: 1O-Nov-17 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110177 GCMS Volatiles by Method SW8260 Batch ID: R305006,R305099 CASE NARRATIVE The test results meet requirements of the current NELAP standards, state requirements or programs where applicable. Batch ID: R304921 Sample ID: S-5 (T-40) (HS17110177-03}, S-6 (T-41) (HS17110177-04) Lowest practical dilution for HS17110177-03, 04 due to sample matrix. Surrogates failure due to sample matrix. Page 3 of26 HFNA-000001830 EPA Inspection Report - Page 1169 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (API HC) 02-Nov-2017 09:55 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 5.5 98.0 101 99.0 99.9 Method:SW8260 0.025 REPORT LIMIT 0.25 70-126 73-120 70-130 82-121 Date: 1O-Nov-17 ANALYTICAL REPORT Work0rder:HS17110177 Lab ID:HS17110177-01 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 07-Nov-2017 13:04 07-Nov-2017 13:04 07-Nov-2017 13:04 07-Nov-2017 13:04 07-Nov-2017 13:04 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of26 HFNA-000001831 EPA Inspection Report - Page 1170 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 02-Nov-2017 09: 18 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 1.5 91.9 99.4 93.7 103 Method:SW8260 0.030 REPORT LIMIT 0.25 70-126 82-124 77-123 82-127 Date: 1O-Nov-17 ANALYTICAL REPORT Work0rder:HS17110177 Lab ID:HS17110177-02 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: PC 08-Nov-2017 20:42 08-Nov-2017 20:42 08-Nov-2017 20:42 08-Nov-2017 20:42 08-Nov-2017 20:42 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of26 HFNA-000001832 EPA Inspection Report - Page 1171 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 02-Nov-2017 08:45 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.024 97.3 103 63.2 96.8 Method:SW8260 0.024 s REPORT LIMIT 0.24 70-126 73-120 70-130 82-121 Date: 1O-Nov-17 ANALYTICAL REPORT Work0rder:HS17110177 Lab ID:HS17110177-03 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 07-Nov-2017 13:28 07-Nov-2017 13:28 07-Nov-2017 13:28 07-Nov-2017 13:28 07-Nov-2017 13:28 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of26 HFNA-000001833 EPA Inspection Report - Page 1172 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-6 (T-41) 02-Nov-2017 08:50 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.025 98.5 103 60.4 95.3 Method:SW8260 0.025 s REPORT LIMIT 0.25 70-126 73-120 70-130 82-121 Date: 1O-Nov-17 ANALYTICAL REPORT Work0rder:HS17110177 Lab ID:HS17110177-04 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 07-Nov-2017 13:51 07-Nov-2017 13:51 07-Nov-2017 13:51 07-Nov-2017 13:51 07-Nov-2017 13:51 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of26 HFNA-000001834 EPA Inspection Report - Page 1173 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Field Blank 02-Nov-2017 09:06 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 91.5 94.5 95.4 99.7 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 1O-Nov-17 ANALYTICAL REPORT Work0rder:HS17110177 Lab ID:HS17110177-05 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 08-Nov-2017 19:22 08-Nov-2017 19:22 08-Nov-2017 19:22 08-Nov-2017 19:22 08-Nov-2017 19:22 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 8 of26 HFNA-000001835 EPA Inspection Report - Page 1174 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 1 02-Nov-2017 09:41 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 89.9 99.3 93.5 102 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 1O-Nov-17 ANALYTICAL REPORT Work0rder:HS17110177 Lab ID:HS17110177-06 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 08-Nov-2017 19:48 08-Nov-2017 19:48 08-Nov-2017 19:48 08-Nov-2017 19:48 08-Nov-2017 19:48 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 9 of26 HFNA-000001836 EPA Inspection Report - Page 1175 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 2 02-Nov-2017 09:41 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.00061 93.5 99.2 94.2 102 Method:SW8260 J 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 1O-Nov-17 ANALYTICAL REPORT Work0rder:HS17110177 Lab ID:HS17110177-07 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 08-Nov-2017 20:15 08-Nov-2017 20:15 08-Nov-2017 20:15 08-Nov-2017 20:15 08-Nov-2017 20:15 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 10 of26 HFNA-000001837 EPA Inspection Report - Page 1176 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Duplicate 02-Nov-2017 00:00 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 1.4 91.4 101 93.1 105 Method:SW8260 0.030 REPORT LIMIT 0.25 70-126 82-124 77-123 82-127 Date: 1O-Nov-17 ANALYTICAL REPORT Work0rder:HS17110177 Lab ID:HS17110177-08 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: PC 08-Nov-2017 21 :09 08-Nov-2017 21:09 08-Nov-2017 21:09 08-Nov-2017 21:09 08-Nov-2017 21:09 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 11 of26 HFNA-000001838 EPA Inspection Report - Page 1177 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Trip Blank 02-Nov-2017 00:00 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 98.1 103 93.7 107 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 1O-Nov-17 ANALYTICAL REPORT Work0rder:HS17110177 Lab ID:HS17110177-09 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 07-Nov-2017 20:11 07-Nov-2017 20:11 07-Nov-2017 20:11 07-Nov-2017 20:11 07-Nov-2017 20:11 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 12 of26 HFNA-000001839 EPA Inspection Report - Page 1178 of 1969 ALS Group USA, Corp Client: Navajo Refining Company Project: BWON Monthly Sampling (EOL) WorkOrder: HS17110177 Batch ID: 2066 SamplD HS17110177-01 HS17110177-03 HS17110177-04 Method: VOLATl LES BY SW8260C Container Sample Wt/Vol 4.986 (g) 5.129 (g) 5.035 (g) Final Volume 5 (ml) 5 (ml) 5 (ml) Weight Factor 0.97 0.99 Container Type Bulk (5030B) Bulk (5030B) Bulk (5030B) Date: 1O-Nov-17 WEIGHT LOG Page 13 of26 HFNA-000001840 EPA Inspection Report - Page 1179 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110177 Sample ID Client Samp ID Collection Date TCLP Date Batch ID R304921 Test Name : VOLATILES BY SW8260C HS17110177-01 HS17110177-03 HS17110177-04 S-1 (API HC) S-5 (T-40) S-6 (T-41) 02 Nov 2017 09:55 02 Nov 2017 08:45 02 Nov 2017 08:50 Batch ID R305006 Test Name: VOLATILES- SW8260C HS17110177-09 Trip Blank 02 Nov 2017 00:00 Batch ID R305099 Test Name: VOLATILES - SW8260C HS17110177-02 HS17110177-05 HS17110177-06 HS17110177-07 HS17110177-08 S-3 (API Water) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate 02 Nov 2017 09:18 02 Nov 2017 09:06 02 Nov 2017 09:41 02 Nov 2017 09:41 02 Nov 2017 00:00 Date: 1O-Nov-17 DATES REPORT Prep Date Analysis Date DF Matrix: Liquid 07 Nov 2017 13:04 50 07 Nov 2017 13:28 50 07 Nov 2017 13:51 50 Matrix: Liquid 07 Nov 2017 20:11 Matrix: Liquid 08 Nov 2017 20:42 50 08 Nov 2017 19:22 08 Nov 2017 19:48 08 Nov 2017 20:15 08 Nov 2017 21 :09 50 Page 14 of26 HFNA-000001841 EPA Inspection Report - Page 1180 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110177 Date: 1O-Nov-17 QC BATCH REPORT Batch ID: R304921 Instrument: VOA8 Method; SW8260 MBLK Client ID: Analyte Sample ID: MBLKW1-110717 Units: ug/Kg Analysis Date: 07-Nov-2017 08:36 Run ID: VOA8_304921 SeqNo: 4297273 PrepDate: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 25 2464 2492 2503 2439 250 0 2500 0 2500 0 2500 0 2500 0 98.6 76 - 125 0 99.7 83- 120 0 100 80 - 119 0 97.6 81 - 118 LCS Client ID: Analyte Sample ID: VLCSW1-110717 Units: ug/Kg Analysis Date: 07-Nov-2017 07:50 Run ID: VOA8_304921 SeqNo: 4297272 PrepDate: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 52.97 5.0 50 51.86 0 50 50.99 0 50 52.15 0 50 49.9 0 50 0 106 75 - 124 0 104 76 - 125 0 102 83 - 120 0 104 80 - 119 0 99.8 81 - 118 MS Client ID: Analyte Sample ID: HS17110124-04MS Units: ug/Kg Analysis Date: 07-Nov-2017 10:59 Run ID: VOA8_304921 SeqNo: 4297878 Prep Date: OF: 1000 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 50540 40660 44830 42190 43790 4400 0 0 0 0 43500 43500 43500 43500 43500 5900 0 0 0 0 103 93.5 103 97.0 101 70 - 130 70 - 126 72 - 120 70 - 130 82 - 121 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 15 of26 HFNA-000001842 EPA Inspection Report - Page 1181 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110177 Date: 1O-Nov-17 QC BATCH REPORT Batch ID: R304921 Instrument: VOA8 Method; SW8260 MSD Client ID: Analyte Sample ID: HS17110124-04MSD Units: ug/Kg Analysis Date: 07-Nov-2017 11:23 Run ID: VOA8_304921 SeqNo: 4297879 PrepDate: OF: 1000 Result PQL SPKVal SPK Ref Value %REC Control Limit RPO Ref RPO Value %RPO Limit Qual Benzene 47800 4400 43500 5900 96.3 70 - 130 50540 5.57 30 Surr: 1,2-0ichloroethane-d4 40950 0 43500 0 94.1 70 - 126 40660 0. 701 30 Surr: 4-Bromofluorobenzene 45730 0 43500 0 105 72 - 120 44830 1.98 30 Surr: Dibromofluoromethane 42240 0 43500 0 97.1 70 - 130 42190 0.136 30 Surr: Toluene-dB 44120 0 43500 0 101 82 - 121 43790 0. 759 30 The following samples were analyzed in this batch: ~f_s_17_1_1_01_7_7_-0_1_ _ _H_s_1_7_1_10_1_7_7-_o_3_ _ _H_s_1_7_11_0_17_7_-_o4_ _ _ _ _ _ _ _ _ _ _ _ _~ Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 16 of26 HFNA-000001843 EPA Inspection Report - Page 1182 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110177 Date: 1O-Nov-17 QC BATCH REPORT Batch ID: R305006 Instrument: VOA1 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-171107 Units: ug/L Analysis Date: 07-Nov-2017 13:00 Run ID: VOA1 - 305006 Result PQL SPKVal SeqNo: 4299137 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 47.82 0 50 49.87 0 50 47.54 0 50 52.66 0 50 0 95.6 70 - 123 0 99.7 83 - 122 0 95. 1 73 - 126 0 105 81 - 119 LCS Client ID: Analyte Sample ID: VLCSW-171107 Units: ug/L Analysis Date: 07-Nov-2017 12:07 Run ID: VOA1 - 305006 Result PQL SPKVal SeqNo: 4299136 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 47.56 5.0 50 50.76 0 50 52.41 0 50 47.62 0 50 49.06 0 50 0 95.1 74 - 120 0 102 70 - 130 0 105 83 - 122 0 95.2 73 - 126 0 98. 1 81 - 119 MS Client ID: Analyte Sample ID: HS17101542-06MS Units: ug/L Analysis Date: 07-Nov-2017 15:16 Run ID: VOA1 - 305006 Result PQL SPKVal SeqNo: 4299139 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 63.52 5.0 50.69 0 50.06 0 48.68 0 47.26 0 50 9.765 108 70 - 127 50 0 101 70 - 126 50 0 100 82 - 124 50 0 97.4 77 - 123 50 0 94.5 82 - 127 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 17 of26 HFNA-000001844 EPA Inspection Report - Page 1183 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110177 Date: 1O-Nov-17 QC BATCH REPORT Batch ID: R305006 Instrument: VOA1 Method; SW8260 MSD Client ID: Analyte Sample ID: HS17101542-06MSD Units: ug/L Analysis Date: 07-Nov-2017 15:43 Run ID: VOA1 - 305006 Result PQL SPKVal SeqNo: 4299140 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 52.86 5.0 46.2 0 51.45 0 47.97 0 51.05 0 The following samples were analyzed in this batch: S17110177-09 50 9.765 86.2 70 - 127 63.52 18.3 20 50 0 92.4 70 - 126 50.69 9.26 20 50 0 103 82 - 124 50.06 2.75 20 50 0 95.9 77 - 123 48.68 1.48 20 50 0 102 82 - 127 47.26 7.71 20 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 18 of26 HFNA-000001845 EPA Inspection Report - Page 1184 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110177 Date: 1O-Nov-17 QC BATCH REPORT Batch ID: R305099 Instrument: VOA1 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-171108 Units: ug/L Analysis Date: 08-Nov-2017 14:55 Run ID: VOA1 - 305099 Result PQL SPKVal SeqNo: 4301656 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 46.76 0 50 47.67 0 50 47. 18 0 50 51.96 0 50 0 93.5 70 - 123 0 95.3 83 - 122 0 94.4 73 - 126 0 104 81 - 119 LCS Client ID: Analyte Sample ID: VLCSW-171108 Units: ug/L Analysis Date: 08-Nov-2017 14:02 Run ID: VOA1 - 305099 Result PQL SPKVal SeqNo: 4301655 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 48.33 5.0 50 48. 17 0 50 50.05 0 50 49.03 0 50 48.92 0 50 0 96.7 74 - 120 0 96.3 70 - 130 0 100 83 - 122 0 98. 1 73 - 126 0 97.8 81 - 119 MS Client ID: Analyte Sample ID: HS17110166-15MS Units: ug/L Analysis Date: 08-Nov-2017 17:08 Run ID: VOA1 - 305099 Result PQL SPKVal SeqNo: 4301661 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 81 .11 5.0 47.26 0 52.09 0 47.68 0 49.31 0 50 36.05 90.1 70 - 127 50 0 94.5 70 - 126 50 0 104 82 - 124 50 0 95.4 77 - 123 50 0 98.6 82 - 127 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 19 of26 HFNA-000001846 EPA Inspection Report - Page 1185 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110177 Date: 1O-Nov-17 QC BATCH REPORT Batch ID: R305099 Instrument: VOA1 Method; SW8260 MSD Client ID: Analyte Sample ID: HS17110166-15MSD Units: ug/L Analysis Date: 08-Nov-2017 17:35 Run ID: VOA1 - 305099 Result PQL SPKVal SeqNo: 4301662 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 79.32 5.0 45.62 0 51.46 0 47.63 0 49.28 0 The following samples were analyzed in this batch: S17110177-02 S17110177-08 50 36.05 86.5 70 - 127 81.11 2.24 20 50 0 91.2 70 - 126 47.26 3.52 20 50 0 103 82 - 124 52.09 1.2 20 50 0 95.3 77 - 123 47.68 0. 103 20 50 0 98.6 82 - 127 49.31 0.0597 20 HS17110177-05 HS17110177-06 HS17110177-07 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 20 of26 HFNA-000001847 EPA Inspection Report - Page 1186 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110177 Date: 1O-Nov-17 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND O P R S U Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL/SOL Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SOL TRRP Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Unit Reported mg/Kg mg/L Description Milligrams per Kilogram Milligrams per Liter Page 21 of26 HFNA-000001848 EPA Inspection Report - Page 1187 of 1969 ALS Group USA, Corp Agency Arkansas California Illinois Kentucky Louisiana North Carolina North Dakota Oklahoma Texas Date: 1O-Nov-17 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number 17-027-0 2919 2016-2018 004112 123043 03087 2017-2017 624-2017 R193 2017-2017 2017-088 T104704231-17-19 Expire Date 27-Mar-2018 31-Jul-2018 09-May-2018 30-Apr-2018 30-Jun-2018 31-Dec-2017 30-Apr-2018 31-Aug-2018 30-Apr-2018 Page 22 of26 HFNA-000001849 EPA Inspection Report - Page 1188 of 1969 ALS Group USA, Corp Client Name: Work Order: Navajo Refining HS17110177 Date/Time Received: Received by: Date: 1O-Nov-17 Sample Receipt Checklist 03-Nov-2017 09:10 JRM Checklist completed by: Raegen Giga eSignature 3-Nov-2017 Date Reviewed by: Nicole Edwards eSignature 1O-Nov-2017 Date Matrices: Carrier name: FedEx Priority Overnight Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Chain of custody present? Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? TX1005 solids received in hermetically sealed vials? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler( s )/Kit( s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ 1.8c/2.1 C uc/c ox 11/03/2017 15:39 Yes ;# Yes D Yes D No D No D No D No D No D No D No D No D No D No D No D No D No No D No D D Not Present D Not Present Not Present ~ N/A ~ IR 11 No VOA vials submitted N/A ~ N/A ~ Login Notes: Client Contacted: Date Contacted: Person Contacted: Contacted By: Comments: Regarding: Corrective Action: Page 23 of26 HFNA-000001850 EPA Inspection Report - Page 1189 of 1969 Chain of Custody Form I Page _1_ I of ___j__ D Cincinnati, OH +1 513 733 5336 D Everett, WA +1425356 D 2600 D + 1 616 399 6070 Holland, Ml D +1 281 530 5656 Houston, TX D Middletown, PA +1 717 944 5541 D +1801 266 Salt lake City, UT 7700 D Spring City, PA + 1 510 948 D 4903 Enuironmental ....cusfomef i11tonriatfon ALS Project Manager: Erica Padilla . <ProJec.t information . Work Order#: << ) Projec{~cifu.e BWON Monthly Sampling (EOL) ................... >A VOLATILES (8260) Benzene 1IH 1111111111111IH 11111111111111 :Ji~oj~c( N4~b~r - . . . . . . . . . . . >{Ct.iin~~ily t<lanie Navajo Refining Company LLC \BiliJi{oiripariy Holly Frontier Navajo Refining LLC >C Tyler Turner Gabi Combs . )n~oi~{4itt11. Susie Aguilar HS17110177 - Navajo Refining Company - P.O. Box 159 501 East Main :E: BWON Monthly Sampling (EOL) p: - : < \ lfvi~tatel~ip Artesia, NM 88211-0159 - - . . . ...l'.'(IV.fll'I (575) 748-3311 r.. .. :-:-: ._ .. I. ... . . ,,~.~. (575) 748-3311 H: . :::::: < F~x (575) 746-5451 - : . < : Fax (575) 746-5451 <:::> :M:;l:A:,;dc.:,::: tlurner.am@gmail.com .>>:M:: ~I~:;,;~:: S A 1 ""'h II f 1 .. ::ec aJ .". r~ss Gabrieia.Combs6'lhollvfrontiercom : : :~~. ~~ .~......~~s uzanne. gu1 ar\W o y ron ier.com ... . ... ,. :~;~rif~ . . . . . .. .. ,~~; :::: :>>: ::: ~~'.'.'"'.'.::' 0.-,~:"';y'I':'.!': :.. .> .:: . 1 } Date <<.> S-1 (API HC) 11/02/17 9:55AM Liquid B X C.,..:,..'-'-i-------------------l-----------i-----1----+-----+---i----l----+----,1---+---+--!----+--!----1------ 1 : S-3 (API Water) 11/02/17 9:18 AM Liquid 8,1 X ' :: S-5 (T-40) 11/02/17 8:45AM Liquid 8 X < ::: S-6 (T-41) S:: Field Blank 11!02/17 8:50AM Liquid 8 X 11/02/17 9:06AM Liquid 8,1 X ~ > EQ Blank Port 1 >{ EQ Blank Port 2 1{ Duplicate 11/02/17 9:41 AM Liquid 8,1 X 11/02/17 9:41 AM Liquid 8,1 X 11/02/17 XXX Liquid 8,1 X f Trip Blank lO Temperature Blank 11/02/17 11/02/17 XXX Liquid 8,1 Liquid 2 X 1 I .: ....... ....... . ::- "":t .....>.. ......... IJ'ate: Time: Received by: Required Turnaround Time: D STD 10 Wk Days 0 S Wk Days Notes: Dother _ _ __ D 2 Wk Days D 24 Hour 4:00 Relinquished by:f Date: Time: Received by (Laboratory): ' logged by (laboratory): Preservative Kl:)y: 1.-HCL 2-HN03 Date: 3H2S04 Time: 4-NaOH _,.,,--- ( / t,1..-. u.-..,17 Checked by (laboratory): . .C,~ ,""ll'.::.~io ,fJ4rrVf Cooler Temp. }.g- 5-Na2S203 s~NaHS04 7.other 8-4 degrees C 905035 Level II: Standard QC Level III: Std QC+ Raw Data Level IV: SW846 CLP-Like Other: TRRP-Checklis! TRRP Level IV Note: Any changes must be made in writing once samples and COC Form have been submitted to ALS laboratory Group. Copyright 2009 by ALS Laboratory Group Page 24 of26 HFNA-000001851 EPA Inspection Report - Page 1190 of 1969 Use of this system constitutes your agreement to the service conditions in the current FedEx Service Guide, available on fedex.com. FedEx will not be responsible for any claim in excess of $100 per package, V'lhether the result of loss, damage, delay, non~delivery, misdelivery, or misinformation, unless you declare a higher va!ue, pay an additional charge, document your actual !oss and flle a timely claim. Limitations found in the current FedEx Service Guide apply. Your right to recover from FedEx for any lms1 including intrinsic value of the pack.age, loss of sales, income interest1 profit, attorney's fees, costs, and other forms of damage whether direct, incidental, cons:equentia!, or special ls limlted tothe greater of $100 or the authorized declared value. Recovery cannot exceed actual documented !oss. Maximum for items of extraordinary value is $1,000, e.g. jewelry, precious metals, negotiable instruments and other items listed in our Service Guide. Written claims must be filed within strict time !imits1 see current FedEx Service Guide. After ptinting this !abel: CONSIGNEE COPY PLEASE PLACE IN FRONT OF POUCH 1 Fo!ct the printed page i:'long t~e hofr.:;:.mt2! l!:"le 2., Place labe,I iii shipping pow:h and affix \t to your shipment )> CD en G) ~ _.... ::< C <I> ............ >O :c~ ~! ..... 0 <.O (.,.) 0 co (J'I w 0 .i::,. <.O ..... '"Cl ;:o 0 ;:o =i -< 0 < m ;:o z >c::, c5 ::x:: G') -l CJ ~ ~ i m ~ ~ m I 8 ~ "!'I~ 2:! 0 <,) z 0 .<.... 0 c.:, ~ Page 25 of26 -l .... 0 ~! 0 :Z:,,Z r- ~rn~ ~ en o ~c UI 0 -<z"' c:, r ~s:i; en m m~"' "'~"' ~ m 55~~ z 0 U) C') ~ ~ r :z:,, ~ ,; ;;o rn w "'T1 0 i en HFNA-000001852 EPA Inspection Report - Page 1191 of 1969 ALS Enuironmental 10450 Stancliff Rd., Suite 210 Houston, Texas 77099 1;,1. +1 2a1 530 5656 Fax. +1 281 530 5887 ~ "" Date: !() t? Page 26 of26 HFNA-000001853 EPA Inspection Report - Page 1192 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 November 10, 2017 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling (EOL) Dear Gabriela, Work Order: HS17110184 ALS Environmental received 4 sample(s) on Nov 03, 2017 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, Generated By: Dayna.Fisher Nicole Edwards Project Manager Right Solutions Right Partnu www.a!sg!obaLcom Pagel of25 HFNA-000001854 EPA Inspection Report - Page 1193 of 1969 ALS Group USA, Corp Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110184 lab Samp ID HS17110184-01 HS17110184-02 HS17110184-03 HS17110184-04 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Matrix Liquid Liquid Liquid Liquid Date: 10-Nov-17 SAMPLE SUMMARY TagNo Collection Date 02-Nov-2017 09:55 02-Nov-2017 09: 18 02-Nov-2017 08:45 02-Nov-2017 08:50 Date Received 03-Nov-2017 09: 1O 03-Nov-2017 09: 1O 03-Nov-2017 09: 1O 03-Nov-2017 09: 1O Hold D D D D Page 2 of25 HFNA-000001855 EPA Inspection Report - Page 1194 of 1969 ALS Group USA, Corp Dale: 1O-Nov-17 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110184 Work Order Comments CASE NARRATIVE The analysis for Specific Gravity was subcontracted lo ALS Environmental in Holland, Ml. Final report attached. Page 3 of25 HFNA-000001856 EPA Inspection Report - Page 1195 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (API HC) 02-Nov-2017 09:55 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS Miscellaneous Analysis See Attached Method:NA 0 REPORT LIMIT Date: 1O-Nov-17 ANALYTICAL REPORT Work0rder:HS17110184 Lab ID:HS17110184-01 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED 1O-Nov-2017 13:56 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of25 HFNA-000001857 EPA Inspection Report - Page 1196 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 02-Nov-2017 09: 18 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS Miscellaneous Analysis See Attached Method:NA 0 REPORT LIMIT Date: 1O-Nov-17 ANALYTICAL REPORT Work0rder:HS17110184 Lab ID:HS17110184-02 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED 1O-Nov-2017 13:56 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of25 HFNA-000001858 EPA Inspection Report - Page 1197 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 02-Nov-2017 08:45 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS Miscellaneous Analysis See Attached Method:NA 0 REPORT LIMIT Date: 1O-Nov-17 ANALYTICAL REPORT Work0rder:HS17110184 Lab ID:HS17110184-03 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED 1O-Nov-2017 13:56 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of25 HFNA-000001859 EPA Inspection Report - Page 1198 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-6 (T-41) 02-Nov-2017 08:50 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS Miscellaneous Analysis See Attached Method:NA 0 REPORT LIMIT Date: 1O-Nov-17 ANALYTICAL REPORT Work0rder:HS17110184 Lab ID:HS17110184-04 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED 1O-Nov-2017 13:56 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of25 HFNA-000001860 EPA Inspection Report - Page 1199 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110184 Sample ID Client Samp ID Collection Date TCLP Date Batch ID R305229 Test Name : SUBCONTRACTED ANALYSIS HS17110184-01 HS17110184-02 HS17110184-03 HS17110184-04 S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) 02 Nov 2017 09:55 02 Nov 2017 09:18 02 Nov 2017 08:45 02 Nov 2017 08:50 Date: 1O-Nov-17 DATES REPORT Prep Date Analysis Date DF Matrix: Liquid 10 Nov 201713:56 10 Nov 201713:56 10 Nov 201713:56 10 Nov 201713:56 Page 8 of25 HFNA-000001861 EPA Inspection Report - Page 1200 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110184 Date: 1O-Nov-17 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND 0 p R s u Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SOL TRRP Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL/SOL Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Page 9 of25 HFNA-000001862 EPA Inspection Report - Page 1201 of 1969 ALS Group USA, Corp Agency Arkansas California Illinois Kentucky Louisiana North Carolina North Dakota Oklahoma Texas Date: 1O-Nov-17 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number 17-027-0 2919 2016-2018 004112 123043 03087 2017-2017 624-2017 R193 2017-2017 2017-088 T104704231-17-19 Expire Date 27-Mar-2018 31-Jul-2018 09-May-2018 30-Apr-2018 30-Jun-2018 31-Dec-2017 30-Apr-2018 31-Aug-2018 30-Apr-2018 Page 10 of25 HFNA-000001863 EPA Inspection Report - Page 1202 of 1969 ALS Group USA, Corp Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17110184 Lab Sarnp ID HS17110184-01 HS17110184-02 HS17110184-03 HS17110184-04 Client Sample ID S-1 (API HG) S-3 (API Water) S-5 (T-40) S-6 (T-41) Action Login Login Login Login Date 11/3/2017 3:48:05 PM 11/3/2017 3:48:05 PM 11/3/2017 3:48:05 PM 11/3/2017 3:48:05 PM Person RPG RPG RPG RPG Date: 10-Nov-17 SAMPLE TRACKING New Location Sub Sub Sub Sub Page 11 of25 HFNA-000001864 EPA Inspection Report - Page 1203 of 1969 ALS Group USA, Corp Client Name: Work Order: Navajo Refining HS17110184 Date/Time Received: Received by: Date: 1O-Nov-17 Sample Receipt Checklist 03-Nov-2017 09:10 JRM Checklist completed by: Raegen Giga eSignature 3-Nov-2017 Date Reviewed by: Nicole Edwards eSignature 1O-Nov-2017 Date Matrices: Carrier name: FedEx Priority Overnight Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Chain of custody present? Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? TX1005 solids received in hermetically sealed vials? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler( s )/Kit( s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ 1.8c/2.1 C uc/c No D No D No D No D No D No D No D No D No D No D No D No D ox 11/03/2017 16:00 Yes ;# No Yes D Yes D No D No D D Not Present D Not Present Not Present ~ N/A ~ IR 11 No VOA vials submitted N/A ~ N/A ~ Login Notes: Client Contacted: Date Contacted: Person Contacted: Contacted By: Comments: Regarding: Corrective Action: Page 12 of25 HFNA-000001865 EPA Inspection Report - Page 1204 of 1969 Enuironmental ............c.u.stomer iijf()rmatfon P~r~nase dicier Chain of Custody Form Page _1_ of ____j_ D Cincinnati, OH +1 513 733 5336 D Everett, WA +l 425 356 D 2500 ALS ProjectManager: Erica Padilla \():~ojectNartie BWON Monthly Sampling (EOL) <j Specific Gravity D + 1 616 399 6070 Holland, Ml D +1 281 530 5656 Houston, TX D Middletown, PA +1 717 944 5541 Work Order#: D +l 801 266 Salt Lake City, UT 7700 D Spring City, PA +1610 948 D 4903 C~m~~ny Name Navajo Refining Company LLC : : : : .:.:.:.:.:.:-: :-: :<->>>> ........................ Address Tyler Turner Gabi Combs P.O. Box 159 > ~ity/~tatel#ii> Artesia, NM 88211-0159 > . ........ . Pii~iie (575) 748-3311 > J".c1x (575) 145.5451 ~iUTo}k.n1pan)i Holly Frontier Navajo Refining LLC C I. 501 East Main . . ..<'.iityJ..S,fa.t.e./.Zip Artesia, New Mexico 88210 > .... <<. ... Ptiona (575) 748-3311 .. ........... ' .. < << < <f:cix (575) 746-5451 f e~Mall Address Suzanne.Aquilar@hollyfrontier.com j HS17110184 Navajo Refining Company BVVON Monthly Sampling (EOL) - 1111111111111111 IIII II -- : S-1 (API HC) S-3 (API Water) 11/02/17 11/02/17 9:55AM Liquid 8 9:18 AM Liquid 8 X I X S-5 (T-40) 11/02/17 8:45AM Liquid 8 X S-6 (T-41) 11/02/17 8:50AM Liquid 8 X ,: 8 .. Relinquished by: .. Logged by (Laboratory): Pres.ervative K~: 1-HCL 2-Hi\103 Note: Any changes must be made in writing . . Date: If -;;..o Date: Date: 3-H2S04 once samples and IShipment. Method: ... J fedEK Required Turnaround Time: D STD 10 Wk Days 0 5 Wk Days D Time: '-f:~IJ Received by: Notes: Time: Received by {Laboratory): ' Cooler Temp. Time: Checked by {Laborato,:y): 5-Na2S203 6,NaHS04 :7 . . COC Form have been submitted to ALS Laboratory Group. D0ther _ _ __ 2 Wk Days D 24 Hour : ... .... .... :. ... ..>: >.<>>: .. <: ::: :.. CIC PackagEi:(Chei;.1(139:x.~EllC!vv}.: Level II: Standard QC Level III: Std QC+ Raw Data Level IV: SW846 CLP-Like ..< .... <<< .< . . TR RP-Checklist TRRP Level IV Other: Copyright 2009 by ALS Laboratory Group Page 13 of 25 HFNA-000001866 EPA Inspection Report - Page 1205 of 1969 Use of this system constitutes your agreement to the service conditions in the current FedEx Service Guide, available on fedex:.com. FedEx will not be responsible for any daim in excess of $100 per package, whether the result of !ass, damage, delay, non--deliverv, misde!ivery, or misinformation, unless you declare a higher value, pay an additional charge, document your actual loss and file a timely claim. limitations found in the current FedEx Service Guide apply. Your right to recover from FedEx for any loss, including intrinsic value of the package, loss of sales, income interest, profit, attorne/s fees, costs, and other forms of damage whether direct, incidental, consequentia I, or special is fimlted to the greater of $100 or the authorized declared value. Recovery cannot exceed actual documented loss. rvlaximum for items of extraordinary value is $1,000, e.g. jewelry, precious metals, negotlab!e Instruments and other items listed in our Service Guide. Written claims must be filed within strict time limits, see current FedEx Service Guide. After printing ttiis label: CONSIGNEE COPY PLEASE PLACE IN FRONT OF POUCH 1 Fold the piinted page along the Mnz.ontal lme 2. Place label in shipping pouch and affix it 10 your shJpment ------------------------------------------ )> CD u, G) ~ X... C: "_' ...-..a, ):>O :r:~ i~.. ....... 0 <D w 0 00 CJ'I <D 0 fi> ....... '"t] 22 0 :::0 =i -< g m ::0 z > i5 C ::c G) -l 0 ,[!l ! r vi" ~ ~ !'l I 0 ri> Q 0 ,, ei 22 0 (.,) z ~ ..... 0 0 w )> .0.. i)>Z .-- (/) 8 rm m ~ (/) Page 14 of 25 HFNA-000001867 EPA Inspection Report - Page 1206 of 1969 ALS enulronmental 10450 Stancliff Rd., Suite 210 Houston, Texas 77099 Tai. +1 281 530 5656 Fax. +1 281 530 5887' ("?,-LCI ~ Page 15 of 25 HFNA-000001868 EPA Inspection Report - Page 1207 of 1969 1O-Nov-2017 Nicole Edwards ALS Environmental 10450 Stancliff Rd Suite 210 Houston, TX 77099 Re: HS17110184 Dear Nicole, Work Order: 1711345 ALS Environmental received 4 samples on 04-Nov-2017 09:45 AM for the analyses presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Sample results are compliant with industry accepted practices and Quality Control results achieved laboratory specifications. Any exceptions are noted in the Case Narrative, or noted with qualifiers in the report or QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained from ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. The total number of pages in this report is 10. If you have any questions regarding this report, please feel free to contact me. Sincerely, Electronically approved by: Chad Whelton Chad Whelton Project Manager Certificate No: MN 998501 Report of Laboratory Analysis HFNA-000001869 EPA Inspection Report - Page 1208 of 1969 ALS Group, USA Client: Project: Work Order: ALS Environmental HS17110184 1711345 Lab Samp ID Client Sample ID 1711345-01 HS17l l0184-0l 1711345-02 HS17110184-02 1711345-03 HS17110184-03 1711345-04 HS17110184-04 Date: 10-Nov-17 Matrix Liquid Liquid Liquid Liquid Work Order Sample Summary Tag Number S-1 (API HC) S-2 (API Water) S-5 (T-40) S-6 (T-41) Collection Date 11/2/2017 09:55 11/2/2017 09:18 11/2/2017 08:45 11/2/2017 08:50 Date Received 11/4/2017 09:45 11/4/2017 09:45 11/4/2017 09:45 11/4/2017 09:45 Hold Page 17 of25 Sample Summary Pagel of 1 HFNA-000001870 EPA Inspection Report - Page 1209 of 1969 ALS Group, USA Client: Project: WorkOrder: ALS Environmental HS17110184 1711345 Date: 10-Nov-l7 QUALIFIERS, ACRONYl\1S, UNITS Qualifier ** a B E H J ND 0 p R s u X Description Value exceeds Regulatory Limit Estimated Value Analyte is non-accredited Anal)1e detected in the associakd Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte is present at an estimated concentration between the MDL and Report Limit Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPD above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL Analyte was detected in the Method Blank between the MDL and Repo1ting Limit, sample results may exhibit background or reagent contamination at the observed level. Acronvm Description DUP Method Duplicate LCS Laboratory Control Sample LCSD Laboratory Control Sample Duplicate LOD Limit of Detection (see MDL) LOQ Limit ofQuantitation (see PQL) MBLK Method Blank MDL Method Detection Limit MS Matrix Spike MSD Matrix Spike Duplicate PQL Practical Quantitation Limit RPD Relative Percent Difference TDL Target Detection Limit TNTC Too Numerous To Count A APHA Standard Methods D ASTM E EPA SW SW-846 Update III Units Reported none Description Page 18 of25 QFPage 1 o/1 HFNA-000001871 EPA Inspection Report - Page 1210 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS17110184 HS17110184-0l 11/2/2017 09:55 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: JO-Nov-17 Result Qual Report Limit Work Order: 1711345 Lab ID: 1711345-01 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.00 none Analyst: RZM 11/9/2017 04:50 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 19 of25 Analytical Results Page l of 4 HFNA-000001872 EPA Inspection Report - Page 1211 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS17110184 HS17110184-02 11/2/2017 09: 18 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: JO-Nov-17 Result Qual Report Limit Work Order: 1711345 Lab ID: 1711345-02 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.01 none Analyst: RZM 11/9/2017 04:50 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 20 of25 Analytical Results Page 2 of 4 HFNA-000001873 EPA Inspection Report - Page 1212 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS17110184 HS17110184-03 11/2/2017 08:45 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: JO-Nov-17 Result Qual Report Limit Work Order: 1711345 Lab ID: 1711345-03 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.13 none Analyst: RZM 11/9/2017 04:50 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 21 of25 Analytical Results Page 3 of 4 HFNA-000001874 EPA Inspection Report - Page 1213 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS17110184 HS17110184-04 11/2/2017 08:50 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: JO-Nov-17 Result Qual Report Limit Work Order: 1711345 Lab ID: 1711345-04 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.13 none Analyst: RZM 11/9/2017 04:50 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 22 of25 Analytical Results Page 4 of 4 HFNA-000001875 EPA Inspection Report - Page 1214 of 1969 ALS Group, USA Client: ALS Environmental Work Order: 1711345 Project: HS17110184 Date: 10-Nov-l7 QC BATCH REPORT Batch ID: R224230 Instrument ID WETCHEM Method: D5057-90 DUP Sample ID: 1711345-02A DUP Client ID: HS17110184-02 Run ID: WETCHEM_171109M Units: none SeqNo: 4751313 Analysis Date: 11/9/2017 04:50 PM Prep Date: OF: 1 Analyte Result SPK Ref PQL SPKVal Value %REC Control Limit RPO Ref Value %RPO RPO Limit Qual Specific Gravity 1.007 0 0 0 0 0-0 1.006 0.139 20 The following samples were analyzed in this batch: 1711345-01A 1711345-04A 1711345-02A 1711345-03A Note: See Qualifiers Page for a list of Qualifiers and their explanation. Page 23 of25 QC Page: 1 of 1 HFNA-000001876 EPA Inspection Report - Page 1215 of 1969 A-- - - s 10450 Stancllff Rd, Ste 210 Hou_ston, TX 77099 T: +1 281 530 5656 F: +1 2~! 530 58~7 www.als1lobal.com Subcontract Chain of Custody COC ID: 7991 SUBCONTRACT TO: ALS Laboratory Group 3352 128th Ave. Holland, Ml 494249263 - Phone: +1 616 399 6070 CUSTOMER INFORMATION: Company: ALS Houston Contact: Address: Phone: Nicole Edwards 10450 stanclllf Rd, Ste 210 +1 281 530 5656 - sEmaHL -- - - Nlcole.Edwards@alsglobal.com-- Alternate Contact: Emall: J1J111ok_E! M. Lawal jumoke.lawal@alsgJobal.com INVOICE INFORMATION: Company: ALS Houston Contact: Accounts Payable Addrus: 10450 Stancliff Rd, Ste 210 Phone: +1 281 530 5656 ___ , __ -" Reference:__ HS17-ll0184 - _ TSR: Houston House Acct 1. HS17110184-01 S-1 (API HC) Specific Gravity Sub to ALS Holland 2. HS17110184-02 Specific Gravity Sub to ALS Holland 3, - HSl.7110184-03 s~s (T-40) - Specific Gravity Sub to ALS Holland 4. HS17110184--04 S-6 (T-41) Specific Gravity Sub to ALS Holland Uquld L,lquld UqiJld Uquld 02 Nov 2017 09:55 10 Nov 2017 02 Nov 2017 09:18 10 Nov 2017 02 Nov 2017 08:45 10 Nov 2017 02 Nov 2017 08:50 10 Nov 2017 eomments: Please analyze for the analysis listed above. Send report to the emalls shown above. QC Level: STD (Laboratory Standard QC: method blank and LCS required) Rellnqulshed By: Received By: Cooler ID(s): Date/Time: Date/Time: Temperature(s): IJ1}(? ( ~ } (,,.. Y-( ) O<i ~ '5--e,..'L,{ 1, , ,:2.. lUGHT SOLUTIONS\ RIGHT P/iRTNFH Page 24 of25 HFNA-000001877 EPA Inspection Report - Page 1216 of 1969 ALS Group, USA Client Name: Work Order: ALS - HOUSTON 1711345 Sample Receipt Checklist Date/Time Received: Received by: 04-Nov-17 09:45 Checklist completed by 11uL ~ = 06-Nov-17 ------------~----- e Signature Date Reviewed by: eSignature Matrices: Carrier name: Shipping container/cooler in good condition? Yes [i,] No Not Present D Custody seals intact on shipping container/cooler? Yes [i,] No Not Present D Custody seals intact on sample bottles? Yes No Not Present [i,] Chain of custody present? Yes [i,] No Chain of custody signed when relinquished and received? Yes [i,] No D Chain of custody agrees with sample labels? Yes [i,] No D Samples in proper container/bottle? Yes [i,] No D Sample containers intact? Yes [i,] No Sufficient sample volume for indicated test? Yes [i,] No All samples received within holding time? Yes [i,] No Container/Temp Blank temperature in compliance? Yes [i,] No Sample(s) received on ice? Temperature(s)/Thermometer(s): Yes [i,] No Cooler(s)/Kit(s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: r11/6/20179:17:27 AM Yes !~ No No VOA vials submitted Yes [i,] Yes D No N/A D No [i,l N/A D Login Notes: 06-Nov-17 Date Client Contacted: Contacted By: Comments: Date Contacted: Regarding: Person Contacted: CorrectiveAction: ~agc=of'.15~ SRC Page 1 of 1 HFNA-000001878 EPA Inspection Report - Page 1217 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 December 14, 2017 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling (EOL) Dear Gabriela, Work Order: HS17120448 ALS Environmental received 4 sample(s) on Dec 06, 2017 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, Generated By: Dayna.Fisher Nicole Edwards Project Manager Right Solutions Right Partnu www.a!sg!obaLcom Pagel of25 HFNA-000001879 EPA Inspection Report - Page 1218 of 1969 ALS Group USA, Corp Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120448 lab Samp ID HS17120448-01 HS 17120448-02 HS17120448-03 HS 17120448-04 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Matrix Liquid Liquid Liquid Liquid Date: 14-Dec-17 SAMPLE SUMMARY TagNo Collection Date 05-Dec-2017 09:48 05-Dec-2017 09:36 05-Dec-2017 09:00 05-Dec-2017 09:05 Date Received 06-Dec-2017 09:50 06-Dec-2017 09:50 06-Dec-2017 09:50 06-Dec-2017 09:50 Hold D D D D Page 2 of25 HFNA-000001880 EPA Inspection Report - Page 1219 of 1969 ALS Group USA, Corp Dale: 14-Dec-17 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120448 Work Order Comments CASE NARRATIVE The analysis for Specific Gravity was subcontracted lo ALS Environmental in Holland, Ml. Final Report attached. Page 3 of25 HFNA-000001881 EPA Inspection Report - Page 1220 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (API HC) 05-Dec-2017 09:48 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS Miscellaneous Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-17 ANALYTICAL REPORT Work0rder:HS17120448 Lab ID:HS17120448-01 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED NA 14-Dec-2017 09:03 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of25 HFNA-000001882 EPA Inspection Report - Page 1221 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 05-Dec-2017 09:36 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS Miscellaneous Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-17 ANALYTICAL REPORT Work0rder:HS17120448 Lab ID:HS17120448-02 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED NA 14-Dec-2017 09:03 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of25 HFNA-000001883 EPA Inspection Report - Page 1222 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 05-Dec-2017 09:00 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS Miscellaneous Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-17 ANALYTICAL REPORT Work0rder:HS17120448 Lab ID:HS17120448-03 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED NA 14-Dec-2017 09:03 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of25 HFNA-000001884 EPA Inspection Report - Page 1223 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-6 (T-41) 05-Dec-2017 09:05 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS Miscellaneous Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-17 ANALYTICAL REPORT Work0rder:HS17120448 Lab ID:HS17120448-04 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED NA 14-Dec-2017 09:03 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of25 HFNA-000001885 EPA Inspection Report - Page 1224 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120448 Sample ID Client Samp ID Collection Date TCLP Date Batch ID R307189 Test Name : SUBCONTRACTED ANALYSIS HS17120448-01 HS17120448-02 HS17120448-03 HS17120448-04 S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) 05 Dec 2017 09:48 05 Dec 2017 09:36 05 Dec 2017 09:00 05 Dec 2017 09:05 Date: 14-Dec-17 DATES REPORT Prep Date Analysis Date DF Matrix: Liquid 14 Dec 2017 09:03 14 Dec 2017 09:03 14 Dec 2017 09:03 14 Dec 2017 09:03 Page 8 of25 HFNA-000001886 EPA Inspection Report - Page 1225 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120448 Date: 14-Dec-17 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND 0 p R s u Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SOL TRRP Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL/SOL Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Page 9 of25 HFNA-000001887 EPA Inspection Report - Page 1226 of 1969 ALS Group USA, Corp Agency Arkansas California Illinois Kentucky Louisiana North Carolina North Dakota Oklahoma Texas Date: 14-Dec-17 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number 17-027-0 2919 2016-2018 004112 123043 03087 2017-2017 624-2017 R193 2017-2017 2017-088 T104704231-17-19 Expire Date 27-Mar-2018 31-Jul-2018 09-May-2018 30-Apr-2018 30-Jun-2018 31-Dec-2017 30-Apr-2018 31-Aug-2018 30-Apr-2018 Page 10 of25 HFNA-000001888 EPA Inspection Report - Page 1227 of 1969 ALS Group USA, Corp Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120448 Lab Sarnp ID HS17120448-01 HS17120448-02 HS17120448-03 HS17120448-04 Client Sample ID S-1 (API HG) S-3 (API Water) S-5 (T-40) S-6 (T-41) Action Login Login Login Login Date 12/8/2017 1:24:53 PM 12/8/2017 1:24:53 PM 12/8/2017 1:24:53 PM 12/8/2017 1:24:53 PM Person RPG RPG RPG RPG Date: 14-Dec-17 SAMPLE TRACKING New Location Sub Sub Sub Sub Page 11 of25 HFNA-000001889 EPA Inspection Report - Page 1228 of 1969 ALS Group USA, Corp Client Name: Work Order: Navajo Refining HS17120448 Date/Time Received: Received by: Date: 14-Dec-17 Sample Receipt Checklist 06-Dec-2017 09:50 JRM Checklist completed by: Raegen Giga eSignature 8-Dec-2017 Date Reviewed by: Nicole Edwards eSignature 8-Dec-2017 Date Matrices: Carrier name: FedEx Priority Overnight Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Chain of custody present? Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? TX1005 solids received in hermetically sealed vials? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler( s )/Kit( s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ .1 c/2.4c uc/c oam 12/06/2017 13:51 Yes ;# Yes D Yes D No D No D No D No D No D No D No D No D No D No D No D No D No No D No D D Not Present D Not Present Not Present ~ N/A ~ IR 11 No VOA vials submitted N/A ~ N/A ~ Login Notes: Client Contacted: Date Contacted: Person Contacted: Contacted By: Comments: Regarding: Corrective Action: Page 12 of25 HFNA-000001890 EPA Inspection Report - Page 1229 of 1969 Chain of Custody Form 1 HS17120448 ..,.............."'".:_:_e..,.:::,.,.::n-:c'="~'"..."...:.7..""..":""l~:"'"~:::"-"'o:~-lll-;'"T:tit"'"o'"'.".:..,.,.::"'"'::'""..........."""::::"""::'!""<: _,.,..:.:.::,...:,..,.:..-"""'::.........A..-...L.-:::;-.'."'".;-o""l'~~-e 11 --:.-e~:-:t"l"!l:-~;-0,.,.::,.-:..-.:.-...-r~-;:i--:n""'c...a..-.-..P,...,..a:.....-._.l'_l-..a..-..._.-. _--j-__-__-+..-..:. : Pt6je~{~arne BWON Monthly Sampling (EOL) :A: >: (;Jln1pa11yJ1laltle Navajo Refining Company LLC Tyler Turner Gabl Combs Bili>To Coniany Holly Frontier Navajo Refining LLC ...... .. : P.O. Box 159 > \(:;ify/$tatei2ip Artesia, NM 88211-0159 ..: Fax 1 ..... :.;.."'-~~ (575) 748-3311 i .:: : . >'. "'.".'.'.'~ (s1s1746-5451 :: :: ~Mali Aciciress .... :..... . . ............. uume, G am@gmailcorn ab~[a.Combs<mhallvfrnn!.illL@m . '.1/ S-1 (API HC) : <{: S-3 (API Water) i> ~ S-5 (T-40) I:< : S-6 (T-41) 1:>~ >: 501 East Main > ,: cityl$:t.a.te.i.Z.1.i>. Artesia, New Mexico 88210 G . . .. : : ,: . . . . . . >: :-~ (575) 748-3311 . .. H .. : :Fax (s1sJ 746-5451 > ::::.:: e"MaUA;dd~ss Suzanne.Aguilar@lhollyfrontier.com : ;J ...::::. ))afe .. :fi!J:1~ ...... Mat~x> Pres: 11fti1es I 12/05/17 9:48AM Liquid 8 1 X 12/05/17 9:36AM liquid 8 1 X 12/05/17 9:00AM Liquid 8 X 12/05/17 9:05AM liquid 8 X ..-...:.:.-.:""':::-:- Specific . . . . ...JIHfft'.1]nnJrm1 111 Gravity o EE:: .. ::: .: H 1,: ( . J ::,: .. . H<>ict :: .~:: .-.~ <10 > Relinquished by: ' Logged by (Laboratory): Date: Time: J.:?/c:/1/ Time: !Required Turnaround Time: 0 STD IO Wk Days E) 5 Wk Days 0 Notes: Received by {Laboratory): Checked by (Laborato!Y): Cooler Temp. 1 Preservative Key: 1~HCL 2-HN03 3~H2S04 4-NaOH 5-Na2S203 6-NaHS04 7-0tfler 8-4 degrees C 9-5035 Note: Any changes must be made in writing once samples and COC Form hav ' e been submitted to ALS Laboratory Group. F:,-,:,,,,.'1_ (J,z;,f~ Page 13 of 25 I . Omher ____ 2 Wk Days O 24 Hour <: / . ... q9 P.arikag~: (9he~~ B~JC ~elov,i). / < : .. Level II: Standard QC ITRRP-Checklist Level Ill: Std QC+ Raw Data ITRRP Level IV Level IV: SW846 CLP-Like Other: Copyright 2009 by ALS Laboratory Group HFNA-000001891 EPA Inspection Report - Page 1230 of 1969 Use of thls system constitutes your agreement to the service condltlons in the current FedEx Service Guide, available on fedex.com. FedEx will not be responsible for any claim in excess of $100 per package, whether the result of loss, damage, deiay, non-delivery, misdelivery, er misinformation, unless you declare a h!gher value, pay an additional charge, document your actual !ass and file a timely claim. limitations fourid in the current FedEx Service Guide apply. Your right to recover from FedEx for any loss, including intrinsic value of the package, loss of sales, income interest, profit, attorney's fees, costs, and <?therforms of damage whether direct, incidental, consequentlal, or special is limited to the greater of $100 or the a.uthorized declared value. Recovery cannot exceed actual documented loss, Maximum for items of extraordinary value is $1,000, e.g. Jewelry, preciOllS metals, negotiable instruments and other items listed in our Service Guide. Wr'itten claims must be filed within strict tlme !imlts, see current FedEx Servfce Guide. lWZ 8 0 J30 After prin:lir1g this label: CONSIGNEE COPY PLEASE PLACE IN FRONT OF POUCH i Fold th<: printed page along Ins hOriz.onta! Hne. 2, Place !abe! in shipping pouch and affix it to your shipmen1 )> [~Ji CD ...... 0 (,I) w en 0 CIO G) 01 <D ~ 0 .C..J.1. N _X.... c:. "' ............ )>O > 0 :::c ~ 0 .,, ;:o :E 0 m ;:o 0 ~ 0 0, 0 0 m< m ;:o .0... z 0 i5 w ::t: -i ~ Page 14 of 25 -------- ---- HFNA-000001892 EPA Inspection Report - Page 1231 of 1969 SHIPPER'S DECLARATION FOR DANGEROUS GOODS (Provide at least three copies to airline.) Shipper Brady Hubbard AQUA MICROBICS 501 E MAIN C/0 AQUA MICROBICS ARTESIA NM88210 US Consignee Nicole Edwards ALS 10450 Stancliff Suite 210 HOUSTON TX77099 US Air Waybill No. 709308590512 Page 1 of 1 Page(s) ~ : x Shipper's Reference Number (optional) 18 Compliant Express CAFE3108 Two completed and signed copies of this Declaration must be handed to the operator WARNING TRANSPORT DETAILS This shipment is within the !imitations prescribed for: {delete non applicable) Airport of Departure ARTESIA Failure to comply with all respects with the applicable Dangerous Goods Regulations may be in breach of the applicable law ,subject to legal penalties. ~ V T Airport of Destination: HOUSTON ABSGRA Shinment tvne: (delete non appllcable) n. ,,. NATURE AND QUANTITY OF DANGEROUS GOODS UN Number or identification Number, proper shipping name, ('.Jass or Division (subsidiary risk), packing group (if required), and all other required Information. UN 3266. Corrosive liquid, basic, inorganic, n.o.s.(Sodium Hydroxide),8,1// UN 1268, Petroleum distillates, n.o.s.,3,1111/ 0.04 U/366 All Packed In One FIBREBOARD BOX Q =0.1 0.08 U/854 -A-d-d-i-ti-o-n-a--l-H-a--n-d-l-in-g--I-n-f-o-r-m--a-t-io-n-----------------------------------------------------------------------------------~--------~------ 24-Hour Emergency Response- CHEMTREC 1800-4249300, CCN 201319 I hereby declare that the contents of this consignment are fully and accurately described above by the proper shipping name, and are classified, packaged, marked and labelled/placarded, and are in all respects in proper condition for transport according to applicable International and National Governmental Regulations. I declare that all of the applicable air transport requirements have been met. Name/Title of Signatory Brady Hubbard/Environmental Coordinator Place and Date Artesia.NM 12/05i2017 Signature Brady Hubbard 18004249300 EmergMcy 1'elophone Number (see warning above) l r ~ 1.J;..Lt-1 FOR RAOIOACTIVE MATERIAL SHIPMENT ACCEPTABLE FOR ?ASSENGER AIRCRAFT, THE SHIPMENT CONTAINS RAOlOACTIVE MATERIAL INTENDED FOR USE IN OR INC!nENTTO RESEARCH, MEDICAL DIAGNOSIS OR TREATMENT. AOR EUROPEAN TRANSPORT STATEMENT: CARRIAGE IN ACCORDANCE WITH 1.1.4.2.1 LOGOS !i157295 11/12 Page 15 of 25 HFNA-000001893 EPA Inspection Report - Page 1232 of 1969 14-Dec-2017 Nicole Edwards ALS Environmental 10450 Stancliff Rd Suite 210 Houston, TX 77099 Re: HS17120448 Dear Nicole, Work Order: 1712629 ALS Environmental received 4 samples on 09-Dec-2017 11 :30 AM for the analyses presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Sample results are compliant with industry accepted practices and Quality Control results achieved laboratory specifications. Any exceptions are noted in the Case Narrative, or noted with qualifiers in the report or QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained from ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. The total number of pages in this report is 10. If you have any questions regarding this report, please feel free to contact me. Sincerely, Electronically approved by: Chad Whelton Chad Whelton Project Manager Certificate No: MN 998501 Report of Laboratory Analysis HFNA-000001894 EPA Inspection Report - Page 1233 of 1969 ALS Group, USA Client: Project: Work Order: ALS Environmental HS 17120448 1712629 Lab Samp ID Client Sample ID 1712629-01 HS17120448-0l 1712629-02 HS l 7120448-02 1712629-03 HSI 7120448-03 1712629-04 HS17120448-04 Date: 14-Dec-17 Matrix Liquid Liquid Liquid Liquid Work Order Sample Summary Tag Number S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Collection Date 12/5/2017 09:48 12/5/2017 09:36 12/5/2017 09:00 12/5/2017 09:05 Date Received 12/9/2017 11:30 12/9/2017 11:30 12/9/2017 11:30 12/9/2017 11:30 Hold Page 17 of25 Sample Summary Pagel of 1 HFNA-000001895 EPA Inspection Report - Page 1234 of 1969 ALS Group, USA Client: Project: WorkOrder: ALS Environmental HS17120448 1712629 Date: 14-Dec-17 QUALIFIERS, ACRONYl\1S, UNITS Qualifier ** a B E H J ND 0 p R s u X Description Value exceeds Regulatory Limit Estimated Value Analyte is non-accredited Anal)1e detected in the associakd Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte is present at an estimated concentration between the MDL and Report Limit Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPD above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL Analyte was detected in the Method Blank between the MDL and Repo1ting Limit, sample results may exhibit background or reagent contamination at the observed level. Acronvm Description DUP Method Duplicate LCS Laboratory Control Sample LCSD Laboratory Control Sample Duplicate LOD Limit of Detection (see MDL) LOQ Limit ofQuantitation (see PQL) MBLK Method Blank MDL Method Detection Limit MS Matrix Spike MSD Matrix Spike Duplicate PQL Practical Quantitation Limit RPD Relative Percent Difference TDL Target Detection Limit TNTC Too Numerous To Count A APHA Standard Methods D ASTM E EPA SW SW-846 Update III Units Reported none Description Page 18 of25 QFPage 1 o/1 HFNA-000001896 EPA Inspection Report - Page 1235 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS17120448 HS17120448-0l 12/5/2017 09:48 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 7 Result Qual Report Limit WorkOrder: 1712629 Lab ID: 1712629-01 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.00 none Analyst: RZM 12/13/2017 04: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 19 of25 Analytical Results Page l of 4 HFNA-000001897 EPA Inspection Report - Page 1236 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS17120448 HS l 7120448-02 12/5/2017 09:36 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 7 Result Qual Report Limit WorkOrder: 1712629 Lab ID: 1712629-02 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.00 none Analyst: RZM 12/13/2017 04: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 20 of25 Analytical Results Page 2 of 4 HFNA-000001898 EPA Inspection Report - Page 1237 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS17120448 HS l 7120448-03 12/5/2017 09:00 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 7 Result Qual Report Limit WorkOrder: 1712629 Lab ID: 1712629-03 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.14 none Analyst: RZM 12/13/2017 04: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 21 of25 Analytical Results Page 3 of 4 HFNA-000001899 EPA Inspection Report - Page 1238 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS17120448 HS17120448-04 12/5/2017 09:05 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 7 Result Qual Report Limit WorkOrder: 1712629 Lab ID: 1712629-04 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.15 none Analyst: RZM 12/13/2017 04: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 22 of25 Analytical Results Page 4 of 4 HFNA-000001900 EPA Inspection Report - Page 1239 of 1969 ALS Group, USA Client: ALS Environmental Work Order: 1712629 Project: HS17120448 Date: 14-Dec-l 7 QC BATCH REPORT Batch ID: R226448 Instrument ID WETCHEM Method: D5057-90 DUP Sample ID: 1712629-02A DUP Client ID: HS17120448-02 Run ID: WETCHEM_171213R. Units: none SeqNo: 4809420 Analysis Date: 12/13/2017 04:15 PM Prep Date: OF: 1 Analyte Result SPK Ref PQL SPKVal Value %REC Control Limit RPO Ref Value %RPO RPO Limit Qual Specific Gravity 1.002 0 0 0 0 0-0 1.003 0.0299 20 The following samples were analyzed in this batch: 1712629-01A 1712629-04A 1712629-02A 1712629-03A Note: See Qualifiers Page for a list of Qualifiers and their explanation. Page 23 of25 QC Page: 1 of 1 HFNA-000001901 EPA Inspection Report - Page 1240 of 1969 , . -~ :- . ' -- . - -~. -: ,;;,:-:~ .:- 10450 Stancliff Rd, Ste 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 www.alsglobal.com Subcontract Chain of Custody COC ID: 8189 SUBCONTRACT TO: ALS Laboratory Group 3352 128th Ave. Holland, MI 494249263 Phone: +1 616 399 6070 CUSTOMER INFORMATION: company: Contact: Address: Phone: Email: Alternate Contact: Email: ALS Houston Nicole Edwards 10450 Stancliff Rd, Ste 210 + 1 281 530 5656 Nicole. Edwa rds@alsglobal.com Jumoke M. Lawal jumoke.lawal@alsglobal.com INVOICE INFORMATION: Company: ALS Houston contact: Address: Phone: Refm-ence: TSR: Accounts Payable 10450 Stancliff Rd, Ste 210 +1 281 530 5656 HS17120448 Houston House Acct 1. HS17120448-01 Specific Gravity Sub to ALS Holland 2. HS17120448-02 S-3 (API Water) Specific Gravity Sub to ALS Holland 3. HS17120448-03 S-5 (T-40) Specific Gravity Sub to ALS Holland 4, HS17120448--04 S-6 (T-41} Specific Gravity Sub to ALS Holland Liquid Liquid Liquid Liquid 05 Dec 2017 09:48 13 Dec 2017 05 Dec 2017 09:36 13 Dec 2017 05 Dec 2017 09:00 13 Dec 2017 05 Dec 2017 09:05 13 Dec 2017 Comments: Please analyze for the analysis listed above. Send report to the emails shown above. QC level: STD (Laboratory Standard QC: method blank and LCS required) Relinquished By: Received By: Cooler ID(s): '~filf 1~;: Date/Tlme: Date/Time: Tern perature(s): 1 . n 3R,2 2 (;, C SOS SHEETS ATTACHED Page 24 of25 HFNA-000001902 EPA Inspection Report - Page 1241 of 1969 ALS Group, USA Client Name: Work Order: ALS - HOUSTON 1712629 Sample Receipt Checklist Date/Time Received: Received by: 09-Dec-17 11 :30 Checklist completed by _LlULK</ '-c;',e'-""" 11-Dec-17 ------------~----- e Signature Date Matrices: Carrier name: Reviewed by: ~ . C:""'"'"'"", eSignature Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Yes [i,] Yes No Not Present D No Not Present [i,] Custody seals intact on sample bottles? Yes No Not Present [i,] Chain of custody present? Yes [i,] No Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Yes [i,] Yes [i,] Yes [i,] Yes [i,] No D No D No D No Sufficient sample volume for indicated test? Yes [i,] No All samples received within holding time? Yes [i,] No Container/Temp Blank temperature in compliance? Yes [i,] No Sample(s) received on ice? Temperature(s)/Thermometer(s): Yes [i,] No Cooler(s)/Kit(s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? r12/11 /2017 1:44:58 PM Yes No VOA vials submitted [i,] Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Yes Yes D No N/A No D N/A Login Notes: 11-Dec-17 Date Client Contacted: Contacted By: Comments: Date Contacted: Regarding: Person Contacted: CorrectiveAction: ~agc=of'.15~ SRC Page 1 of 1 HFNA-000001903 EPA Inspection Report - Page 1242 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 December 13, 2017 Tyler Turner (Cons. Aqua Microbics) Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling (EOL) Dear Tyler, Work Order: HS17120451 ALS Environmental received 9 sample(s) on Dec 06, 2017 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, Generated By: Jumoke.Lawal Nicole Edwards Project Manager Right Solutions Right Partnu www.a!sg!obaLcom Pagel of26 HFNA-000001904 EPA Inspection Report - Page 1243 of 1969 ALS Group USA, Corp Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120451 lab Samp ID HS17120451-01 HS17120451-02 HS17120451-03 HS17120451-04 HS17120451-05 HS17120451-06 HS17120451-07 HS17120451-08 HS17120451-09 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Matrix Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Date: 13-Dec-17 SAMPLE SUMMARY TagNo Collection Date 05-Dec-2017 09:48 05-Dec-2017 09:36 05-Dec-2017 09:00 05-Dec-2017 09:05 05-Dec-2017 09:31 05-Dec-2017 09:55 05-Dec-2017 09:55 05-Dec-2017 00:00 05-Dec-2017 00:00 Date Received 06-Dec-2017 09:50 06-Dec-2017 09:50 06-Dec-2017 09:50 06-Dec-2017 09:50 06-Dec-2017 09:50 06-Dec-2017 09:50 06-Dec-2017 09:50 06-Dec-2017 09:50 06-Dec-2017 09:50 Hold D D D D D D D D D Page 2 of26 HFNA-000001905 EPA Inspection Report - Page 1244 of 1969 ALS Group USA, Corp Dale: 13-Dec-17 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120451 GCMS Volatiles by Method SW8260 Batch ID: R306950 CASE NARRATIVE The test results meet requirements of the current NELAP standards, state requirements or programs where applicable. Batch ID: R306963 Sample ID: S-1 (API HC) (HS17120451-01) Lowest practical dilution for HS17120451-01 ,due to sample matrix. Sample ID: S-5 (T-40) (HS17120451-03) Surrogates failure for HS17120451-03 due to sample matrix. Lowest practical dilution for HS17120451-03 ,due to sample matrix. Sample ID: S-6 (T-41) (HS17120451-04) Lowest practical dilution for HS17120451-04 ,due to sample matrix. Surrogates failure for HS17120451-04 due to sample matrix. Batch ID: R307105 The test results meet requirements of the current NELAP standards, state requirements or programs where applicable. Page 3 of26 HFNA-000001906 EPA Inspection Report - Page 1245 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (API HC) 05-Dec-2017 09:48 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.025 95.3 101 98.0 97.2 Method:SW8260 0.025 REPORT LIMIT 0.25 70-126 73-120 70-130 82-121 Date: 13-Dec-17 ANALYTICAL REPORT Work0rder:HS17120451 Lab ID:HS17120451-01 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 11-Dec-2017 19:13 11-Dec-2017 19:13 11-Dec-2017 19:13 11-Dec-2017 19:13 11-Dec-2017 19:13 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of26 HFNA-000001907 EPA Inspection Report - Page 1246 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 05-Dec-2017 09:36 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.43 80.7 94.0 91.8 103 Method:SW8260 0.0060 REPORT LIMIT 0.050 70-126 82-124 77-123 82-127 Date: 13-Dec-17 ANALYTICAL REPORT Work0rder:HS17120451 Lab ID:HS17120451-02 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L 10 %REC 10 %REC 10 %REC 10 %REC 10 Analyst: PC 12-Dec-2017 17:07 12-Dec-2017 17:07 12-Dec-2017 17:07 12-Dec-2017 17:07 12-Dec-2017 17:07 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of26 HFNA-000001908 EPA Inspection Report - Page 1247 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 05-Dec-2017 09:00 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.024 97.7 101 61.7 95.2 Method:SW8260 0.024 s REPORT LIMIT 0.24 70-126 73-120 70-130 82-121 Date: 13-Dec-17 ANALYTICAL REPORT Work0rder:HS17120451 Lab ID:HS17120451-03 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 11-Dec-2017 19:37 11-Dec-2017 19:37 11-Dec-2017 19:37 11-Dec-2017 19:37 11-Dec-2017 19:37 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of26 HFNA-000001909 EPA Inspection Report - Page 1248 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-6 (T-41) 05-Dec-2017 09:05 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.025 98.1 105 62.9 95.2 Method:SW8260 0.025 s REPORT LIMIT 0.25 70-126 73-120 70-130 82-121 Date: 13-Dec-17 ANALYTICAL REPORT Work0rder:HS17120451 Lab ID:HS17120451-04 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 11-Dec-2017 20:00 11-Dec-2017 20:00 11-Dec-2017 20:00 11-Dec-2017 20:00 11-Dec-2017 20:00 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of26 HFNA-000001910 EPA Inspection Report - Page 1249 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Field Blank 05-Dec-2017 09:31 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 98.8 104 100 102 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 13-Dec-17 ANALYTICAL REPORT Work0rder:HS17120451 Lab ID:HS17120451-05 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 1O-Dec-2017 18:03 10-Dec-2017 18:03 10-Dec-2017 18:03 10-Dec-2017 18:03 10-Dec-2017 18:03 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 8 of26 HFNA-000001911 EPA Inspection Report - Page 1250 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 1 05-Dec-2017 09:55 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 94.9 98.1 97.8 100 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 13-Dec-17 ANALYTICAL REPORT Work0rder:HS17120451 Lab ID:HS17120451-06 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 1O-Dec-2017 18:30 10-Dec-2017 18:30 10-Dec-2017 18:30 10-Dec-2017 18:30 10-Dec-2017 18:30 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 9 of26 HFNA-000001912 EPA Inspection Report - Page 1251 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 2 05-Dec-2017 09:55 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 97.2 105 97.4 105 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 13-Dec-17 ANALYTICAL REPORT Work0rder:HS17120451 Lab ID:HS17120451-07 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 1O-Dec-2017 18:56 10-Dec-2017 18:56 10-Dec-2017 18:56 10-Dec-2017 18:56 10-Dec-2017 18:56 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 10 of26 HFNA-000001913 EPA Inspection Report - Page 1252 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Duplicate 05-Dec-2017 00:00 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.41 86.9 99.0 92.4 107 Method:SW8260 0.0060 REPORT LIMIT 0.050 70-126 82-124 77-123 82-127 Date: 13-Dec-17 ANALYTICAL REPORT Work0rder:HS17120451 Lab ID:HS17120451-08 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L 10 %REC 10 %REC 10 %REC 10 %REC 10 Analyst: PC 12-Dec-2017 17:34 12-Dec-2017 17:34 12-Dec-2017 17:34 12-Dec-2017 17:34 12-Dec-2017 17:34 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 11 of26 HFNA-000001914 EPA Inspection Report - Page 1253 of 1969 ALS Group USA, Corp Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Trip Blank 05-Dec-2017 00:00 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 88.5 97.6 96.7 98.4 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 13-Dec-17 ANALYTICAL REPORT Work0rder:HS17120451 Lab ID:HS17120451-09 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 1O-Dec-2017 17:36 10-Dec-2017 17:36 10-Dec-2017 17:36 10-Dec-2017 17:36 10-Dec-2017 17:36 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 12 of26 HFNA-000001915 EPA Inspection Report - Page 1254 of 1969 ALS Group USA, Corp Client: Navajo Refining Company Project: BWON Monthly Sampling (EOL) WorkOrder: HS17120451 Batch ID: 2149 SamplD HS17120451-01 HS17120451-03 HS17120451-04 Method: VOLATl LES BY SW8260C Container Sample Wt/Vol 5.063 (g) 5.102 (g) 5.033 (g) Final Volume 5 (ml) 5 (ml) 5 (ml) Weight Factor 0.99 0.98 0.99 Container Type Bulk (5030B) Bulk (5030B) Bulk (5030B) Date: 13-Dec-17 WEIGHT LOG Page 13 of26 HFNA-000001916 EPA Inspection Report - Page 1255 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120451 Sample ID Client Samp ID Collection Date TCLP Date Batch ID R306950 Test Name : VOLATILES - SW8260C HS17120451-05 HS17120451-06 HS17120451-07 HS17120451-09 Field Blank EQ Blank Port 1 EQ Blank Port 2 Trip Blank 05 Dec 2017 09:31 05 Dec 2017 09:55 05 Dec 2017 09:55 05 Dec 2017 00:00 Batch ID R306963 Test Name: VOLATILES BY SW8260C HS17120451-01 HS17120451-03 HS17120451-04 S-1 (API HC) S-5 (T-40) S-6 (T-41) 05 Dec 2017 09:48 05 Dec 2017 09:00 05 Dec 2017 09:05 Batch ID R3071 05 Test Name : VOLATILES - SW8260C HS17120451-02 HS17120451-08 S-3 (API Water) Duplicate 05 Dec 2017 09:36 05 Dec 2017 00:00 Date: 13-Dec-17 DATES REPORT Prep Date Analysis Date DF Matrix: Liquid 10 Dec 2017 18:03 10 Dec 2017 18:30 10 Dec 2017 18:56 10 Dec 2017 17:36 Matrix: Liquid 11 Dec201719:13 50 11 Dec 2017 19:37 50 11 Dec 2017 20:00 50 Matrix: Liquid 12 Dec 2017 17:07 10 12 Dec 2017 17:34 10 Page 14 of26 HFNA-000001917 EPA Inspection Report - Page 1256 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120451 Date: 13-Dec-17 QC BATCH REPORT Batch ID: R306950 Instrument: VOA1 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-171210 Units: ug/L Analysis Date: 10-Dec-2017 12:15 Run ID: VOA1 - 306950 Result PQL SPKVal SeqNo: 4345073 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Dimethyl disulfide Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 < 0.055 1.0 46. 11 0 50 51.68 0 50 47.36 0 50 52. 1 0 50 0 92.2 70 - 123 0 103 83 - 122 0 94.7 73 - 126 0 104 81 - 119 LCS Client ID: Analyte Sample ID: VLCSW-171210 Units: ug/L Analysis Date: 10-Dec-2017 11 :22 Run ID: VOA1 - 306950 Result PQL SPKVal SeqNo: 4345072 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 50.14 5.0 50 48.52 0 50 49.41 0 50 48.09 0 50 47. 11 0 50 0 100 74 - 120 0 97.0 70 - 130 0 98.8 83 - 122 0 96.2 73 - 126 0 94.2 81 - 119 MS Client ID: Analyte Sample ID: HS17120338-01 MS Units: ug/L Analysis Date: 10-Dec-2017 14:02 Run ID: VOA1 - 306950 Result PQL SPKVal SeqNo: 4345075 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 49.98 5.0 50 50.84 0 50 53.16 0 50 49.45 0 50 46.59 0 50 0 100.0 70 - 127 0 102 70 - 126 0 106 82 - 124 0 98.9 77 - 123 0 93.2 82 - 127 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 15 of26 HFNA-000001918 EPA Inspection Report - Page 1257 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120451 Date: 13-Dec-17 QC BATCH REPORT Batch ID: R306950 Instrument: VOA1 Method; SW8260 MSD Client ID: Analyte Sample ID: HS17120338-01 MSD Units: ug/L Analysis Date: 10-Dec-2017 14:29 Run ID: VOA1 - 306950 Result PQL SPKVal SeqNo: 4345076 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 42.9 5.0 47.63 0 52.71 0 50.37 0 46.64 0 The following samples were analyzed in this batch: fS17120451-05 50 50 50 50 50 HS17120451-06 0 85.8 70 - 127 0 95.3 70 - 126 0 105 82 - 124 0 101 77 - 123 0 93.3 82 - 127 49.98 50.84 53. 16 49.45 46.59 15.2 20 6.52 20 0.856 20 1.85 20 0. 112 20 HS17120451-07 HS17120451-09 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 16 of26 HFNA-000001919 EPA Inspection Report - Page 1258 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120451 Date: 13-Dec-17 QC BATCH REPORT Batch ID: R306963 Instrument: VOA8 Method; SW8260 MBLK Client ID: Analyte Sample ID: MBLKW1-121117 Units: ug/Kg Analysis Date: 11-Dec-2017 14:35 Run ID: VOA8_306963 SeqNo: 4345297 PrepDate: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 25 2527 2415 2524 2535 250 0 2500 0 2500 0 2500 0 2500 0 101 76 - 125 0 96.6 83 - 120 0 101 80 - 119 0 101 81 - 118 LCS Client ID: Analyte Sample ID: VLCSW1-121117 Units: ug/Kg Analysis Date: 11-Dec-2017 13:48 Run ID: VOA8_306963 SeqNo: 4345296 PrepDate: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 45.51 5.0 50 53.81 0 50 50.41 0 50 52.42 0 50 49.51 0 50 0 91.0 75 - 124 0 108 76 - 125 0 101 83 - 120 0 105 80 - 119 0 99.0 81 - 118 MS Client ID: Analyte Sample ID: HS17120051-07MS Units: ug/Kg Analysis Date: 11-Dec-2017 17:41 Run ID: VOA8_306963 SeqNo: 4345866 Prep Date: OF: 500 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 24030 21540 23790 22160 23360 2400 0 0 0 0 23750 23750 23750 23750 23750 0 101 70 - 130 0 90.7 70 - 126 0 100 72 - 120 0 93.3 70 - 130 0 98.3 82 - 121 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 17 of26 HFNA-000001920 EPA Inspection Report - Page 1259 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120451 Date: 13-Dec-17 QC BATCH REPORT Batch ID: R306963 Instrument: VOA8 Method; SW8260 MSD Client ID: Analyte Sample ID: HS17120051-07MSD Units: ug/Kg Analysis Date: 11-Dec-2017 18:04 Run ID: VOA8_306963 SeqNo: 4345867 PrepDate: OF: 500 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene 25140 2400 23750 0 106 70 - 130 24030 4.51 30 Surr: 1,2-0ichloroethane-d4 21240 0 23750 0 89.4 70 - 126 21540 1.42 30 Surr: 4-Bromofluorobenzene 23600 0 23750 0 99.4 72 - 120 23790 0.802 30 Surr: Dibromofluoromethane 23590 0 23750 0 99.3 70 - 130 22160 6.26 30 Surr: Toluene-dB 23380 0 23750 0 98.4 82 - 121 23360 0.0977 30 The following samples were analyzed in this batch: ~f_s_17_1_2_04_s_1_-0_1_ _ _H_s_1_7_1_20_4_s_1-_0_3_ _ _H_s_1_7_12_0_4_s1_-_04_ _ _ _ _ _ _ _ _ _ _ _ _~ Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 18 of26 HFNA-000001921 EPA Inspection Report - Page 1260 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120451 Date: 13-Dec-17 QC BATCH REPORT Batch ID: R307105 Instrument: VOA1 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-171212 Units: ug/L Analysis Date: 12-Dec-2017 12:38 Run ID: VOA1 - 307105 Result PQL SPKVal SeqNo: 4348785 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Dimethyl disulfide Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 < 0.055 1.0 44.76 0 50 47.3 0 50 46.6 0 50 49.85 0 50 0 89.5 70 - 123 0 94.6 83 - 122 0 93.2 73 - 126 0 99.7 81 - 119 LCS Client ID: Analyte Sample ID: VLCSW-171212 Units: ug/L Analysis Date: 12-Dec-2017 11 :45 Run ID: VOA1 - 307105 Result PQL SPKVal SeqNo: 4348784 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 45.03 5.0 50 46. 11 0 50 53.03 0 50 47.65 0 50 51J 0 50 0 90.1 74 - 120 0 92.2 70 - 130 0 106 83 - 122 0 95.3 73 - 126 0 103 81 - 119 MS Client ID: Analyte Sample ID: HS17120351-02MS Units: ug/L Analysis Date: 12-Dec-2017 15:46 Run ID: VOA1 - 307105 Result PQL SPKVal SeqNo: 4348787 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 44.6 5.0 50 46.01 0 50 49.91 0 50 48.04 0 50 49.02 0 50 0 89.2 70 - 127 0 92.0 70 - 126 0 99.8 82 - 124 0 96. 1 77 - 123 0 98.0 82 - 127 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 19 of26 HFNA-000001922 EPA Inspection Report - Page 1261 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120451 Date: 13-Dec-17 QC BATCH REPORT Batch ID: R307105 Instrument: VOA1 Method; SW8260 MSD Client ID: Analyte Sample ID: HS17120351-02MSD Units: ug/L Analysis Date: 12-Dec-2017 16:13 Run ID: VOA1 - 307105 Result PQL SPKVal SeqNo: 4348788 SPK Ref Value %REC Prep Date: Control Limit OF: 1 RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 41 .07 5.0 45.79 0 47.73 0 47.08 0 50.48 0 The following samples were analyzed in this batch: fS17120451-02 50 50 50 50 50 HS17120451-08 0 82.1 70 - 127 0 91.6 70 - 126 0 95.5 82 - 124 0 94.2 77 - 123 0 101 82 - 127 44.6 46.01 49.91 48.04 49.02 8.24 20 0.491 20 4.46 20 2.02 20 2.94 20 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 20 of26 HFNA-000001923 EPA Inspection Report - Page 1262 of 1969 ALS Group USA, Corp Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS17120451 Date: 13-Dec-17 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND O P R S U Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL/SOL Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SOL TRRP Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Unit Reported mg/Kg mg/L Description Milligrams per Kilogram Milligrams per Liter Page 21 of26 HFNA-000001924 EPA Inspection Report - Page 1263 of 1969 ALS Group USA, Corp Agency Arkansas California Illinois Kentucky Louisiana North Carolina North Dakota Oklahoma Texas Date: 13-Dec-17 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number 17-027-0 2919 2016-2018 004112 123043 03087 2017-2017 624-2017 R193 2017-2017 2017-088 T104704231-17-19 Expire Date 27-Mar-2018 31-Jul-2018 09-May-2018 30-Apr-2018 30-Jun-2018 31-Dec-2017 30-Apr-2018 31-Aug-2018 30-Apr-2018 Page 22 of26 HFNA-000001925 EPA Inspection Report - Page 1264 of 1969 ALS Group USA, Corp Client Name: Work Order: Navajo Refining HS17120451 Date/Time Received: Received by: Date: 13-Dec-17 Sample Receipt Checklist 06-Dec-2017 09:50 JRM Checklist completed by: Raegen Giga eSignature 8-Dec-2017 Date Reviewed by: Nicole Edwards eSignature 8-Dec-2017 Date Matrices: Carrier name: FedEx Priority Overnight Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Chain of custody present? Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? TX1005 solids received in hermetically sealed vials? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler( s )/Kit( s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ .1 c/2.4c uc/c tyrafoam 12/06/2017 18:00 Yes ;# Yes D Yes D No D No D No D No D No D No D No D No D No D No D No D No D No No D No D D Not Present D Not Present Not Present ~ N/A ~ IR 11 No VOA vials submitted N/A ~ N/A ~ Login Notes: Client Contacted: Date Contacted: Person Contacted: Contacted By: Comments: Regarding: Corrective Action: Page 23 of26 HFNA-000001926 EPA Inspection Report - Page 1265 of 1969 A Enuiranmental .. ........ . ::.:P.~rchase Order Chain of Custody Form Page _1_ of __j__ D Cincinnati, OH +1 513 733 5336 D Everett, WA +1 425 356 2600 D Fort Collins, CO +19704901511 [] +16163996070 Holland, Ml D Houston, TX +1 2815305656 D Middletown, PA +1717944 5541 D Salt Lake City, UT +1 801 266 7700 D Spring City, PA + I 610 948 4903 D York, PA +I 717 505 5280 ALS Project Mamager: Erica Padilla .. << > i:,roiectlnfottriatfon < Pibjectriiaiti~ BWON Monthly Sampling (EOL} Wotk Order#: <<P.ai'amet~r,Mettiod Re~!tfotAtia1ysis> : ..... A; VOLATILES (8260) Benzene ~ompa~y ~ania Navajo Refining Company LLC Tyler Turner Gabi Combs P.O. Box 159 i ~ityl~tatelllp Artesia, NM 88211-0159 ....... >:: .. Phone (575J 748-3311 ..... << < > Fait (575J 746-5451 }Bili Tei Corripany Holly Frontier Navajo Refining LLC 501 East Main < > QityJStat~l?IP Artesia, New Mexico 88210 ....... / ;''::::'"' (575) 748-3311 >H: .... <<: fax (575) 746-5451 ec~alLAd~#s Suzanne.Aguilar@hollyfrontier.com J HS17120451 Navajo Refining Company 11, ,mr11rirnnn1111 - - f S-1 (API HC) i S-3 (AP! Water) 12/05/17 12/05/17 9:48AM Liquid 8 9:36AM Liquid 8,1 1 X 1 X ) S-5 (T-40) 12/05/17 9:00AM Liquid 8 1 X 4:: S-6 (T-41) <~ Field Blank i f EQ Blank Port 1 :7:< EQ Blank Port 2 >>a Duplicate : :9: Trip Blank 1(C Temperature Blank 12/05/17 12/05/17 12/05/17 12/05/17 12/05/17 12/05/17 12/05/17 9:05AM Liquid 8 9:31 AM Liquid 8,1 9:55AM Liquid 8,1 9:55AM Liquid 8,1 XXX XXX Liquid 8,1 Liquid 8,1 Liquid 1 X 1 X 1 X 1 X 1 X 2 X 1 Required Turnaround Time: Oother _ _ __ ( D STD 10 Wk Days 0 5 Wk Days D 2 Wk Days D 24Hour Relinquished bl'.;.-.HrGI. ~ H1.16bcircf Date: Time: Received by: Notes: "JliuA...JJ '-1/J 11- fj l~S-('7 Relinquished by: ' - Time: Received by (Laboratory): CQOlerTemp. 9~ ~ackagiH~heck !3ox Bel6iNF Loggeaby:(l:.aboratoryJ: Preservative Key: . .. 1-HCL . 2~HN03 Date: 3-H2S04 Time: Cllooked by (Laboratory): . 4-NaOH .. 5-Na2S203 6-NaHS04 7-0ther 8,4 degrees C 9-5035 . Level II: Standard QC Level Ill: Std QC+ Raw Data Level !V: SW846 CLP-Like Other: ITRRP-Checklist ITRRP Level IV Note: Any changes must be made in writing once samples and COC Form have been submitted to ALS Laboratory Group. Copyright 2009 by ALS Laboratory Group Page 24 of26 HFNA-000001927 EPA Inspection Report - Page 1266 of 1969 Use of this system constitutes your agreement to the serulce conditions in the current FedEx Service GlJ!de, avail.able on fedex.com. FedEx will not be responsible for any daim in excess of $10D per package, whether the result of loss, damage, delay, non--delivery, misdellvery, or misinformation, unless you declare a higher value, pay an additional charge, document your actual los.s and file a timely claim. limitations found in the current FedEx Service Guide apply. Your right to recover from FedEx for any loss, including intrinsic value of the package, loss of sales, income interest, profit, attorney's fees, costs, and C?ther forms of damage whether direct, incidental, consequentlal 1 ars.peclai is limited to the greater of $100 or the aJ.Jthorized declared value. Recovery cannot exceed actual documented less. Maximum for items of elctraordinary value ls $1,000, e.g. jewelry, precious metals, negotiable instruments and other items listed in our Service Gulde. Written claims must be flied wlthin strict time limits, see current Fed Ex Service GtJide. After printing this f::1be1 CONSIGN5e COPY Pl.5AS5 Pl.ACE IN FRONT OF POUCH 1. Fold the printed page along the Mnzontal ill'!& 2. Plac& iab'=i in shipping pouch a!'ld affix it to y"our shipment )> [~Ji CD -.i 0 ~ w en 0 CIO G) U1 ~ ~ Q .U...1. N _i .0.. ~)>Z r-- CI) 8 r- m m ;:o Cl (/) Page 25 of26 HFNA-000001928 EPA Inspection Report - Page 1267 of 1969 SHIPPER'S DECLARATION FOR DANGEROUS GOODS Shipper Brady Hubbard AQUA MICRQBICS 501 E MAIN C/0 AQUA MICROBICS ARTESIA NM86210 US Consignee Nicole Edwards ALS 10450 Stancliff Suite 210 HOUSTON TX77099 US Two completed and signed copies of this Declaration must be handed to the operator TRANSPORT DETAILS This shipment is within the limitations prescribed for: (delete non applicable) Airport of Departure ARTESIA T y ~ Alrport of Destination: HOUSTON ABSGRA (Provide at least three copies to airline.) Air Waybill No. 709308590512 Page 1 of 1 Page(s) Shipper's Reference Number :x (optional) ~ 18 Compliant Express CAFE3108 WARNING Failure to comply with all respects with the applicable Dangerous Goods Regulations may be in breach of the applicable law ,subject to legal penalties. Shioment !voe: (delete non applicable) NATURE AND QUANTITY OF DANGEROUS GOODS UN Number or idetJtificatian Number, proper shipping name, Class or Division (subsidiary risk), packing group (if required), and all other required Information. UN 3266. Corrosive liquid, basic, inorganic, n.o.s.(Sodium Hydroxide),8,1/1 UN 1268, Petroleum distillates, n.o.s.,3,111// 0.04 Li/366 All PacKed In One FIBREBOARD BOX Q=0.1 0.08 Li/854 -A--d-d-i-ti-o-n-a-l--H-a-n--d-li-n-g--I-n-fo--r-m-a--ti-o-n-------------------------------------------------------------~------------------------------------- 24-Hour Emergency Response- CHEMTREC i-800-424-9300, CCN 201319 I hereby declare that the contents of this consignment are fully and accurately described above by the proper shipping name, and are classified, packaged, marked and labelled/placarded, and are in all respects in proper condition tor transport according to applicable international and National Governmental Regulations. I declare that all of the applicable air transport requirements have been met 18004249300 Emergency Telephone Number Name/Title of Signatory Brady Hubbard/Environmental Coordinator Place and Date Artesia, NM 12/05/2017 Signature (see w:flrning above) Brady Hubbard JJr"-",~ FOR RAOlOACTIVE'. MATERIAL. SHIPMENT ACCEPTABLE FOR PASSENGER AIRCRAFT, THE SHIPMENT CONTAINS RADIOACTIVE MATERIAL INTENDED FOR use: IN OR INCIDENT TO RESEARCH, MEDICAL DIAGNOSIS OR TREATMENT. ADR EUROPEAN TRANSPORT STATEMENT: CARRIAGE IN ACCORDANCE WITH 1.1.4 2.1 t.<Xi05 #15729511/12. Page 26 of26 HFNA-000001929 EPA Inspection Report - Page 1268 of 1969 April 30, 2019 U.S. Environmental Protection Agency Director, Air Enforcement Division Ariel Rios Building 1200 Pennsylvania Avenue, N.W. Mail Code 2242-A Washington, DC 20460 Certified_MailiRetum_Receipt 7014 3490 0000 6269 5352 Re: Quarterly Implementation Progress Report Pursuant to the Consent Decree entered March 5, 2002 by the U.S. District Court for the District of New Mexico in United States of America et al. v. Navajo Refining Company, LLC et: al. Dear Director: Pursuant to Paragraphs 37 and 23.0 of the subject consent decree, this submittal provides the status of implementation of consent decree requirements through the calendar quarter ending March 31, 2019 for HollyFrontier Navajo Refining LLC (formerly Navajo Refining Company, L.L.C), (Navajo's) Artesia and Lovington, NJ\/1 refineries. As specified by Paragraph 37, a statement of certification is provided on the following page. In accordance with the notice provisions ofParagraph 91, copies ofthis report are being mailed to both addresses listed for the State of New Mexico. Navajo is also providing an additional hardcopy to EPA's contractor and an electronic-mail copy to the address provided in the email from EPA Region 6 dated January 31, 2019. If you have any questions regarding this submittal, please contact me at the address below or by phone at 575-746-5487. Sincerely, Scott M. Denton Environmental Manager HollyFrontier Navajo Refining LLC HollyFrontier Navajo Refining LLC 501 East Main Artesia, NM 88210 (575) 748-3311 !urn;//~'.Yi1'Y,h9llYfrQl'.ll:i~r,rQm HFNA-000002818 EPA Inspection Report - Page 1269 of 1969 By signature below, the undersigned hereby certifies to the following: Statement of Certification I certify under penalty of law that this information was prepared under my direction or supervision in accordance with a system designed to assure that qualified personnel properly gather and evaluate the information submitted. Based on my directions and my inquiry of the person(s) who manage the system~.~?r the person(s) directly responsible for gathering the information, the informatiofi sjibmitted is, to the best of my knowledge and belief, true, accurate, and complet.ei / ,,, , "" / (xt,Jlf~- Parrish R. Miller Vice President & Refinery Manager HollyFrontier Navajo Refining LLC Enclosure cc {w/enc.): Bureau Chief Air Quality Bureau New Mexico Enviromnent Department 525 Camino de los Marquez, Suite 1 Santa Fe, NM 87507 U.S. Enviromnental Protection Agency c/o Matrix Environmental & Geotechnical Services Matrix New World Engineering, lnc. 26 Columbia Turnpike Florham Park, NJ 07932 General Counsel Office of General Counsel New Mexico Environment Department P.O. Box 26110 Santa Fe, NM 87502-6110 Electronic cc (wienc.): Electronic cc (w/enc.): Environmental File: HollyFrontier: P. Miller, B. Romine, G. Combs J. Stump, T. Jones, T. Wheeler, S. Gokhale; R Bagherian G:\Environmental\2.0 Air Quality\2.1 Original Agency Correspondence\2019 HollyFmnticr Navajo Refining LLC 501 East Main Artesia, NM 88210 (575) 748-331 I hur.://w:w:w,hgJJyfo;mJi~r,~q_m HFNA-000002819 EPA Inspection Report - Page 1270 of 1969 CALENDAR QUARTERLY REPORT SUBMITTED PURSUANT TO SECTION IX OFTHECONSENTDECREEENTEREDIN UNITED STATES OF AMERICA ET AL. V. NAVAJO REFINING COMPANY, L.P., AND MONTANA REFINING COMPANY (ENTERED MARCH 5, 2002) Cumulative from Lodging (December 20, 2001) Through March 31, 2018 HollyFrontier Navajo Refining LLC (formerly Navajo Refining Company, L.L.C.) Artesia and Lovington, NM Refineries P.O. Box 159 Artesia, NM 88211-0159 HFNA-000002820 EPA Inspection Report - Page 1271 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries TABLE OF CONTENTS 1.0 INTRODUCTION ............................................................................................................ 1 2.0 PROGRESS REPORT ON IMPLEMENTATION OF SECTION V OF THE CONSENT DECREE .................................................................................................................................... 2 3.0 SUMMARY OF ACTUAL OR ANTICIPATED PROBLEMS IN IMPLEMENTING THE REQUIREMENTS OF SECTION V...........................................................................................24 4.0 SUMMARY OF EMISSIONS DATA ..............................................................................24 5.0 IMPLEMENTATION OF ENVIRONMENTALLY BENEFICIAL PROJECTS ..................28 6.0 OTHER MATTERS........................................................................................................33 ATTACHMENTS ATTACHMENT 1 -APPENDIX G SUMMARY REPORT ATTACHMENT 2-APPENDIX H SUMMARY REPORT ATTACHMENT 3-QUARTERLY EOL SUMMARY ATTACHMENT 4- 2018 TAB SUMMARY ENCLOSED CD ATTACHMENT 5-1QT 2019 EOL ANALYTICAL REPORTS ATTACHMENT 6 - 2018 TAQB ANALYTICAL RESULTS ATTACHMENT 7- NSPS SUBPART JA EXCESS EMISSIONS PERIOD: JULY-DECEMBER 2018 ii HFNA-000002821 EPA Inspection Report - Page 1272 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries CALENDAR QUARTERLY REPORT Cumulative from Lodging (DECEMBER 20, 2001) Through March 31, 2019 HollyFrontier Navajo Refining LLC (Navajo) Artesia and Lovington, NM Refineries 1.0 INTRODUCTION In accordance with the requirements of Section IX of the Consent Decree entered in UNITED STATES OF AMERICA ET AL., D. V.M. NAVAJO REFINING COMPANY, L.P., AND MONTANA REFINING COMPANY (entered March 5, 2002), Navajo submits the following "calendar quarterly report" for the Artesia and Lovington, NM refineries. Section IX requires that the quarterly report be submitted within 30 days following the calendar quarter. Today's report covers actions through the first quarter 2019. For completeness, this report addresses relevant actions or activities not just within the current quarter but anytime after the December 20, 2001 Date of Lodging. The contents of this report include: 1. A progress report on the implementation of the requirements of Section V (Section 2.0) 2. A description of any problems anticipated with respect to meeting the requirements of Section V (Section 3.0) 3. A summary of the emissions data as required by Section V (Section 4.0); 4. A description of environmentally beneficial projects and SEP implementation activity during this reporting period (Section 5.0); and 5. Such other matters as Navajo believes should be brought to the attention of EPA (Section 6.0). Summaries showing the progress on Consent Decree Appendices G and H are provided as Attachments 1 and 2, respectively. 1 HFNA-000002822 EPA Inspection Report - Page 1273 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries 2.0 PROGRESS REPORT ON IMPLEMENTATION OF SECTION V OF THE CONSENT DECREE A. Section V, Paragraphs 11 and 14: NOx and CO Emission Reductions from FCCUs Paragraph 12: S02 Emission Reductions from FCCUs Paragraph 13: PM Emission Reductions from FCCUs Artesia FCCU (No FCCU Requirement Begin baseline period, perform notices of Low- NOx promoter and optimization study. Baseline period data collection from 1/1/04 6/30/04. Optimization period to commence no later than June 30, 2004. Commencement of NOx Additive Demonstration Period and reporting beginning 3/31/05. at Lovington): CD Paragraph 11.B 11.D Status/Comment Requirement completed. The optimization period was completed and the optimized addition rate to be used during the demonstration period was submitted to EPA with supporting documentation on 2/24/05. As agreed between Navajo and EPA, the Demonstration Period ended 05/31/2006. Navajo submitted proposed concentration-based NOx limits on 07/27/2006. 2 HFNA-000002823 EPA Inspection Report - Page 1274 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirement Install/certify CEMS to monitor FCCU NOx and 0 2 by 12/31/03. CD Paragraph 11.F Status/Comment CEMS installed and certification RATA performed 11/13/03. Report showing initial certification submitted to NMED on 1/7/04. Pursuant to 40 CFR 60 App F, annual RATA performed 02/14 and 02/15/06. Report showing certification submitted to NMED on 03/15/06. Pursuant to 40 CFR 60 App F, annual RATA performed 01/24/07. Report showing certification submitted to NMED on 02/22/07. Pursuant to 40 CFR 60 App F, annual RATA performed 01/22/08. Report showing certification submitted to NMED on 02/18/08. Pursuant to 40 CFR 60 App F, annual RATA performed 03/03/09. Report showing certification submitted to NMED on 03/30/09. Pursuant to 40 CFR 60 App F, annual RATA performed 03/02/201 O and 03/03/2010. Report showing certification submitted to NMED on 04/05/2010. Pursuant to 40 CFR 60 App F, annual RATA performed 03/01/2011. Report showing certification submitted to NMED on 03/28/2011. Pursuant to 40 CFR 60 App F, annual RATA performed 01/17/2012. Report showing certification submitted to NMED on 02/17/2012. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2013. Report showing certification submitted to NMED on 02/07/2013. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2014. Report showing certification submitted to NMED on 02/04/2014. Annual RATA performed 01/06/2015. Report submitted to NMED on 02/05/2015. Annual RATA performed 01/05/2016. Report submitted to NMED on 02/04/2016. Annual RATA performed 01/03/2017. Report submitted to NMED on 02/04/2017. Annual RATA performed 01/09/2018. Report submitted to NMED on 02/09/2018. Annual RATA performed 02/13/2019. Report submitted to NMED on 03/23/2019. A review of documentation of QC procedures under 40 CFR 60 App. F was recently undertaken. Documentation of all QC procedures in accordance with 40 CFR 60 App. F was completed as of 12/31/2017. 3 HFNA-000002824 EPA Inspection Report - Page 1275 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirement Submit plan to minimize NOx from FCCU during GOHT outages within 180 days of Lodging Date. Install and operate wet gas scrubber on FCCU to meet 25 ppmv (annual avg) and 50 ppmv (7-day) S02 by 12/31/03. CD Paragraph 11.G 12.B Status/Comment Plan Submitted on 6/18/02. EPA's response letter dated 12/9/04 enumerated the requirements for Navajo to have relief from the short term NOx emission limit. Wet gas scrubber installed and operational during 4th Quarter 2003. S02 performance testing completed on 10/16/03; report submitted 1/7/04. 4 HFNA-000002825 EPA Inspection Report - Page 1276 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirement Install and calibrate S02 CEMS in accordance with 40 CFR 60.11, 60.13 and Part 60 App. F CD Paragraph 12.D Status/Comment CEMS installed and certification RATA performed 11/13/03. Report showing initial certification submitted to NMED on 1/7/04. Pursuant to 40 CFR 60 App F, annual RATA performed 02/14 and 02/15/06. Report showing certification submitted to NMED on 03/15/06. Pursuant to 40 CFR 60 App F, annual RATA performed 01/24/07. Report showing certification submitted to NMED on 02/22/07. Pursuant to 40 CFR 60 App F, annual RATA performed 01/22/08. Report showing certification submitted to NMED on 02/18/08. Pursuant to 40 CFR 60 App F, annual RATA performed 03/03/09. Report showing certification submitted to NMED on 03/30/09. Pursuant to 40 CFR 60 App F, annual RATA performed 03/02/201 O and 03/03/2010. Report showing certification submitted to NMED on 04/05/2010. Pursuant to 40 CFR 60 App F, annual RATA performed 03/01/2011. Report showing certification submitted to NMED on 03/28/2011. Pursuant to 40 CFR 60 App F, annual RATA performed 01/17/2012. Report showing certification submitted to NMED on 02/17/2012. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2013. Report showing certification submitted to NMED on 02/07/2013. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2014. Report showing certification submitted to NMED on 02/04/2014. Annual RATA performed 01/06/2015. Report submitted to NMED on 02/05/2015. Annual RATA performed 01/05/2016. Report submitted to NMED on 02/04/2016. Annual RATA performed 01/03/2017. Report submitted to NMED on 02/04/2017. Annual RATA performed 01/09/2018. Report submitted to NMED on 02/09/2018. Annual RATA performed 02/13/2019. Report submitted to NMED on 03/23/2019. See entry for Paragraph 11.F. regarding 40 CFR 60 App. F QC procedures. 5 HFNA-000002826 EPA Inspection Report - Page 1277 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirement WGS shall achieve 1 lb PM per 1000 lb coke burn on 3-hr basis by 12/31 /03. CD Paragraph 13.B Status/Comment Wet gas scrubber installed and operational during 4th Quarter 2003. PM testing completed 11/13/03 and report submitted 1/7/04. Results of 0.5-0.6 lb PM per 1,000 lb coke burn compared to <1.0 lb PM per 1,000 lb coke burn standard. Additional testing was performed 3/3/04 following repairs to the scrubber. These test results indicate <0.25 lb PM per 1,000 lb coke burn (i.e., 25% of standard). 6 HFNA-000002827 EPA Inspection Report - Page 1278 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirement Meet 500 ppmv CO on 1-hr basis and 100 ppmv on annual avg. by 12/31/03. Install/Certify CEMS for FCCU CO and 02 by 12/31/03. CD Paragraph 14.B and 14.C Status/Comment CO performance testing conducted 10/16/03. CEMS installed and RATA performed 11/13/03. Report showing certification submitted to NMED on 1/7/04. Pursuant to 40 CFR 60 App F, annual RATA performed 02/14 and 02/15/06. Report showing certification submitted to NMED on 03/15/06. Pursuant to 40 CFR 60 App F, annual RATA performed 01/24/07. Report showing certification submitted to NMED on 02/22/07. Pursuant to 40 CFR 60 App F, annual RATA performed 01/22/08. Report showing certification submitted to NMED on 02/18/08. Pursuant to 40 CFR 60 App F, annual RATA performed 03/03/09. Report showing certification submitted to NMED on 03/30/09. Pursuant to 40 CFR 60 App F, annual RATA performed 03/02/201 O and 03/03/2010. Report showing certification submitted to NMED on 04/05/2010. Pursuant to 40 CFR 60 App F, annual RATA performed 03/01/2011. Report showing certification submitted to NMED on 03/28/2011. Pursuant to 40 CFR 60 App F, annual RATA performed 01/17/2012. Report showing certification submitted to NMED on 02/17/2012. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2013. Report showing certification submitted to NMED on 02/07/2013. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2014. Report showing certification submitted to NMED on 02/04/2014. Annual RATA performed 01/06/2015. Report submitted to NMED on 02/05/2015. Annual RATA performed 01/05/2016. Report submitted to NMED on 02/04/2016. Annual RATA performed 01/03/2017. Report submitted to NMED on 02/03/2017. Annual RATA performed 01/09/2018. Report submitted to NMED on 02/09/2018. Annual RATA performed 02/13/2019. Report submitted to NMED on 03/23/2019. See entry for Paragraph 11.F. regarding 40 CFR 60 App. F QC procedures. 7 HFNA-000002828 EPA Inspection Report - Page 1279 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries B. Section V, Paragraph 15: NSPS Applicability of FCCUs Artesia FCCU (No FCCU at Lovington): Requirements CD Status/Comment Paragraph NSPS becomes applicable to 15 Wet gas scrubber installed and operational during FCCU for S02, PM, CO and 4th Quarter 2003. PM performance testing, initial opacity on 12/31/03. CEMS certification RATA for S02 and CO completed 11/13/03 and report submitted 1/7/04. AMP for opacity submitted 12/31/03; pending written approval. Method 9 readings indicate O- 5% opacity. Annual PM testing per AMP was performed 2/8/05 indicating 0.11 lb PM/1000 lb coke. Annual PM testing per AMP was performed 2/15/06 indicating 0.19 lb PM/1000 lb coke. Annual PM testing per AMP was performed 1/24/07 indicating 0.34 lb PM/1000 lb coke. Annual PM testing per AMP was performed 1/22/08 indicating 0.13 lb PM/1000 lb coke. Annual PM testing per AMP was performed 3/3/09 indicating 0.47 lb PM/1000 lb coke burned. Annual PM testing per AMP was performed 03/02/201 O and 03/03/201 a.indicating 0.54 lb PM/1000 lb coke burned. Annual PM testing per AMP was performed 03/01/2011 indicating 0.23 lb PM/1000 lb coke burned. Annual PM testing per AMP was performed 01/17/2012 indicating 0.39 lb PM/1000 lb coke burned. Annual PM testing per AMP was performed 01/08/2013, which did not show compliance, and again on 3/04/2013 indicating 0.204 lb PM/1000 lb coke burned. Annual PM testing per AMP performed 01/08/2014 indicating 0.71 lb PM/1000 lb coke burned. Report showing certification submitted to NMED on 02/04/2014. Annual PM testing per AMP performed 01/06/2015 indicating 0.11 lb PM/1000 lb coke burned. Report submitted to NMED on 02/05/2015. Annual PM testing per AMP performed 01/05/2016 indicating 0.35 lb PM/1000 lb coke burned. Report submitted to NMED on 02/04/2016. Annual PM testing per AMP performed 01/03/2017 indicating 0.03 lb PM/1000 lb coke burned. Report submitted to NMED on 02/03/2017. Annual PM testing per AMP performed 01/09/2018 indicating 0.50 lb PM/1000 lb coke burned. Report submitted to NMED on 02/09/2018. Annual PM testing per AMP performed 02/13/2019 indicating 0.10 lb PM/1000 lb coke burned. Report submitted to NMED on 03/23/2019. 8 HFNA-000002829 EPA Inspection Report - Page 1280 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries C. Section V, Paragraph 16: NOx Emissions Reductions from Heaters and Boilers Requirements CD Status/Comment Paragraph Install NOx control on 8-7 by 16.8.ii. and FGR started up on 12/17/2002. CEMS installed 12/31/02 to meet 0.06 lb/MM8tu and operate CEMS on 8-7 for NOx and 0 2. 16.C.i. and was successfully certified by a RATA performed 12/18/2002. Test results and CEMS indicate 8-7 meets NOx control requirement. Pursuant to 40 CFR 60 App F, annual RATA performed 09/26/2006, 09/13/2007, 09/09/2008, 09/17/2009, 08/24/2010, 08/16/2011, 08/15/2012, 08/07/2013. RATA performed 07/30/2014. Certification report submitted to NMED on 09/11/2014. RATA performed 07/23/2015. Certification report submitted to NMED on 08/20/2015. RATA performed 07/13/2016. Certification report submitted to NMED on 08/05/2016. RATA performed 06/21/2017. Certification report submitted to NMED on 07/20/2017. RATA performed 03/06/2018. Certification report submitted to NMED on 03/29/2018. RATA performed 03/19/2019. Certification report submitted to NMED on 04/18/2019. Install NOx control on 8-8 by 16.8.ii. and 8-8 began actual initial startup and shakedown 12/31/03 to meet 0.06 16.C.i. period on 7/23/03. NOx controls and CEMS lb/MM8tu and operate CEMS on 8-8 for NOx and 0 2. operational. CEMS RATA and 8-8 performance testing done 10/29/03. Test report submitted 12/8/03. Pursuant to 40 CFR 60 App F, annual RATA performed 09/26/2006, 09/13/2007, 09/09/2008, 09/17/2009, 08/24/2010 08/16/2011, 08/15/2012, 08/06/2013, 07/30/2014. RATA was performed 07/29/2014. Certification report submitted to NMED on 09/11/2014. RATA was performed 07/22/2015. Certification report submitted to NMED on 08/20/2015. RATA was performed 07/13/2016. Certification report submitted to NMED on 08/05/2016. RATA performed 06/21/2017. Certification report submitted to NMED on 07/20/2017. RATA performed 03/07/2018. Certification report submitted to NMED on 03/29/2018. RATA performed 03/19/2019. Certification report submitted to NMED on 04/18/2019. 9 HFNA-000002830 EPA Inspection Report - Page 1281 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements Install next-generation ultralow NOx control on H-20 and H-601 at Artesia refinery. Performance test H-20 and H-601. Establish compliance indicators by an initial performance test. CD Paragraph 16.8.i., 16.C.iii., and Appendix C Status/Comment H-601 burners installed. Testing conducted on 3/2/04. Report including proposed compliance indicators and permit limits was submitted 5/14/04. H-20 burners installed prior to 12/31/05 deadline and heater resumed operation 12/29/05. H-20 performance test conducted on 02/16/06. Report submitted to NMED on 03/23/06. Permit limit proposed in air permit application submitted to NMED on 4/27/06. NMED issued permit 6/23/06. 10 HFNA-000002831 EPA Inspection Report - Page 1282 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements Install next-generation ultralow NOx control on H-101 at Lovington refinery. Operate CEMS or PEMS on H-101 by 12/31/05. CD Paragraph 16.B.i., 16.C.ii., and Appendix C Status/Comment Heater H-101 was removed from service November 2003. Navajo installed NGULNBs in the new Crude Oil Charge Heater (H-103) that replaced H-101. Installation of H-103 was completed during December 2003 turnaround and began operation after 4th Quarter turnaround. As-installed duty of NGULNBs was< 150 MM Btu/hr, but> 100 MM Btu/hr. H-103 initial testing done 03/04/04. Test report, including proposed parametric monitoring plan and permit limits, was submitted 05/14/04. The permit with new limits was approved on 02/21/2006. In 02/2009, Navajo installed eight additional NGULNBs in the Crude Oil Charge Heater (H-103) that replaced H-101. As-installed duty of NGULNBs was> 150 MM Btu/hr, so a NOx CEMS was installed. An initial performance test and the NOx CEMS RATA were conducted 05/21/2009. Pursuant to 40 CFR 60 App F, annual RATA performed 05/20/2010, 08/16/2011, 05/24/2012. RATA was performed 05/14/2013. Certification report submitted to NMED on 06/10/2013. RATA was performed 05/13/2014. Certification report submitted to NMED on 06/12/2014. RATA was performed 05/06/2015. Certification report submitted to NMED on 06/04/2015. RATA was performed 05/04/2016. Certification report submitted to NMED on 06/03/2016. RATA was performed 04/25/2017. Certification report submitted to NMED on 05/16/2017. RATA was performed 02/14/2018. Certification report submitted to NMED on 03/14/2018. RATA was performed 03/05/2019. Certification report submitted to NMED on 04/08/2019. Based on a review, not all QC procedures for heaters and boilers with CEMS may be documented in accordance with 40 CFR 60 App. F. The 4th quarter 2017 Consent Decree progress report inadvertently cross-referenced the entry for Paragraph 11. F. (pertaining to the FCCU) and did not explain that QC procedures for heaters and boilers with CEMS may not have been fully documented. A review of documentation of QC procedures under 40 CFR 60 App F was undertaken. A draft QA/QC manual was prepared and was finalized in January 2019. 11 HFNA-000002832 EPA Inspection Report - Page 1283 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements Install next-generation ultralow NOx control on H-600 and 70-H1/H2/H3 at Artesia refinery. Performance test H600, and 70-H1/H2/H3. Establish compliance indicators by 12/31/09. Install next-generation ultralow NOx control on 8-SG1101A and B-SG-1101 Bat Lovington refinery by 12/31/09. Conduct performance test 8-SG1101A and B-SG-1101 Band establish compliance indicators. CD Paragraph 16.8.i., 16.C.iii., and Appendix C 16.8.i., 16.C.iii., and Appendix C Status/Comment H-600: Air permit 0195-M25-R3 authorizing the burner retrofit was issued by NMED on 05/14/08. The retrofit was completed in 02/2009. The performance test was conducted 03/04/09 and the test report submitted 03/30/09. Administrative permit revision 0195-M26-R1 effective 04/14/2009. 70-H1/H2/H3: NGULNBs were installed in CCR Heaters 70-H1/H2/H3 in May 2006 and heaters resumed operation on 6/2/06. Performance test conducted 7/11/06 and test report submitted 8/15/06. An application for a proposed permit limit was submitted to NMED 9/28/06. NMED issued permit PSD-NM-0195-M25 on 12/14/2007. An air permit application proposing the installation of NGULNBs in SG-1101A and SG-1101 B was submitted to NMED on 12/21/2007. Permit 0273M7 authorizing the retrofit with NGULNBs was issued by NMED on 05/06/2008. Navajo subsequently decided to replace the existing boilers with new boilers using NGULNBs. Permit 0273-M7-R 1 authorizing the replacement boilers was issued by NMED on 10/14/2009. Boiler SG11 OB was permanently shut down on 12/05/2009. Its replacement, 80-1104, began operation on 12/17/2009. Initial performance testing was conducted 01/28/2010 on 80-1104 and the report submitted to NMED on 02/24/2010. Because of initial operating problems with 80-1104, the second boiler, SG-1101A was not permanently shut down until 01/04/2010. Its replacement, BO1105, began operation on 01/15/2010. Initial performance testing was conducted 01/26/2010 on 80-1105 and the report submitted to NMED on 2/24/2010. The 80-1105 initial performance test was conducted on 1/26/2010, and the report submitted to the AQB on 02/24/2010. The BO1104 initial performance test was conducted on 01/28/2010, and the report submitted to the AQB on 02/24/2010. The burners installed with BO1105 and 80-1104, were subsequently found to not meet the NGULNB performance specification in the Consent Decree. The installation of NGULNB in 80-1105 was completed 06/20/2013. The installation of 80-1104 NGULNB was completed 07/29/2013. 80-1105 NOx Performance Test was completed 07/12/2013 and the results were submitted to NMED on 08/06/2013. 80-1104 NOx Performance Test was completed 09/04/2013 and the results were submitted to NMED on 12/05/2013. 12 HFNA-000002833 EPA Inspection Report - Page 1284 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements Submit proposed NOx permit limits within 120 days of NOx control technology installation. CD Paragraph 16.D Status/Comment Requirement completed. B-7: Proposed B-7 NOx limit submitted to NMED 01/31/03. B-8: Proposed B-8 NOx limit submitted to NMED 12/8/03. H-601: Proposed H-601 NOx limit submitted 5/14/04 in stack test report and permitted in 195M17 as issued 12/15/04. H-103 (Lovington Refinery): Proposed H-103 NOx limit submitted 5/14/04 in stack test report; on 2/21/06 NMED issued 0273-M4 to add the NOx limit. After installing additional NGULNBs in 02/2009, the limits were confirmed in the 05/21/2009 test and included in Permit 0273-M7R1 issued by NMED on 10/14/2009. H-20: Proposed H-20 NOx limit submitted to NMED in air permit application on 04/27/06; permit 0195-M24 issued 06/23/06. 70-H1/H2/H3: Proposed 70-H1/H2/H3 NOx limit submitted to NMED in air permit application on 09/28/06; permit PS0-NM-0195-M25 issued 12/14/2007. H-600: Proposed H-600 NOx limit authorized by NMED air permit administrative revision effective on 04/14/09. B0-1104 and B0-1105: (replacement boilers for B-SG-11 OA and B-SG-1101 B). Proposed B0-1104 and B0-1105 NOx limits submitted to NMED in air permit application on 04/13/2010; permit 0273-M8 issued 07/19/2010. 13 HFNA-000002834 EPA Inspection Report - Page 1285 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Submit annual progress report on NOx control technology 16.E First report was submitted 12/19/02. The report for 2003 was submitted 12/29/03 with supplemental information provided 1/8/04. 2004 report submitted 12/31/2004. 2005 report submitted 12/31/2005. 2006 report submitted 12/11/2006. 2007 report submitted 12/20/2007. 2008 report submitted 12/19/2008. 2009 report submitted 12/28/2009. 2010 report submitted 12/15/2010. 2011 report submitted 12/31/2011. 2012 report submitted 12/11/2012. 2013 report submitted 12/18/2013. 2014 report submitted 12/19/2014. 2015 report submitted 12/31/2015. 2016 report submitted 12/30/2016 2017 report submitted 12/28/2017. 2018 report submitted 12/27/2018. D. Section V, Paragraph 17: S02 Emissions Reductions from Heaters and Boilers and NSPS Applicability Requirements CD Status/Comment Paragraph NSPS Subparts A and J 17.B Commenced 12/20/01 become applicable to Heaters See entry for Paragraph 16.B.i., 16.C.ii., and and Boilers by Date of Appendix C on p. 12 of this report regarding 40 Lodging. CFR 60 App. F QC procedures. E. Section V, Paragraphs Requirements SRP shall comply with NSPS J limit and monitor tail gas emissions by Date of Lodging. 18 and 19: NSPS Applicability for SRP and Flaring Devices CD Status/Comment Paragraph 18.C.i. and Commenced 12/20/01. 18.C.ii. See entry for Paragraph 11. F. regarding 40 CFR 60 App. F QC procedures. 14 HFNA-000002835 EPA Inspection Report - Page 1286 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements NSPS Subparts A and J become applicable to Flares by Date of Lodging. CD Paragraph Appendix E Status/Comment Commenced 12/20/01. The recent implementation of flare monitoring requirements under NSPS Ja resulted in the identification and repair of several relief valves that were leaking to the flare. In addition, three flare gas streams with higher sulfur levels were identified as routed to the Lovington flare. These three streams were rerouted to the fuel gas system. As of November 11, 2015, all gas streams currently routed to the flares are monitored for compliance with the NSPS Ja requirements. Excess emission information for the flares at Artesia and Lovington for the semiannual period: January-June 2016 was included in Attachment 4 to the 3rd quarter 2016 Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: July-December 2016 was included in the semiannual NSPS monitoring report submitted on January 30, 2017, and was attached to the 1st quarter 2017 Consent Decree Progress Report. Excess emission information for events occurring during the semiannual period: January-June 2017 was included in the semiannual NSPS Ja monitoring report submitted on July 28, 2017, and was attached to the 3rd quarter Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: July-December 2017 was included in the semiannual NSPS monitoring report submitted on January 30, 2018, and was attached to the 1st quarter 2018 Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: JanuaryJune 2018 was included in the semiannual NSPS monitoring report submitted on July 30, 2018, and was attached to the 3rd quarter 2018 Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: JulyDecember 2018 was included in the NSPS monitoring report submitted on January 30, 2019, and is attached to this 1st quarter Consent Decree Progress Report. Submit AMP plan for Flares FL-400, FL-401, FL-402 and FL-403 within 90 days of Lodging Date. Appendix E Submitted 3/19/02. 15 HFNA-000002836 EPA Inspection Report - Page 1287 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements NSPS Subparts A and J become applicable to Flare FL-1001 at Lovington refinery on 12/31/06. Submit AMP plan for Flare FL-1001 at Lovington refinery by 7/30/07. Submit enhanced Maintenance and Operation plan for SRP (PMO plan) within 270 days of Date of Lodging. Begin optimization study on SRP by 1/1/04. Complete optimization study on SRP and report results by 12/31/04. 10-day prior notice required for scheduled Duke Energy shutdowns affecting Lovington refinery by Date of Lodging. CD Paragraph Appendix E Status/Comment Off-Gas Scrubber system for sweetening sour LPG before combusting in flare completed by 12/31/06. Appendix E An approvable AMP was submitted 02/14/07. AMP is pending EPA approval. 18.D Plan submitted on 9/16/02 and updated on 03/24/05. The last revision was completed on 09/2017 18.E 18.E 19.E Study commenced by 1/1/04 deadline. Navajo retained a third party to coordinate performance testing for the optimization study and prepare a report which was submitted to EPA on 12/31/04. Commenced 12/20/01. F. Section V, Paragraphs 20 and 21: Control of Acid Gas Flaring, Tail Gas Incidents and Hydrocarbon Flaring Requirements CD Paragraph Status/Comment Perform root cause analyses for acid gas and tail gas incidents beginning on Lodging Date. Perform root cause analyses for hydrocarbon flaring incidents beginning on Lodging Date. 20 Commenced 12/20/01. 21 Commenced 12/20/01. G. Section V, Paragraph 22: Benzene Waste NESHAP Requirements CD Paragraph Status/Comment 16 HFNA-000002837 EPA Inspection Report - Page 1288 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements Complete Phase One of the review and verification of the TAB by 9/16/02. CD Paragraph 22.C.i. Status/Comment Completed 09/11/02. Submit BWN Phase One Compliance Review and Verification report for EPA approval by 10/16/02. Submit amended TAB report if BWN Compliance Review shows reporting applied. 22.C.i. Report of results submitted on 10/09/02. 22.D.i. Amended TAB report was included in the 10/09/02 submittal. Establish annual review program 22.E Completed as part of Phase One review and is now ongoing. Train employees who conduct sampling. Submit schematics of Waste/Slop/Off-Spec Oil Management by 03/20/02. Conduct annual sampling of waste streams which the BWN Compliance Review and Verification Report showed to be 0.05 Mg/yr or greater. 22.G and 22.M.ii.a(1) 22.H.i. 22.J.i. and 22.M.ii.a(2) A training plan was developed on 12/06/02 for the Artesia Refinery (i.e., since its TAB is greater than 1.0 Mg/yr). The first training session was held 01/07/03 at both the Artesia and Lovington refineries. The second training session for the two refineries was held 1/27/04 and 01/28/04. Annual refresher training for the two refineries was performed the weeks of 02/08/05, 03/27/06, 03/05/07, 02/25/08 (Lov), 11/07/08 (Art), 12/18/09, 12/17/10 and 12/20/2011. BWON TAB training was conducted on at the Artesia and Lovington refineries on 11/08/2012 01/14/2013 and 04/18/2013, 11/12 to 11/14/2013, 05/24/2014, 06/22/2014, 12/12/2014, 3/16/2015, 4/1/2015, 5/15/2015, 2/29/2016, 3/8/2016, 3/17/2016, 09/25/2017, 11/08/2018, and 11/12/2018. Submitted on 03/19/02. Revised schematics reflecting NSPS QQQ were submitted 04/29/04. Schematics are awaiting approval by EPA. The annual sampling was performed in February 2005. The results were in Attachment 4 to the first quarter 2005 report. Annual sampling performed in February 2006. The results were in Attachment 4 of the first quarter 2006 report. Annual sampling was performed in September and December 2007. The results were submitted in attachment 4 of the first quarter 2008 report as required by ,T22.M.ii.a(2). Annual sampling was performed in December 2008. The results were in attachment 4 of the first quarter 2009 report as required by ,T22.M.ii.a(2). Annual sampling was performed in December 2009. The results were submitted in attachment 4 of the first quarter 2010 report as required by 17 HFNA-000002838 EPA Inspection Report - Page 1289 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements Meet with NMED and EPA at the refinery and submit an annual end of line (EOL) sampling plan - applicable to Artesia Refinery (i.e., TAB is equal to or greater than 1 Mg/yr but less than 10 Mg/yr). CD Paragraph 22.J.ii Status/Comment ,I22.M.ii.a(2). Annual sampling was performed in December 2010. The results were in attachment 4 of the first quarter 2011 report as required by ,I22.M.ii.a(2). Annual sampling was performed in December 2011. The results are in Attachment 4 of the first quarter 2012 report as required by ,I22.M.ii.a(2). Annual sampling was performed in December 2012. The results were submitted in Attachment 4 of the first quarter 2013 report as required by ,I22.M.ii.a(2). Annual sampling was performed in December 2013. The results were submitted in Attachment 4 of the first quarter 2014 report as required by ,I22.M.ii.a(2). Annual sampling was performed in December 2014. The results were submitted in Attachment 4 of the 1st quarter 2015 report as required by ,I22.M.ii.a(2). Annual sampling was performed in December 2015. The results were included in Attachment 4 of the 1st quarter 2016 report as required by ,I22.M.ii.a(2). Annual sampling was performed in October 2016. The results were included in Attachment 4 of the 1st quarter 2017 report as required by ,I22.M.ii.a(2). Annual sampling was performed in December 2017. The results were included in Attachment 4 and 7 of the 1st quarter 2018 report as required by ,I22.M.ii.a(2). Annual sampling was performed in December 2018. The results are included in this 1st quarter 2019 report as required by ,I22.M.ii.a(2). Navajo was notified by NMED and EPA via email dated 12/9/02 that the ,I22.J.ii visit by the agencies would not occur. Navajo met the deadline by submitting the EOL sampling plan on 2/6/03. Conditional approval of the plan was received from EPA by letter dated 1/23/04. Navajo responded by submitting a revised EOL sampling plan by letter dated 3/31/04. 18 HFNA-000002839 EPA Inspection Report - Page 1290 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements Conduct quarterly EOL sampling and submit the results to EPA in quarterly report. CD Paragraph 22.J.iii. and 22.M.ii.a(3) Status/Comment These requirements are not applicable until EPA approves the sampling plan. Although EPA has not approved or commented on the revised sampling plan submitted 03/31/2004, Navajo conducted its first EOL sampling during the week of 3/22/2004. The EOL benzene quantity (BQ) for the fourth quarter of 2004 was 0.8 Mg (projected annual< 10 Mg). The annual TAB, submitted 4/05 was 4.9 M~ for Artesia and 1.5 Mg for Lovington. The 1st, 2n , 3rd, and 4th quarter 2005 EOL BQs were each <2.5 Mg. The 1st, 2nd, 3rd, and 4th quarter 2006 EOL BQs were each <2.5 Mg. The 1st, 2nd, and 3rd quarter 2007 EOL BQs were each <2.5 Mg. The 4tn quarter 2007 EOL BQ result was greater than 2.5 Mg, but the projected 2007 TAB was< 10 Mg. The 1st quarter 2008 EOL BQ result was less than 2.5 Mg. The 2nd and 3rd quarter 2008 EOL BQ results were both greater than 2.5 Mg. The EOL BQ for the 4th quarter of 2008 was <2.5 Mg and the projected 2008 TAB was <10 Mg/yr. The EOL BQ for the 1s1, 2nd, 3rd and 4th quarters of 2009 was <2.5 Mg and the projected 2009 TAB was <10 Mg/yr. The EOL BQ for the 1 1s , 2nd, 3rd, and 4th quarters of 2010 was <2.5 Mg and the projected 2010 TAB was <10 Mg/yr. The EOL BQ for the 1st, 2nd, 3rd and 4th quarters of 2011 was <2.5 Mg and the projected 2011 TAB was <10 Mg/yr. The EOL BQ for the 1st, 2nd, 3rd and 4th quarters of 2012 were each <2.5 Mg and the projected 2012 TAB was <10 Mg/yr. The EOL BQ for the 1st, 2nd, 3rd, and 4th quarters of 2013 were each <2.5 Mg and the projected 2013 TAB was <10 Mg/yr. The projected 2013 TAB was < 10 Mg/yr. The EOL BQ for the 1st, 2nd, 3rd, and 4th quarters of 2014 were each <2.5 Mg and the projected 2014 TAB was <10 Mg/yr. The EOL BQ for the 1st, 2nd, 3rd, and 4th quarters of 2015 were <2.5 Mg and the projected TAB for 2015 was <10 Mg/yr. The EOL BQ for the 1st quarter of 2016 was <2.5 Mg and the projected TAB for 2016 was <10 Mg/yr. The EOL BQ for the 2nd quarter of 2016 was <2.5 Mg and the projected TAB for 2016 was <10 Mg/yr. The EOL BQ for the 3rd quarter of 2016 exceeded 2.5 Mg. As required by paragraph 22.J.iv, Navajo submitted a plan with the fourth quarter Consent 19 HFNA-000002840 EPA Inspection Report - Page 1291 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements CD Paragraph Status/Comment Decree report that identified the specific actions to be taken and the schedule for such actions to ensure that the TAB does not exceed 10 Mg in the calendar year. The EOL BQ for the 4th quarter of 2016 was <2.5 Mg and the projected TAB for 2016 was <10 Mg/yr. The EOL BQ for the 1st quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BQ for the 2nd quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BQ for the 3rd quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BQ for the 4th quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BQ for the 1st quarter of 2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr. The EOL BQ for the 2nd quarter of 2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr. The EOL BQ for the 3rd quarter of 2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr. The EOL BQ for the 4th quarter of 2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr. The EOL BQ for the 1st quarter of 2019 was <2.5 Mg and the projected TAB for 2019 was <10 Mg/yr. H. Section V, Paragraph 23: LOAR Requirements CD Paragraph Develop and maintain written facility-wide LOAR compliance program by 04/19/02. LOAR Training within 1 year of Date of Lodging. 23.A 23.B Status/Comment Completed before 4/19/02. Newly assigned personnel (both 3ra party and Navajo) are receiving training. On going training programs have been implemented. Perform initial LOAR 3rd party/internal audits by 12/20/02 and correct deficiencies. Repeat audits every two years. 23.C and 23.D 3ra party audits for Artesia and Lovington were conducted on 10/2002 and deficiencies were corrected per Paragraph 23.D. 3rd party audits for Artesia and Lovington were performed during 12/2004, 01/2007, 01/2009, and 01/2011. The Artesia and Lovington refineries underwent maintenance turnaround from January to March, 2013. The 2013 LOAR 3rd party audit was conducted from 09/16 to 09/20/2013, after the refinery was back online and normal operation data 20 HFNA-000002841 EPA Inspection Report - Page 1292 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements Valves use 500 ppm leak definition by 2 years after Date of Lodging NSPS Subpart GGG becomes applicable to FCCU wet gas compressor on 12/31/03. Pump monitoring using internal leak definition of 2,000 ppm in accordance with phased-in schedule - i.e., 50% by 6/20/03, 85% by 12/20/03, and 100% by 4/20/05 NSPS Subpart GGG becomes applicable to Crude vent compressor at Lovington refinery as of Date of Lodging. First attempt at repairs on valves that have voe reading > 200 ppm within 90 days of Lodging Date. Quarterly monitoring of valves - no Skip Period by Date of Lodging. LOAR database to include date, time, operator, and instrument within 6 months of Date of Lodging. Submit operational specifications designed to minimize non-electronic data collection and transfer within CD Paragraph 23.E.i. 23.E.iii 23.E.ii.a., b., and c. 23.E.iii 23.G 23.H.ii. 23.1.i. 23.1.ii., and 23.0.i.b. Status/Comment had been collected for 1 complete quarter for comparative monitoring. A copy of the 2013 LOAR 3rd party audit report and resolutions were submitted in Attachment 5 of the 1st Quarter 2014 report. 3rd party audits for Artesia and Lovington were performed during the week of October 5th to 9th, 2015. A copy of the 2015 LOAR 3rd party audit report and resolutions are included in Attachment 5 of the 1st Quarter 2016 report. The 2017 LOAR 3rd party audit was conducted from 05/17 to 05/18/2017. A copy of the audit report was attached to the 3rd Quarter 2017 Consent Decree Progress Report. The audit resolutions were included as Attachment 5 to the 51 1 Quarter 2018 report. Completed prior to 12/20/03. Compressor seal system was upgraded during 2003 FCCU turnaround. Operational beginning December 2003. List of pumps comprising >85% was developed and these pumps are using the 2,000 ppm leak definition for all monitoring subsequent to 12/20/03. All pump monitoring using internal leak definition of 2,000 ppm after 4/20/05. This was completed upon CD lodging. Crude Vent Compressor (C-150A/B) is now included in the LOAR monitoring program. Commenced with January 2002 quarterly monitoring. Completed by 12/20/01. Commenced with May 2002 monitoring. Submitted 6/19/02. 21 HFNA-000002842 EPA Inspection Report - Page 1293 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements 6 months of Date of Lodging CD Paragraph Status/Comment Develop/ implement procedure for LOAR data QA/QC within 90 days of Lodging Date. Establish accountable LOAR personnel by Date of Lodging. Establish tracking program for adding new pumps and valves to LOAR program within 120 days of Date of Lodging Conduct calibration/drift assessments of monitoring instruments at the end of each shift by the Date of Lodging. More stringent delay of repair requirements including drill and tap for valves reading >10,000 ppm by Date of Lodging. Submit written facility-wide LOAR compliance program by 5/19/02. Submit LOAR report with MACT Periodic reports. 23.J 23.K 23.L 23.M 23.N.ii. 23.0.i.a. 23. O.ii.c. Procedure developed on 3/19/02 and included as an appendix in the written LOAR program. Completed by 12/20/01. This program was established by 4/19/02 and is described in the written LOAR program. Commenced on 12/20/01. Commenced on 12/20/01. Submitted 05/13/2002. The monitoring results were incorporated into the periodic reports submitted pursuant to 40 CFR 63.654 on: 3/15/02, 9/13/02, 3/15/03, 9/15/03, 3/15/04, 9/15/04, 3/14/05 (3/15/05 for Lovington), 9/13/05 (9/15/05 for Lovington), 3/17/06, 9/13/06 (9/06/06 for Lovington), 3/16/07, 09/14/07, 3/17/08, 9/12/08, 03/16/09, 08/27/09, 03/16/2010, 09/13/2010, 03/16/2011, 03/09/2012 and 09/06/2012 (09/06/2012 for Lovington), 03/15/2013, 09/16/2013, 02/25/2014 (Artesia), 08/26/2014 (Lovington), 02/26/2015 (Artesia and Lovington), 08/27/2015 (Artesia and Lovington), 02/18/2016 (Artesia and Lovington), 08/29/2016 (Artesia and Lovington), 02/28/2017 (Artesia and Lovington), 08/29/2017 (Artesia and Lovington), 08/30/2018 (Artesia and Lovington), and 02/28/2019 (Artesia and Lovington). 22 HFNA-000002843 EPA Inspection Report - Page 1294 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries I. Section V, Paragraph 24: Incorporate CD Requirements into Enforceable Permits Requirements CD Status/Comment Paragraph Within 180 days of Date of Lodging, submit an application for Federally enforceable NSR permit to incorporate of limits, standards, or schedules effective on the Date of Lodging. Submit applications within 30 days of the effective date or establishment of limits, standards, or schedules pursuant to the CD. 24.A Applications to revise the NSR permits for the Artesia and Lovington refineries were submitted 5/28/02. Permit revision issued for Lovington on 10/15/03. Permit revision for Artesia issued 12/15/04. 24.B Navajo's understanding is that ,T16 NOx limits for boilers and heaters, which require permit application filing within 120 days after start-up under ,T16.D, are not subject to ,T24.B. No other limits under Section V have occurred to date. Section V, Paragraph 25: Requirements Utilize best efforts to obtain construction permits to implement control projects required by the CD. Obtaining Construction Permits CD Paragraph 25 Status/Comment Requirement Completed. The 5/28/02 NSR permit revision application for the Artesia refinery represented the installation of the FCCU wet gas scrubber. Navajo submitted an application to NMED on 4/9/03 to install a new crude heater (H-103) at the Lovington refinery. The permit was issued 10/15/03. H-103 began operation in 12/03. Since heater H-103 replaced H-101 (i.e., the existing crude heater which requires burner retrofit by 12/05 under the CD) and uses NGULNBs, this effectively achieves early implementation of the NOx emission reductions sought by the CD. In order to retrofit heater H-20 with NGULNB by 12/31/05, Navajo submitted a significant revision air permit application to NMED on 04/12/05. Since NMED had not completed the application review, a waiver allowing limited construction activities to begin was granted on 10/11/05. Permit 0195-M21, authorizing NGULNB for H-20, was issued by NMED on 11/18/05. An air permit application proposing the installation of NGULNBs in B0-1105 (formerly SG-1101A) and B0-1104 (formerly SG-1101 B) was submitted to NMED on 12/21/2007. Permit 0273-M? authorizing 23 HFNA-000002844 EPA Inspection Report - Page 1295 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Requirements CD Paragraph Status/Comment the NGULNBs in SG-1101A and SG-1101Bwas issued by NMED on 05/06/2008. Navajo subsequently decided to replace the existing boilers with new boilers using NGULNBs. Permit 0273-M7-R 1 authorizing the replacement boilers was issued by NMED on 10/14/2009. The installation of NGULNB in B0-1105 was completed 06/20/2013. The installation of B0-1104 NGULNB was completed 07/29/2013. H-600: Air permit 0195-M25-R3 authorizing the burner retrofit was issued by NMED on 05/14/08. The retrofit was completed in 02/2009. 3.0 SUMMARY OF ANTICIPATED PROBLEMS IN IMPLEMENTING THE REQUIREMENTS OF SECTION V. None at this time. 4.0 SUMMARY OF EMISSIONS DATA The Boiler B-7 initial performance stack test and CEMS RATA was conducted on 12/18/2002 and the results submitted to the NMED on 01/31/2003. The Boiler B-8 initial performance stack test and CEMS RATA was conducted on 10/29/2003 and the results submitted to the NMED on 12/08/2003. The Heater H-601 initial performance stack test was conducted on 03/02/2004 and the results were submitted to the NMED on 05/14/2004. The Heater H-103 (replacement for H-101) initial performance stack test was conducted on 03/04/2004 and the results were submitted to the NMED on 05/14/2004. Data was collected for reporting pursuant to Paragraph 11 (e.g., FCCU NOx optimization and demonstration period data.) NOx Additive Demonstration Period report with proposed NOx concentration-based limits submitted 07/27/2006. The FCCU Regenerator Scrubber CEMS RATA was conducted on February 14 and 15, 2006 and the results were submitted to the NMED on 03/15/2006. The FCCU Regenerator Scrubber annual PM test was conducted on 02/15/2006 and the results were submitted to the NMED on 03/15/2006. Heater H-20 was retrofit with NGULNBs in December 2005. A performance stack test was conducted on 02/16/2006 and the results were submitted to the NMED on 03/23/2006. Heaters H-352, H-353, and H-354 (formerly identified as 70-H1/H2/H3) were retrofit with NGULNBs in June 2006. A performance stack test was conducted on 07/11/2006 and the results were submitted to the NMED on 08/15/2006. The Boiler B-7and Boiler B-8 annual CEMS RATAs were conducted on 09/26/2006 and the results submitted to the NMED on 10/17/2006. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/24/2007 and the results were submitted to the NMED on 02/22/2007. The FCCU Regenerator Scrubber annual PM test was conducted on 01/24/2007 and the results were submitted to the NMED on 02/22/2007. 24 HFNA-000002845 EPA Inspection Report - Page 1296 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries The Heater H-20 annual performance stack test was conducted on 01/25/2007 and the results were submitted to the NMED on 02/22/2007. The Boiler B-7and Boiler B-8 annual CEMS RATAs were conducted on 09/13/2007 and 09/12/2007 respectively, and the results submitted to the NMED on 10/11/2007. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/22/2008 and the results were submitted to the NMED on 02/18/2008. The FCCU Regenerator Scrubber annual PM test was conducted on 01/22/2008 and the results were submitted to the NMED on 02/18/2008. The Heater H-20 annual performance stack test was conducted on 01/23/2008 and the results were submitted to the NMED on 02/18/2008. The Boiler B-7and Boiler B-8 annual CEMS RATAs were conducted on 09/09/2008 and the results submitted to the NMED on 10/09/2008. The FCCU Regenerator Scrubber CEMS RATA was conducted on 03/03/2009 and the results were submitted to the NMED on 03/30/2009. The FCCU Regenerator Scrubber annual PM test was conducted on 03/03/2009 and the results were submitted to the NMED on 03/30/2009. Heater H-600 was retrofit with NGULNBs in 02/2009. The Heater H-600 initial performance stack test was conducted on 03/04/2009 and the results were submitted to the NMED on 03/30/2009. The Heater H-20 annual performance stack test was conducted on 03/05/2009 and the results were submitted to the NMED on 03/30/2009. After adding additional burners, the Heater H-103 (replacement for H-101) performance stack test and NOx CEMS RATA was conducted on 05/21/2009 and the results were submitted to the NMED on 06/22/2009. The Boiler B-7and Boiler B-8 annual CEMS RATAs were conducted on 09/17/2009 and the results submitted to the NMED on 10/14/2009. The B0-1105 (replacement boiler for Lovington boiler BSG-1101 A) initial performance testing was conducted 01/26/2010 and the report submitted to NMED on 02/24/2010. The B0-1104 (replacement boiler for Lovington boiler BSG-1101 B) initial performance testing was conducted 01/28/2010 and the report submitted to NMED on 02/24/2010. The FCCU Regenerator Scrubber CEMS RATA was conducted on 03/02 and 03/2010 and the results were submitted to the NMED on 04/05/2010. The FCCU Regenerator Scrubber annual PM test was conducted on 03/02 and 03/2010 and the results were submitted to the NMED on 04/05/2010. The Heater H-20 annual performance stack test was conducted on 03/04/2010 and the results were submitted to the NMED on 04/05/2010. The Heater H-103 (replacement for H-101) NOx CEMS RATA was conducted on 05/19/2010 and 05/20/2010, and the results were submitted to the NMED on 06/16/2010. The Boiler B-7and Boiler B-8 annual CEMS RATAs were conducted on 08/24/2010 and the results submitted to the NMED on 09/14/2010. The FCCU Regenerator Scrubber CEMS RATA was conducted on 03/01/2011 and the results were submitted to the NMED on 03/28/2011. The FCCU Regenerator Scrubber annual PM test was conducted on 03/01/2011 and the results were submitted to the NMED on 03/28/2011. The Heater H-20 annual performance stack test was conducted on 03/02/2011 and the results were submitted to the NMED on 03/28/2011. The Boiler B-7and Boiler B-8 annual CEMS RATA's were conducted on 08/16/2011 and the results submitted to the NMED on 09/16/2011. 25 HFNA-000002846 EPA Inspection Report - Page 1297 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries The Heater H-103 (replacement for H-101) NOx CEMS RATA was conducted on 05/3/2011 and the results were submitted to the NMED on 05/31/2011. The Heater H-20 annual performance stack test was conducted on 01/19/2012 and the results were submitted to the NMED on 02/27/2012. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/17/2012. Report showing certification submitted to NMED on 02/17/2012. The FCCU Regenerator Scrubber annual PM test was conducted on 01/17/2012. Report showing certification submitted to NMED on 02/17/2012. The Heater H-103 (replacement for H-101) NOx CEMS RATA was conducted on 05/24/2012, and the results were submitted to the NMED on 06/20/2012. The Boiler B-7and Boiler B-8 annual CEMS RATA's were conducted on 08/15/2012 and the results submitted to the NMED on 09/13/2012. The Heater H-20 annual performance stack test was conducted on 01/09/2013 and the results were submitted to the NMED on 02/07/2013. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/08/2013. Report showing certification submitted to NMED on 02/07/2013. The FCCU Regenerator Scrubber annual PM test was conducted on 01/08/2013. Report showing certification submitted to NMED on 02/07/2013. The Heater H-103 (replacement for H-101) NOx and CO CEMS RATA was conducted on 05/14/2013, and the results were submitted to the NMED on 06/10/2013. The FCCU Regenerator Scrubber annual PM was retested on 03/05/2013. Report showing certification submitted to NMED on 04/01/2013. The Boiler B-7annual CEMS RATA's was conducted on 08/07/2013 and the results submitted to the NMED on 09/17/2013. The Boiler B-8 annual CEMS RATA's was conducted on 08/06/2013 and the results submitted to the NMED on 09/17/2013. The Heater H-20 annual performance stack test was conducted on 01/09/2014 and the results were submitted to the NMED on 02/04/2014. The FCCU Regenerator Scrubber annual PM was tested on 01/08/2014. Report showing certification submitted to NMED on 02/04/2014. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/08/2014. Report showing certification submitted to NMED on 02/04/2014. After the installation of NGULNB was completed, the B0-1105 (replacement boiler for Lovington boiler BSG-1101A) initial performance testing was conducted 07/12/2013 and the report submitted to NMED on 08/06/2013. After the installation of NGULNB was completed, the B0-1104 (replacement boiler for Lovington boiler BSG-1101 B) initial performance testing was conducted 09/04/2013 and the report submitted to NMED on 12/05/2013. The Heater H-103 (replacement for H-101) NOx and CO CEMS RATA was conducted on 05/13/2014, and the results were submitted to the NMED on 06/12/2014. The Boiler B-7annual CEMS RATA's was conducted on 07/30/2014 and the results submitted to the NMED on 09/11/2014. The Boiler B-8 annual CEMS RATA's was conducted on 07/29/2014 and the results submitted to the NMED on 09/11/2014. The Heater H-20 annual performance stack test was conducted on 02/17/2015 and the results were submitted to the NMED on 03/09/2015. The FCCU Regenerator Scrubber annual PM was tested on 01/06/2015. Report showing certification submitted to NMED on 02/05/2015. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/06/2015. Report showing certification submitted to NMED on 02/05/2015. 26 HFNA-00000284 7 EPA Inspection Report - Page 1298 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries The Heater H-103 (replacement for H-101) NOx and CO CEMS RATA was conducted on 05/06/2015, and the results were submitted to the NMED on 06/04/2015. The Boiler B-7 annual CEMS RATA's was conducted on 07/23/2015 and the results submitted to the NMED on 08/20/2015. The Boiler B-8 annual CEMS RATA's was conducted on 07/22/2015 and the results submitted to the NMED on 08/20/2015. The Heater H-20 annual performance stack test was conducted on 01/07/2016 and the results were submitted to the NMED on 02/05/2016. The FCCU Regenerator Scrubber annual PM was tested on 01/05/2016. Report showing certification submitted to NMED on 02/04/2016. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/05/2016. Report showing certification submitted to NMED on 02/04/2016. The Heater H-103 (replacement for H-101) NOx and CO CEMS RATA was conducted on 05/04/2016, and the results were submitted to the NMED on 06/03/2016. The Boiler B-7 annual CEMS RATA's was conducted on 07/13/2016 and the results submitted to the NMED on 08/05/2016. The Boiler B-8 annual CEMS RATA's was conducted on 07/13/2016 and the results submitted to the NMED on 08/05/2016. The Heater H-20 annual performance stack test was conducted on 01/05/2017 and the results were submitted to the NMED on 02/03/2017. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/03/2017. Report showing certification submitted to NMED on 02/03/2017. The FCCU Regenerator Scrubber annual PM was conducted on 01/03/2017. Report showing certification submitted to NMED on 02/04/2017. The Boiler B-7 annual CEMS RATA's was conducted on 06/21/2017 and the results submitted to the NMED on 06/20/2017. The Boiler B-8 annual CEMS RATA's was conducted on 06/21/2017 and the results submitted to the NMED on 06/20/2017. The Heater H-103 (replacement for H-101) NOx and CO CEMS RATA was conducted on 04/25/2017, and the results were submitted to the NMED on 05/16/2017. The Heater H-20 annual performance stack test was conducted on 01/11/2018 and the results were submitted to the NMED on 02/09/2018. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/09/2018. Report showing certification submitted to NMED on 02/09/2018. The FCCU Regenerator Scrubber annual PM stack test was conducted on 01/09/2018. Report showing certification submitted to NMED on 02/09/2018. The Boiler B-7 annual CEMS RATA's was conducted on 03/06/2018 and the results submitted to the NMED on 03/29/2018. The Boiler B-8 annual CEMS RATA's was conducted on 03/07/2018 and the results submitted to the NMED on 03/29/2018. The Heater H-103 (replacement for H-101) NOx and CO CEMS RATA was conducted on 02/14/2018, and the results were submitted to the NMED on 03/14/2018.The Heater H-20 annual performance stack test was conducted on 02/20/2019 and the results were submitted to the NMED on 03/21/2019. The FCCU Regenerator Scrubber CEMS RATA was conducted on 02/13/2019. Report showing certification submitted to NMED on 03/23/2019. The FCCU Regenerator Scrubber annual PM stack test was conducted on 02/13/2019. Report showing certification submitted to NMED on 03/23/2019. The Boiler B-7 annual CEMS RATA's was conducted on 03/19/2019 and the results submitted to the NMED on 04/18/2019. 27 HFNA-000002848 EPA Inspection Report - Page 1299 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries The Boiler 8-8 annual CEMS RATA's was conducted on 03/19/2019 and the results submitted to the NMED on 04/18/2019. The Heater H-103 (replacement for H-101) NOx and CO CEMS RATA was conducted on 03/05/2019, and the results were submitted to the NMED on 04/08/2019. Consistent with past reports, any emissions excursions from Consent Decree limits have generally been reported to NMED pursuant to the NSPS, MACT and/or Title V programs semiannually (as well as pursuant to NMED's excess emissions reporting program). We are in this report identifying emissions excursions that occurred in the 4th quarter 2018 for the emission limits and units below. For the flares at Artesia and Lovington, excess emission information for events occurring during the semiannual period: July-December 2018 was included in the semiannual NSPS Ja monitoring report submitted on January 30, 2019, and is attached to this 1st quarter Consent Decree Progress Report. Consent Decree Condition V.18. B: SRU S02 Emission limits SRU-2 S02 250 ppm 12-hr average Start Time 2019-01-0510:00 2019-01-0513:00 2019-01-21 21 :00 2019-01-26 15:00 2019-01-28 17:00 2019-03-12 20:00 End Time 2019-01-0512:00 2019-01-0514:00 2019-01-22 09:00 2019-01-27 03:00 2019-01-29 03:00 2019-03-1315:00 Excess Emissions per Event (lbs) 0.47 0.16 14.40 22.31 9.84 76.60 5. Implementation of ENVIRONMENTALLY beneficial Projects [Changes from Prior Quarter Italicized] Paragraph 35 requires certain information to be submitted for each project which has been completed. The projects for Paragraphs 30 and 32 have been completed. The following summarizes the status of the completed and ongoing projects, and highlights actions taken thus far: A. Section V, Paragraph 29: Refinery-wide Compliance with NSPS Subpart QQQ Environmentally Beneficial CD Status/Comment Project Paragraph Submit Compliance Plan 29.A The plan was submitted on within 180 days of CD Date of May 29, 2002 Lodging. 28 HFNA-000002849 EPA Inspection Report - Page 1300 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Environmentally Beneficial Project NSPS QQQ becomes applicable to Artesia and Lovington individual drain systems, oil-water separators, and aggregate facilities by 12/31/03 CD Paragraph 29.B Status/Comment Prior to 12/31/03, Navajo began operation of the new covered wastewater separator, completed the bypass of the South Plant API, installed covers on junction boxes and initiated drain inspections for the Artesia refinery. Junction boxes at the Lovington refinery were also covered and the routine inspection of drains (to assure proper water seal) was begun. Navajo otherwise ceased the use of an open culvert for draining oily process wastewater into the sewer. In early September 2010, it was discovered that the storm water catch basin of the Alkylation Unit Tar Pit could still receive some oily-water and therefore could be considered as a junction box. A cover for the storm water basin was designed, constructed, and installed by 11/12/2010. In July 2014, it was discovered that visual inspections were not conducted initially and semiannually as required by 40CFR 60.692-2 (07/11/2014 self-disclosure letter to NMED. Certified Receipt Number: 70073020000030288246). Navajo Started semiannual inspections on 07/01/2015. A third party review of the QQQ program indicated that there may be a potential issue regarding certain aspects of the drain systems at the refinery, in particular, the status of catch basins in these drain systems. Subpart QQQ exempts drain systems that have catch basins in their existing configuration prior to the rule's applicability date. Navajo is nevertheless evaluating the proactive retrofit of these catch basins with covers (inserts), and has initiated a capital project to address this. Retrofit work is currently scheduled to begin shortly. 29 HFNA-000002850 EPA Inspection Report - Page 1301 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries B. Section V, Paragraph 30: Operation of the 40 LTPD SRU (SRU1) on Standby Artesia SRP (No SRU at Lovington): Environmentally Beneficial Project Complete installation of equipment on SRU1 to allow operation in standby service by 12/31/03 CD Paragraph 30 Status/Comment SRU1 was started up again on 5/10/03 operating at a reduced rate in backup service. A new 100 long ton per day sulfur recovery unit (SRU3) began operating 05/11/2009. The combined capacity of SRU2 and SRU3 provides excess sulfur recovery capacity. Therefore, as an energy and emissions conservation measure, SRU1 is no longer operated in standby service. Complete study plan on how to limit excess TGU emissions and Acid Gas Flaring by 2/28/04 30 Acid Gas Flaring and TGU Excess Emissions Study Plan submitted 2/27/04. Pursuant to the plan, Navajo completed the study and submitted a 3/24/05 summary of the study including actions taken and recommendations. The study results were used to update the PMO plan with the modified PMO plan included with the 3/24/05 submittal. C. Section V, Paragraph 31: Installation of Spare FCCU Wet Gas Compressor Artesia FCCU (No FCCU at Lovington): Environmentally Beneficial CD Status/Comment Project Paragraph Complete installation of spare 31 A spare wet gas compressor was installed during wet gas compressor by the 4th Quarter of 2003 FCCU turnaround. 12/31/03. Operate so as to On 01/07/2011, Navajo's outside legal counsel minimize the duration of AG submitted a request to modify or remove this or HC flaring incidents during paragraph. Operating procedures to minimize the outages of the original duration of AG flaring were updated 04/30/2015. compressor. A preventive maintenance plan for the spare compressor C-0950 was completed on 05/11/2015. 30 HFNA-000002851 EPA Inspection Report - Page 1302 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries D. Section V, Paragraph 32: Supplemental Environmental Project (SEP) Benefiting the Artesia Community Environmentally Beneficial CD Status/Comment Project Paragraph Complete implementation of SEP to benefit the Artesia community by June 30, 2003 32 Navajo completed the community SEP prior to the revised 9/29/03 deadline and submitted cost certification data on 9/23/03 pursuant to Paragraph 91. The SEP installed mechanical mixers to replace air mixers on nine asphalt storage tanks to reduce odors. The tanks were T-0110, T-0404, T-0405, T- 0406, T-0409, T-0410, T-0428, T-0431, and T- 0432. T-0404, T-0405, T-0406, and T-0409, and T-0428 have been permanently removed from service. E. Section V, Paragraph 33: EMS Baseline Assessment for Artesia Refinery Environmentally Beneficial CD Status/Comment Project Paragraph Obtain NMED approval for Independent Contractor to perform the baseline assessment Execute contract with Independent Contractor Baseline Assessment Report to be received by Navajo within 210 days of Date of Lodging Navajo to implement recommendations in accordance with the baseline report schedule 33.C Completed via letter from NMED dated 4/19/02. 33.D 33.E 33.F Completed as of 4/15/02 Navajo received the baseline assessment report on 7/17/02. Navajo has accepted the recommendations and schedule deadlines provided in the baseline report (the 8 recommendations are numbered in parenthesis in the discussion below). For the two (i.e., 1A and 5) recommendations with 10/1/02 deadlines, Navajo implemented both on time (i.e., prior to the deadline). The report to file required by CD ,T33.F.ii was completed 12/27/02. Navajo to implement recommendations in accordance with the baseline report schedule -Cont'd 33.F Navajo did the roll-out of the refinery environmental policy (1 B) and put environmental responsibilities (3) into a new specifically developed operator's manual prior to the baseline report recommendation deadline (i.e., 2/1/03 and 3/1/03, respectively). 31 HFNA-000002852 EPA Inspection Report - Page 1303 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries Environmentally Beneficial Project Navajo to implement recommendations in accordance with the baseline report schedule -Cont'd CD Paragraph 33.F Status/Comment The position descriptions (6) which were recommended for Navajo's Environmental Affairs Department staff were prepared and distributed prior to the 7/1/03 deadline. An independent consultant performed an on-site evaluation of Navajo's implementation of the recommendations and prepared a 6/23/03 evaluation report prior to the 6/30/03 deadline. Navajo to implement recommendations in accordance with the baseline report schedule -Cont'd Navajo to implement recommendations in accordance with the baseline report schedule -Cont'd Navajo to implement recommendations in accordance with the baseline report schedule -Cont'd 33.F 33.F 33.F Per the independent consultant's June 2003 evaluation report, the 9/1/03 original deadline for the recommended CBT training module (2) was revised to 3/1/04. Work commenced in November 2003 on developing the CBT training module (2). The CBT module was completed and rolled out on 2/27/04, thus meeting the 3/1/04 deadline. The decision was made to implement (7) via the electronic option (6/1/04 deadline). Recommendation No. SA, "Develop Environmental Records Retention Policy and Document Control Procedures" was implemented prior to the 12/1/03 deadline. Completed the evaluation of the LOAR program, process and procedures (4) on 6/3/04 and determined that the program is working as intended. Integrated compliance requirements calendar (7) was implemented prior to the 6/1/04 deadline. Completed work to implement the environmental records management system (88) during May 2004 with the aid of an outside consultant. The records management system is in place and working. An independent consultant conducted the implementation evaluation presented in a June 30, 2004 report, thus meeting the deadline. A final closure letter on the EMS improvement recommendations was issued September 30, 2004 by the consultant concluding no remaining EMS improvement actions for Navajo. 32 HFNA-000002853 EPA Inspection Report - Page 1304 of 1969 Calendar Quarterly Report - 1st Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries 6.0 OTHER MATTERS The recent implementation of flare monitoring requirements under NSPS Ja resulted in the identification and repair of several relief valves that were leaking to the flare. In addition, three flare gas streams with higher sulfur levels were identified as routed to the Lovington flare. These three streams were rerouted to the fuel gas system. As of November 11, 2015, all gas streams currently routed to the flares are being monitored for compliance with the NSPS Ja requirements. Excess emission information for the flares at Artesia and Lovington for the semiannual period: January-June 2016 was included in Attachment 4 to the 3rd quarter 2016 Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: July-December 2016 was included in the semiannual NSPS monitoring report submitted on January 30, 2017, and was attached to the 1st quarter 2017 Consent Decree Progress Report. Excess emission information for events occurring during the semiannual period: January-June 2017 was included in the semiannual NSPS Ja monitoring report submitted on July 28, 2017, and was attached to the 3rd quarter Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: January-June 2018 was included in the semiannual NSPS Ja monitoring report submitted on July 30, 2018, and was attached to the 3rd quarter 2018 Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: July-December 2018 was included in the semiannual NSPS Ja monitoring report submitted on January 30, 2019, and is attached to this 1st quarter Consent Decree Progress Report. 33 HFNA-000002854 EPA Inspection Report - Page 1305 of 1969 ATTACHMENT 1 APPENDIX G SUMMARY REPORTS HFNA-000002855 EPA Inspection Report - Page 1306 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 1st QUARTER2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT REPORTS, PLANS AND CERTIFICATIONS UNDER THE BENZENE WASTE NESHAP ENHANCED PROGRAM PROVISIONS OF PARAGRAPH 22 OF THE CONSENT DECREE IN UNITED STATES ET AL. V. NAVAJO REFINING CO. ET AL. Name or Summary ofthe Re12ort, Plan, or Certification BWN Compliance Review and Verification Report CD SubPara No. C.i. Rqd. ("R") v. Contingent ("C") One-Time ("l ") V. Quarterly orw/ 63.654 Reports ("> l ") R ] Due Date 270 days after Lodging Review completed 09/11/2002. Report submitted l 0/09/2002 Status AmendedBWN C.ii. C l Compliance Review and Verification Report 90 days after completing additional sampling requested by EPA Not Yet Applicable. EPA has not requested additional sampling. Amended TAB Report D.i C 1 60 days after completing BWN Compliance Review and Verification Report An Amended Report for the Artesia Refinery(> 1 Mg, <10 Mg) was Submitted 10/09/2002 with the Verification Report Plan to comply w/ 6 BQ D.ii; C 1 if TAB equals or is J.vi. greater than ] 0 180 days after completing BWN Compliance Review and Verification Report Not Applicable unless the Artesia or Lovington Refinery exceeds 10 Mg/yr in the annual TAB report Page 1 of 12 HFNA-000002856 EPA Inspection Report - Page 1307 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 1st QUARTER2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT Name or Summary of the Re11ort, Plan, or Certification Compliance Certification Waste/Slop/Off-Spec Oil Schematics Submit revised Waste/Slop/Off-Spec Oil Schematics reflecting agreement with EPA on comments. Schedule to complete installation of controls on waste management units handling organic benzene waste Plan to quantify uncontrolled waste/slop/off-spec oil movements CD SubPara No. D.iv H.i. H.i. H.ii. H.iv. Rqd. ("R") v. Contingent ("C") One-Time ("l ") V. Quarterly orw/ 63.654 Reports ("> l ") C l R l C l C l R l Due Date 30 days after completing all actions necessary to come into compliance 90 days after Lodging Mutually-agreed upon time between Navajo and/or Montana Refining and EPA Mutually-agreed upon time between Navajo and/or Montana Refining and EPA, not to exceed 2 years 90 days after EPA has approved schematics Status Not Applicable unless the Artesia or Lovington Refinery exceeds 10 Mg/yr in the annual TAB report. Submitted on 03/19/2002. Revised plan reflecting plant modifications submitted 04/29/2004. Schematics are awaiting written approval by EPA. Not Applicable until EPA confers with Navajo on the Waste/Slop/Off-Spec Oil Schematics. Not Applicable unless the Artesia or Lovington Refinery exceeds 10 Mg/yr in the annual TAB report Not Applicable until EPA provides written approval of the Waste/Slop/OffSpec Oil Schematics. Although EPA has not commented on or approved the schematics submitted under paragraph 22.H.i, Navajo has quantified the uncontrolled waste/slop/off-spec oil movements in the annual NESHAP Subpart FF Total Annual Benzene (TAB) report. Page 2 of 12 HFNA-000002857 EPA Inspection Report - Page 1308 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 1st QUARTER2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT Name or Summary of the Re11ort, Plan, or Certification EOL Sampling Plan EOL Revised Sampling Plan Applicable after refinery TAB exceeds 10 Mg/yr Plan to ensure that uncontrolled benzene does not equal or exceed, 6 Mg/yr or that it is minimized CD SubPara No. I.i; J .ii I.ii; J.ii. I.vii; Rqd. ("R") v. Contingent ("C") One-Time ("l ") V. Quarterly orw/ 63.654 Reports ("> l ") C l C As needed C As needed Due Date 2 months after the 22.D.iii Certification (if TAB is 10 mg/yr or greater); 90 days after submitting final BWN Compliance Reviewand Verification Report (if TAB is l Mg/yr or more but less than 10) If and when Navajo and/or Montana Refining become aware of factors indicating original plan no longer accurately reflects EOL benzene quantity 30 days after the end of the quarter in which the projected calendar year benzene quantity is equal to or greater than 6 Mg. Status EOL Sampling Plan submitted on 02/06/2003. Revised EOL Sampling Plan submitted 03/31/2004. Not Applicable unless the Artesia or Lovington Refinery exceeds 10 Mg/yr in the annual TAB report. Page 3 of 12 HFNA-000002858 EPA Inspection Report - Page 1309 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 1st QUARTER2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or Certification CD SubPara No. Applicable if refinery J.iv- TAB is > 1 but < 10 J.v Mg/yr - Plan to ensure that uncontrolled benzene does not equal or exceed, as applicable, 10 Mg/yr or that it is minimized Rqd. ("R") v. Contingent ("C") One-Time ("l ") V. Quarterly orw/ 63.654 Reports ("> l ") C As needed Due Date Status 30 days after the end of the quarter in which the projected calendar year benzene quantity is equal to or greater than 10 Mg. The 2007 4th quarter EOL benzene quantity exceeded 2.5 Mg, but the calendar year 2007 TAB did NOT exceed 10 Mg. Because the calendar year is over, and the TAB did not exceed IO Mg in the calendar year, submittal of a plan to prevent the calendar year TAB from exceeding 10 Mg, as required under 122.J.iv, becomes moot. As required by 1 22.M.ii.a(3), Navajo specifically sought EPA's concurrence with this interpretation but no response has been received. The EOL BQ for the 1st quarter of 2008 was <2.5 Mg and the projected 2008 TAB was < 10 Mg/yr so no plan was required. The EOL BQ for the 2nd quarter of 2008 was> 2.5 Mg and the projected tab was > l OMg/yr. The required plan \Vas included as a supplement to the 2nd quarter report. Navajo specifically sought EPA's concurrence with this plan but no response has been received. The EOL BQ for the 3rd quarter of2008 was> 2.5 Mg and the projected tab was> 10 Mg/yr (see Attachment 3). The required plan was included as a supplement to the 3rd quarter report. As required by 122.M.ii.a(3), Navajo specifically sought EPA's concurrence with this plan but no response has been received. The EOL BQ for the 4th quarter of 2008 \Vas <2.5 Mg and the projected 2008 TAB was < 10 Mg/yr so no plan was required. The EOL BQs for the l si, 211d, 3rd and 4th quarters of 2009 were <2.5 Mg and the projected 2009 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the 1si, 211d, 3', and 4th quarters of 20 l Owas <2.5 Mg and the projected 2010 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the ls\ 2nd, 3rd and 4th quarters of20ll was <2.5 Mg and the projected 2010 TAB was< 10 Mg/yr so no plan is required. The EOL BQ for the ls\ 2nd, 3rd and 4th quarters of2012 was <2.5 Mg and the projected 2010 TAB was< 10 Mg/yr so no plan is required. The EOL BQ for the ls\ 2nd, 3rd and 4th quarters of2013 were each <2.5 Mg Page 4 of 12 HFNA-000002859 EPA Inspection Report - Page 1310 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 1st QUARTER2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT Name or Summary ofthe Re11ort, Plan, or Certification CD SubPara No. Rqd. ("R") v. Contingent ("C") One-Time ("l ") V. Quarterly orw/ 63.654 Reports ("> l ") Due Date Status and the projected 2012 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the l st and 211d quarters of 2014 was <2.5 Mg and the projected 2014 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the ls\ 211d, 3rd' and 4th quarters of2014 were <2.5 Mg and the projected 2014 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the 1st quarter of2015 was <2.5 Mg and the projected 2015 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the 211d quarter of 2015 was <2.5 Mg and the projected 2015 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the 2nd quarter of 2015 was <2.5 Mg and the projected 2015 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the 3rd quarter of 2015 was <2.5 Mg and the projected 2015 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the 4th quarter of 2015 was <2.5 Mg and the projected 2015 TAB was < l O Mg/yr so no plan was required. The EOL BQ for the 1st quarter of2016 was <2.5 Mg and the projected 2016 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the 2nd quarter of 2016 was <2.5 Mg and the projected 2016 TAB was < l OMg/yr so no plan was required. The EOL BQ for the 3rd quarter of 2016 exceeded 2.5 Mg but the calendar year 2016 TAB did NOT exceed 10 Mg. As the firsttwo quarters of2016 indicated significantly lower concentrations of benzene in the wastewater, the projected TAB remained below 10 Mg for the calendar year, and as such no specific actions need to be taken to ensure the TAB does not exceed lOMg. Regardless of that, however, Navajo developed a plan of targeted monitoring to help identify and address the benzene contributions during the third quarter. The plan was implemented by November 4, 2016 (attachment 4). Page 5 of 12 HFNA-000002860 EPA Inspection Report - Page 1311 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 1st QUARTER 2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT Name or Summary of the Regort. Plan, or Certification CD SubPara No. Rqd. ("R") v. Contingent ("C") One-Time ("l ") V. Quarterly orw/ 63.654 Reports ("> l ") Due Date Status The EOL BQ for the 4th quarter of 2016 was <2.5 Mg and the projected TAB for 2016 was <10 Mg/yr. The EOL BQ for the l st quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BQ for the 2nd quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BQ for the 3rd quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BQ for the 4th quarter of2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BQ for the 1st quarter of 2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr, so no plan was required. The EOL BQ for the 2nd quarter of 2018 \Vas <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr, so no plan was required. The EOL BQ for the 3rd quarter of 2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr, so no plan was required. The EOL BQ for the 4th quarter of 20 l 8 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr, so no plan was required. The EOL BQ for the 1st quarter of 2019 was <2.5 Mg and the projected TAB for 2019 was <10 Mg/yr, so no plan was required. Page 6 of 12 HFNA-000002861 EPA Inspection Report - Page 1312 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 1st QUARTER2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT Name or Summary of the Re11ort, Plan, or Certification Proposal for Third-Party TAB Study and Compliance Review Third-Party TAB Study and Compliance Review Plan to implement the results ofthe Third-Party TAB Study and Compliance Review CD SubPara No. I-viii; J.vi I... vm; J.vi J.vi; Rqd. ("R") v. Contingent ("C") One-Time ("l ") V. Quarterly orw/ 63.654 Reports ("> l ") C l C l C l Due Date Last day of 4th Quarter as set forth in il I.viii. (if TAB is 10 mg/yr or greater); As agreed by EPA and Navajo and/or Montana Refining (if TAB is l Mg/yr or more but less than 10) 30 days after receipt of the Third-Party Study and Compliance Review 120 days after receipt of the Third-Party TAB Study and Compliance Review Status Not Applicable unless refinery cannot take actions to keep TAB below 10 Mg/yr. Not Applicable unless refinery cannot take actions to keep TAB below 10 Mg/yr. Not Applicable unless refinery cannot take actions to keep TAB below 10 Mg/yr. Page 7 of 12 HFNA-000002862 EPA Inspection Report - Page 1313 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 1st QUARTER2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT Name or Summary ofthe Re11ort, Plan, or Certification Report on training done in that Quarter CD SubPara No. G.i- ... m.; Miia(l) Rqd. ("R") v. Contingent ("C") One-Time ("l ") V. Quarterly orw/ 63.654 Reports ("> l ") C Q Due Date Each Quarterly Report due under the Consent Decree Status A training plan was developed 12/6/02 for the Artesia Refinery (i.e., since its TAB is greater than 1.0 Mg/yr). The first training session was held 1/7/03 at both the Artesia and Lovington refineries. The second training session for the two refineries \Vas held 1/27/04 and 1/28/04. Annual refresher training performed the weeks of 2/8/05, 3/27/06, 3/5/07, 2/25/08 (Lov), 11/07/08 (Art), 12/18/09, 12/17/2010 and 12/20/2011, 11/08/2012, 01/14/2013, 04/18/2013 11/12 to 11/14/2013, 05/24/2014, 06/19/2014, 06/20/2014, 12/02/2014, 3/16/2015, 4/1/2015, 5/15/2015, 2/29/2016, 3/8/2016, 3/17/2016 (Art. and Lov), 02/28/2017 (Artesia and Lovington), 08/29/2017 (Artesia and Lovington), 09/30/2018 (Artesia and Lovington) and 02/28/2019 (Artesia and Lovington). Page 8 of 12 HFNA-000002863 EPA Inspection Report - Page 1314 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 1st QUARTER2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT Results of annual J.i; C Q sampling of>0.05 Mg/yr Mii- benzene streams a(2) In the first Quarterly Report for the first calendar quarter of each year TI1e annual sampling was performed in Febmary 2005. The results were presented with the first quarter 2005 report. Annual sampling was performed in Febmary 2006. The results were presented in Attachment 4 with the first quarter 2006 report. Annual sampling was performed in September and December 2007. The results were submitted in attachment 4 ofthe first quarter 2008 report as required by i122.M.ii.a(2). Annual sampling was performed in December 2008. The results \Vere submitted in attachment 4 of the first quarter 2009 report as required by iJ22.M.ii.a(2). Annual sampling was performed in December 2009. The results were submitted in Attachment 4 of the first quarter 2010 report as required by ,22.M.ii.a(2). Annual sampling was performed in December 2010. The results were submitted in Attachment 4 ofthe first quarter 2011 report as required by ,22.M.ii.a(2). Annual sampling was performed in December 2011. The results \Vere submitted in Attachment 4 ofthe first quarter 2012 report as required by iJ22.M.ii.a(2). Annual sampling was perfonned in December 2012. The results were submitted in Attachment 4 ofthe first quarter 2013 report as required by ,22.M.ii.a(2). Annual sampling was performed in December 2013. The results were submitted in Attachment 4 ofthe first quarter 2014 report as required by ,22.M.ii.a(2). Annual sampling was performed in December 2014. The results were submitted in Attachment 4 of the 1stquarter 2015 report as required by iJ22.M.ii.a(2). Page 9 of 12 HFNA-000002864 EPA Inspection Report - Page 1315 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 1st QUARTER2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT Results of annual J.i; C Q sampling of>0.05 Mg/yr Mii- benzene streams a(2) In the first Quarterly Report for the first calendar quarter of each year Annual sampling was performed in December 2015. TI1e results were included in Attachment 4 of the l stquarter 2016 report as required by ,122.M.ii.a(2). Annual sampling was performed in October 2016. The results were included in Attachment 4 of the 1st quarter 2017 report as required by i122.M.ii.a(2). Annual sampling was perfonned in December 2017. The results were included in Attachment 4 of the 1st quarter 2018 report as required by ,22.M.ii.a(2). Annual sampling was performed in December 2018. The results are included in this l st quarter 2019 report as required by iJ22.M.ii.a(2). Results of Quarterly EOL J.iii; C Q Sampling M.ii. a(3); M.ii- b(2) Each Quarterly Report due under the Consent Decree (after written EPA a1212roval of EOL sampling plan) 2004: Under the assumption that the sampling plan was accepted by EPA upon the 03/31/2004 submittal ofthe revised EOL Sampling Plan, Navajo conducted its first EOL sampling during the week of 3/22/04. The annual TAB, submitted 4/05 \Vas 4.9 Mg for Artesia and 1.5 Mg for Lovington. 2005: TI1e EOL benzene quantity (BQ) for the ls\ 2nd, 3rd, and 4th quarter of 2005 were each <2.5 Mg. 2006: The EOL BQ for the l si, 2nd, 3rd, and 4th quarters of 2006 were each <2.5 Mg. 2007: The ls\ 2nd, and 3rd quarter 2007 EOL BQs were each< 2.5 Mg. The 2007 4th quarter EOL benzene quantity exceeded 2.5 Mg, but the calendar year 2007 TAB did NOT exceed 10 Mg. 2008: The EOL BQ for the l st quarter of 2008 was <2.5 Mg and the projected 2008 TAB was < l OMg/yr. The EOL BQ for the 2nd quarter of 2008 was> 2.5 Mg and the projected tab was> 10 Mg/yr. The EOL BQ for the 3rd quarter of 2008 was > 2.5 Mg and the projected tab was > 10 Mg/yr. TI1e EOL BQ for the 4th quarter of 2008 was <2.5 Mg and the projected 2008 TAB was < l OMg/yr. 2009: The EOL BQ for the l si, 2nd, 3rd and 4th quarters of 2009 \Vere <2.5 Mg and the projected 2009 TAB was< 10 Mg/yr so no plan was required. 2010: The EOL BQ for the l si, 211d, 3', and 4th quarters of 2010 was <2.5 Mg and the projected 2010 TAB was< 10 Mg/yr so no plan was required. 2011: The EOL BQ for the ls\ 211d, 3rd and 4th quarters of201 l was <2.5 Mg and the projected 2010 TAB was< 10 Mg/yr so no plan is required. Page 10 of 12 HFNA-000002865 EPA Inspection Report - Page 1316 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 1st QUARTER 2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT 2012: The EOL BQ for the ls1, 211d, 3rd and 4th quarters of2012 was <2.5 Mg and the projected 2012 TAB was< 10 Mg/yr so no plan is required. 2013: The EOL BQ for the 1si, 211d, 3rd and 4th quarters of 2013 \Vas <2.5 Mg and the projected 2012 TAB was< 10 Mg/yr so no plan is required. 2014: The EOL BQ for the ls\ 2nd, 3rd and 4th quarters of 2014 were <2.5 Mg and the projected 2014 TAB was< 10 Mg/yr so no plan was required. 2015: The EOL BQ for the 1st quarter of2015 was <2.5 Mg and the projected 2015 TAB \Vas< 10 Mg/yr so no plan \Vas required. The EOL BQ for the 2nd quarter of 2015 was <2.5 Mg and the projected 2015 TAB \Vas < 10 Mg/yr so no plan \Vas required. The EOL BQ for the 3rd quarter of 2015 was <2.5 Mg and the projected 2015 TAB was < l OMg/yr so no plan was required. The EOL BQ for the 4t11 quarter of 2015 was <2.5 Mg and the projected 2015 TAB was< 10 Mg/yr so no plan was required. 2016: The EOL BQ for the 1st quarter of 2016 \Vas <2.5 Mg and the projected 2016 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the 2nd quarter of 2016 was <2.5 Mg and the projected 2016 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the 3rd quarter of 2016 exceeded 2.5 Mg. As required by paragraph 22.J.iv, Navajo submits the following plan that identifies the specific actions that will be taken, and the schedule for such actions, to ensure the TAB does not exceed l OMg in the calendar year. As the first two quarters of 2016 indicated significantly lower concentrations of benzene in the wastewater, the projected TAB remained below 10 Mg for the calendar year, and as such no specific actions need to be taken to ensure the TAB does not exceed lOMg. Regardless of that, however, Navajo developed a plan of targeted monitoring to help identify and address the benzene contributions during the third quarter. The plan was implemented by November 4, 2016 (attachment 4). The EOL BQ for the 4th quarter of 2016 was <2.5 Mg and the projected TAB for 2016 was <10 Mg/yr. 2017: The EOL BQ for the 1st quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BQ for the 211d quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. Page 11 of 12 HFNA-000002866 EPA Inspection Report - Page 1317 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 1st QUARTER2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT TI1e EOL BQ for the 3rct quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BQ for the 4th quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. 2018: The EOL BQ for the 1st quarter of2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr. The EOL BQ for the 2nd quarter of 2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr. The EOL BQ for the 3rd quarter of 2018 was <2.5 Mg and the projected TAB for 20] 8 was <10 Mg/yr. The EOL BQ for the 4th quarter of 2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr. 2019: The EOL BQ for the l st quarter of 2019 was <2.5 Mg and the projected TAB for 2019 was <10 Mg/yr. Page 12 of 12 HFNA-000002867 EPA Inspection Report - Page 1318 of 1969 ATTACHMENT 2 APPENDIX H SUMMARY REPORTS HFNA-000002868 EPA Inspection Report - Page 1319 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO 1st QUARTER2019 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT REPORTS, PLANS AND CERTIFICATIONS UNDERTHELDARENHANCEDPROGRAM PROVISIONS OF PARAGRAPH 23 OF THE CONSENT DECREE IN UNITED STATES, ET AL. V. NAVAJO REFINING CO., ET AL. Name or Summary of the Report, Plan, or Certification CD Sub-,J Nos. Rqd. ("R") v. Contingent ("C") One-Time ("l ") V. Quarterly or w-/ 63.654 Reports ("> l ") Due Date Status Written Refinery- A- R ' Wide LDAR O.i.a Program Updated Refinery- A C Wide LDAR Program 1 150 D Prepared by 4/19/02 and Submitted after 5/13/02 Lodging 1 As LDAR plan updated 11/19/2009, needed 01/05/2011, 04/28/2014 (approved 7/22/2014). Page 1 of 9 HFNA-000002869 EPA Inspection Report - Page 1320 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO 1st QUARTER2019 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-,I Nos. Rqd. ("R") v. Contingent ("C") One-Time ("1 ") V. Quarterly orw/ 63.654 Reports ("> l ") Due Date Status Report on training B.i; R for new LDAR personnel O.ii- c(l) >l In each Training addressed in 63.654 Report Section submitted 9/13/02, 3/15/03, 9/15/03, 63.654 3/15/04, 9/15/04, 3/14/05 (3/15/05 Report for Lovington), 9/13/05 (9/15/05 for Lovington), 3/17/06, 9/13/06 (9/6/06 for Lovington), 3/16/07, 09/14/07, 03/17/08, 09/12/08, 03/16/09, 08/27/09, 03/16/2010, 09/13/2010, 03/16/2011 06/08/2011, 07/10/2012, 09/10/12, 11/06/2012, 12/11/2012, 01/13/2013, 05/02/2013, 05/08/2013, 05/15/2013, 02/08/2013 03/09/2013 and 09/16/2014 (for Artesia and Lovington). New hire training was conducted 06/08/2011, 07/10/2012, 09/10/12, 11/06/2012, 12/11/2012, 01/13/2013, 05/02/2013, 05/08/2013, 05/15/2013, 02/08/2013, 12/9/2013, 03/22/2014, 03/31/2014, 04/01/2014, 06/18/14, 06/19/14, and 06/20/2014. Annual LDAR Computer Based Training (CBT) implemented during the fourth quarter 2014. First training completed before 12/31/2014. Annual CBT for new personnel completed during 2015. Annual CBT completed in 2016; additional training on 4/28/2016, 05/11/2016. Annual CBT completed in 2017; additional training on 04/13/2017, 04/25/2017, 05/20/2017, 12/01/2017. Annual CBT completed during 2018, additional training on 01/2018, 02/2018, and 03/2018. 2019 training on 01/08/2019, 01/11/2019, 02/20/2019, 03/05/2019, and 03/22/2019. Page 2 of 9 HFNA-000002870 EPA Inspection Report - Page 1321 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO 1st QUARTER2019 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-,I Nos. Rqd. ("R") v. Contingent ("C") One-Time ("1 ") V. Quarterly orw/ 63.654 Reports ("> l ") Due Date Status Report on annual B.ii; R training for LDAR personnel O.ii- c(l) >l In each Training addressed in 63.654 Report Section submitted 9/13/02, 3/15/03, 9/15/03, 63.654 3/15/04, 9/15/04, 3/14/05 (3/15/05 Report for Lovington), 9/13/05 (9/15/05 for Lovington), 3/17/06, 9/13/06 (9/6/06 for Lovington), 3/16/07, 09/14/07, 03/17/08, 09/12/08, 03/16/09, 08/27/09, 03/16/2010, 09/13/2010, (for Artesia and Lovington).Annual training was conducted on the following dates by the on-site LDAR contractor: 06/29/2011, 06/14/2012, 06/24/2013, 06/26/2013, 11/12 tol l/14/20143, 01/12/2014, 01/16/2014, 01/20/2014, 01/21/2014, 02/08/2014, 02/10/2014, 6/18/2014, 6/19/2014, and 06/20/2014. Annual LDAR Computer Based Training (CBT) implemented during the fourth quarter 2014 for all refinery and contractor personnel. Annual CBT conducted during 2015. Annual CBT in 2016; additional 2016 training on l/3/2016, l/6/2016, 1/14/2016, and 1/19/2016, l/31/2016, 04/28/2016, 05/11/2016, 09/2016, 10/2016, 11/2016, and 12/2016. Annual CBT in 2017; additional training on 04/13/2017, 04/25/2017, 05/20/2017, 12/01/2017. Annual CBT in 2018; additional training on 01/2018, 02/2018, and 03/2018. Page 3 of 9 HFNA-000002871 EPA Inspection Report - Page 1322 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO 1st QUARTER2019 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-,I Nos. Rqd. ("R") v. Contingent ("C") One-Time ("1 ") V. Quarterly orw/ 63.654 Reports ("> l ") Due Date Status Report on LDAR B.iii; R training for refinery and O.ii- operations c(l) personnel who hold positions relevant to LDAR >l In each Initial training program Section implemented. Training addressed in 63.654 63.654 Report submitted 9/13/02, Report 3/15/03, 9/15/03, 3/15/04, 9/15/04, 3/14/05 (3/15/05 for Lovington), 9/13/05 (9/15/05 for Lovington), 3/17/06, 9/13/06 (9/6/06 for Lovington), 3/16/07, 09/14/07, 03/17/08, 09/12/08, 03/16/09, 08/27/09, 03/16/2010, 09/13/2010, 03/16/2011, 03/14/2012 and 09/16/2013. Training was conducted on the following dates for refinery environmental personnel: 11/06/2012, 08/13 - 08/15/2013, 05/19 - 5/21/2014, 8/21/2014, l 0/02/2014 . Annual LDAR Computer Based Training (CBT) implemented during the fourth quarter 2014 for all refinery and contractor personnel. Annual CBT in 2015. Annual CBT in 2016: additional training on 1/3/2016, 1/6/2016, 1/14/2016, and 1/19/2016, l/31/2016, 04/28/2016, and 05/11/2016. Annual CBT in 2017; additional training on 04/13/2017, 04/25/2017, 05/20/2017, 12/01/2017. Annual CBT in 2018; additional training on Ol/2018, 02/2018, and 03/2018. Page 4 of 9 HFNA-000002872 EPA Inspection Report - Page 1323 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO 1st QUARTER2019 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-,I Nos. LDARaudit reports and records of corrective actions. Audits are required every two years. D, O.ii-b. Rqd. ("R") v. Contingent ("C") R One-Time ("1 ") V. Quarterly orw/ 63.654 Reports ("> l ") >l Due Date Status In the Quarterly Report forthe 1st calendar Quarter of each year [ncluded in the 1st Qtr 2003 report (submitted 04/17/2003) as Attachment 3. 3rd party audits for Artesia and Lovington were perfonned during December 2004, January 2007, January 2009, and January 2011. Included in the l st Qtr 2012 report, a copy of the 01/2011 Audit Report and the corrective actions taken were included with the 1st Quarter 2012 report as Attachment 5. The 2013 3rd party audit was conducted from 09/16 to 09/20/2013, after major refinery turnaround, and a complete quarter \vorth of normal operation data has been collected for comparative monitoring. A copy of the audit report and resolutions were presented in the 1st Quarter 2014 report. 3rd party audits for Artesia and Lovington were performed during the week of October 5th to 9t\ 2015. A copy of the 2015 LDAR 3rd party audit report and resolutions are included in Attachment 5 of the 1st Quarter 2016 report. The 2017 LDAR 3rd party audit was conducted from 05/17 to 05/18/2017. A copy of the audit report was attached to the 3rd Quarter Consent Decree Progress Report. The audit resolutions were included as Attachment 5 to the 1st Quarter 2018 report. Page 5 of 9 HFNA-000002873 EPA Inspection Report - Page 1324 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO 1st QUARTER2019 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-,I Nos. Rqd. ("R") v. Contingent ("C") One-Time ("1 ") V. Quarterly orw/ 63.654 Reports ("> l ") Due Date Status Certification of G, R implementation of O.iithe first attempt at a(l) repa1r program Operational I.ii.; R specifications for electronic LDAR O.i-b data collection and transfer Certification of r, R implementation of O.ii- QA/QC a(2) procedures for review of data generated by LDAR monitoring technicians 1 In the Provided \vith Initial Quarterly first Qtrly Status Report submitted for 2nd report Quarter 2002 on July 30, 2002 due under the CD or the first Qtrly report in which the rqmt. becomes due 1 6mos. Submitted 06/19/2002 after Lodging for Navajo; 1 yr. after Lodging for Montana Refining 1 In the Provided with Initial Quarterly first Qtrly Status Report submitted for 2nd report Quarter 2002 on July 30, 2002. due under the CD or the first Qtrly report in which the rqmt. becomes due. Page 6 of 9 HFNA-00000287 4 EPA Inspection Report - Page 1325 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO 1st QUARTER2019 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-,I Nos. Rqd. ("R") v. Contingent ("C") One-Time ("1 ") V. Quarterly orw/ 63.654 Reports ("> l ") Due Date Status Identification of K; R each Refinery's O.iiLDAR "point" a(3) person Certification of the L; R development of a O.iitracking program a(4) for new valves and pumps 1 In the Provided \vith Initial Quarterly first Qtrly Status Report submitted for 2nd report Quarter 2002 on July 30, 2002 due under the CD or the first Qtrly report in which the rqmt. becomes due 1 In the Provided \vith Initial Quarterly first Qtrly Status Report submitted for 2nd report Quarter 2002 on July 30, 2002 due under the CD or the first Qtrly report in which the rqmt. becomes due Page 7 of 9 HFNA-000002875 EPA Inspection Report - Page 1326 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO 1st QUARTER2019 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-,I Nos. Rqd. ("R") v. Contingent ("C") One-Time ("1 ") V. Quarterly orw/ 63.654 Reports ("> l ") Due Date Status Certification of M R implementation of O.iicalibration drift a(5) assessment procedures 1 In the Provided \vith Initial Quarterly first Qtrly Status Report submitted for 2nd report Quarter 2002 on July 30, 2002 due under the CD or the first Qtrly report in which the reqmrem ent becomes due Certification of N, R implementation of O.ii- the "delay of a(6) repair" procedures l [n the Provided with Initial Quarterly first Qtrly Status Report submitted for 2nd report Quarter 2002 on July 30, 2002 due under the CD or the first Qtrly report in which the reqmrem ent becomes due Page 8 of 9 HFNA-000002876 EPA Inspection Report - Page 1327 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO 1st QUARTER2019 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-,I Nos. Rqd. ("R") v. Contingent ("C") One-Time ("1 ") V. Quarterly orw/ 63.654 Reports ("> l ") Due Date Status LDAR monitoring O R ' report submitted withMACT O.ii- periodic reports c(2) >l In each Provided in MACT 63.654 Reports Section submitted: 3/15/02, 9/13/02, 3/15/03, 63.654 9/15/03, 3/15/04, 9/15/04, 3/14/05 Report (3/15/05 for Lovington 9/13/05 (9/15/05 for Lovington), 3/17/06, 9/13/06 (9/6/06 for Lovington), 3/16/07, 09/14/07, 03/17/08, 09/12/08, 03/16/09, 08/27/09, 03/16/2010, 09/13/2010, 03/16/2011, 09/15/2011, 03/09/2012, 0/06/2012 (09/06/2012 for Lovington), and 03/15/2013, 09/16/2013, (Lovington and Artesia) 02/25/2014 (Artesia), 08/26/2014 (Lovington), and 02/26/2015 (Artesia and Lovington), 08/27/2015, 2/18/2016 (Artesia and Lovington), 08/29/2016 (Artesia and Lovington), 02/28/2017 (Artesia and Lovington), 08/29/2017 (Artesia and Lovington) and 08/30/2018 (Artesia and Lovington). Page 9 of 9 HFNA-000002877 EPA Inspection Report - Page 1328 of 1969 ATTACHMENT 3 QUARTERLY EOL SUMMARY (Paragraph 22.M .ii.a(3)) HFNA-000002878 EPA Inspection Report - Page 1329 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery End of Line Sampling Report ls1 Quarter 2019 ATTACHMENT 3 TO 1st QUARTER 2019 STATUS REPORT OUARTERLY END OF LINE SAMPLING RESULTS On January 1011\ February ?11\ and March 3rd, 2019, Navajo Refining's Artesia facility performed the End of Line (EOL) sampling pursuant to the Consent Decree, following the protocol described in Navajo's EOL sampling plan that was revised by a letter dated March 31, 2004. Due to changes in our wastewater system, the slop oil from our Alky API is diverted through the new wastewater API. Therefore, that stream is now factored into the calculations for the Wastewater API. As a result, Navajo has identified six (6) sampling points that were monitored during the EOL sampling. This included three representative samples for each sampling site, volume measurements, and specific gravity values, collected once a month during the quarter where applicable. The following calculations estimate the quarterly EOL and calendar year benzene quantities: Oil from Wastewater API EOL (Mg/qtr) = weeks/quarter x Oil Volume (gal/wk) x lbs. water/gallon x Specific Gravity of oil (dimensionless) x average benzene concentration in oil (ppmw) x grams/lb -c- 106 g/Mg Oil from Wastewater API EOL (Mg/qtr) = l3 wks/qtr x 92,387 gals/wk x 8.34 lbs./gallon x 0.97 (dimensionless) x 14.5 lb/106 x 454 g/lb -c- 106 gft,;Ig Oil from Wastewater API EOL = 0.06 Mg/qtr Wastewater - EOL (Mg/qtr) = days/qtr x Average Flow (gal/day) x Water Density (lbs. water/gal) x Average Benzene Concentration in wastewater (ppmw) x grams/lb -c- 106 g/Mg Wastewater - EOL (Mg/qtr) = 92 days/qtr x 720,000 gal/day x 8.34 lbs/gal x 0.98 lb/106 lb X 454 g/lb 7 l 06 g/Mg Wastewater - EOL = 0.25 Mg/qtr Cement Kiln Fuel Product EOL (Mg/qtr) = Amount of cement kiln fuel shipped m quarter (lbs/qtr) x Average Benzene Concentration (ppmw) x g/lb -c- 106 gftvig Cement Kiln Fuel Product EOL (Mg/qtr) = 0 (lbs/qtr) x 5.0 lb/106 x 454 g/lb -c- 106 g/Mg There was no sludge generated during the l st quarter 2019. Cement Kiln Fuel Product EOL = 0.00 Mg/qtr Aqueous Waste Caustic EOL (Mg/qtr) = Amount of aqueous waste caustic shipped in the quarter (total of Tanks 40 and 41) (gal) x lbs/gal x Average Benzene Concentration (ppmw) x g/1b -c- 106 gft,;Ig Page 1 of3 HFNA-000002879 EPA Inspection Report - Page 1330 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery End of Line Sampling Report ls1 Quarter 2019 ATTACHMENT 3 TO 1st QUARTER 2019 STATUS REPORT OUARTERLY END OF LINE SAMPLING RESULTS Aqueous Waste Caustic lb X 454 g/lb -:- 106 g/Mg EOL (Mg/qtr) = 18,603 gal/qtr x 9.69 lbs/gal x 0.327 lb/106 Aqueous Waste Caustic EOL = 2.7 E (-5) :Mg/qtr Waste Caustic Hydrocarbon EOL (Mg/qtr) = days/qtr x avg flow (gal/day) x water density (lbs/ gal) x Specific Gravity (dimensionless) x Average Benzene Concentration (ppmw) x g/lb-;- 106 g/Mg Waste Caustic Hydrocarbon EOL (Mg/qtr) = 92 days/qtr x 42 gal/day x 8.34 lbs/gal x 1.17 (dimensionless) x 0.23 lb/106 lb x 454 g/lb--:-106 g/Mg Waste Caustic Hydrocarbon EOL = 4.0 E(-6) Mg/qtr Therefore, estimated total quarterly benzene equals benzene in Oil from Wastewater API (Mg/qtr) + benzene in Wastewater (Mg/qtr) + benzene in Cement Kiln Fuel Product (Mg/qtr) + benzene in Aqueous Waste Caustic (Mg/qtr) + benzene in Waste Caustic Hydrocarbon (Mg/qtr). Estimated Total Quarterly Benzene= 0.06 l\fg/qtr + 0.25 l\fg/qtr + 0.0 Mg/qtr + 2.7 E (-5) Mg/qtr + 4.0 E(-6) Mg/qtr Estimated Quarterly EOL Benzene= 0.311\-fg/qtr Therefore, the Artesia Refinery's quarterly EOL benzene quantity did not exceed 2.5 Mg/qtr. Estimated Annual Benzene (AB) Quantity for calendar year 2018 Estimated 2019 TAB= 1stQ * 4=0.31 *4 Estimated 2019 TAB= 1.24 l\1Ig The Artesia Refinery's projected calendar year 2019 total annual benzene quantity does not exceed l OMg/yr. The above calculations were determined using the values from the following table and the attached analyses. Page 2 of3 HFNA-000002880 EPA Inspection Report - Page 1331 of 1969 HollyFrontier Navajo Refining LLC Artesia, ~I Refinery ATTACHMENT 3 TO lstQUARTER2019 STATUS REPORT QUARTERLY END OF LINE SAMPLING RESULTS End of Line Sampling Report 1st Quarter 2019 Sampling Point Volume Oil from Wastewater API(S-1) Wastewater Tanks (S-3) Cement Kiln Fuel (S-4)*" Aqueous Waste Caustic Tank 40 (S-5) 92,387 gal/wk 720,000 gal/day 0 lbs 18,603 gal/qtr TABLE 1 QUARTERLY EOL SAMPLING NAVAJO REFINING Test results Sample Collected 01/10/2019 Test results Sample Collected 02/07/2019 Test results Sample Collected 05/03/2019 36ppm 5.50 ppm 1.9 ppm Average of Samples 14.47 ppm 1.70 ppm NA 0.024 ppm+ 0.46 ppm NA 0.024ppm+ 0.78 ppm NA 0.024 ppm+ 0.98 ppm NA 0.024 ppm Specific Gravity or Density 0.97 1.01 NA 1.15 Aqueous Waste Caustic Tank 41 (S-6) * 0.480 ppm 0.210 ppm 0.290ppm 0.327 ppm 1.14 Average of Aqueous Waste Caustic Tanks (S-5 and S-6) Waste Caustic Hydrocarbon (S-7) * 42 gal/day 0.252 ppm 0.23# 0.117 ppm 0.23# 0.157 ppm 0.23# 0.175ppm 0.23# 1.14 1.17# *The volume for Caustic Tank 41 is reflected in the value assigned to Tank 40. The quantity assigned to Tank 40 is the combined volume from BOTH tanks that was shipped out in the quarter. ** There was no sludge generated during the 1st quarter 2018. +The Benzene result was below the method detection limit (MDL) of0.024 ppm. The MDL was used as a conservative aproach. #No sample could be collected because the hydrocarbon layer was between the sample point draws on the tank. 4 QT 2017 average Benzene of0.23 ppm, specific gravity of 1.17 was used. Page 3 of3 HFNA-000002881 EPA Inspection Report - Page 1332 of 1969 ATTACHMENT 4- CD 2018 TAB SUMMARY (Paragraph 22.J) HFNA-000002882 EPA Inspection Report - Page 1333 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery I st Quarter 2019 ATTACHMENT 4 TO l't QUARTER 2019 STATUS REPORT ANNUAL TAB RESULTS 2018 Annual Sampling Results for Streams Contributing~ 0.05 Mg/yr to the 2018 TAB As required by paragraph 22.J.i of the Consent Decree, Navajo identified the streams in the 2018 Total Annual Benzene (TAB) report for the Artesia Refinery that contributed 0.05 Mg/yr benzene or more. These streams were: Process Unit No. 02 08 13 16 Unit Name CRUDE (ATMOSPHERIC) UNIT TANKFARM NAPHTHA HYDROTREATING UNIT SKID TREATERS Streams Identified. 52 21 28 31 Number of TAB Streams 16 12 5 16 2018 TAB (Mg/yr) 0.91 0.05 0.29 0.18 29 BLENDING AREAS 7 34 HYDROCRACKING 45 UNIT LAB LAB SAJvIPLE WASTE 22 4 0.25 21 0.11 19 0.6 VACTRUCKS VACUUM TRUCKS 2 TANK WATER TANK WATER DRAW 2 DRAW wsos WASTE SHIPPED OFF- SITE 2 PUMPS PUMP MAINTENANCE 2 EXCHANGERS EXCHANGER 3 MAINTENANCE l 1.45 1 2.27 1 0.25 l 0.43 2 0.23 Of these streams, "Lab " and "Vacuum Trucks" were not sampled because they are aggregate samples made up of many individual samples. For instance, the Lab Samples number is an aggregate of several thousand product samples, none of which individually would be greater than 0.05 Mg/yr. Similarly, the Vacuum Trucks Movements are an aggregate of all the gathering stations, none of which individually would be over the 0.05 Mg/yr limit. No additional samples were taken from tanks T-40 and T-41. The oil layer in these spent caustic tanks is sampled as part of the quarterly end-of-line sampling. Therefore, the HFNA-000002883 EPA Inspection Report - Page 1334 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery I st Quarter 2019 ATTACHMENT 4 TO l't QUARTER 2019 STATUS REPORT ANNUAL TAB RESULTS results of sampling tanks T-40 and T-41 have been in included in the" Attachment 3" results in each quarterly report for the calendar year. Navajo sampled each of the remaining streams to get a representative average number for each stream's benzene concentration. Because the waste stream flows are not consistent, it is not always possible to obtain a sample. HFNA-000002884 EPA Inspection Report - Page 1335 of 1969 ATTACHMENT 5 - Provided in Enclosed CD 2019 1QT EOL ANALYTICAL REPORTS (Paragraph 22.M .ii.a(3)) HFNA-000002885 EPA Inspection Report - Page 1336 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 January 17, 2019 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling (EOL) Dear Gabriela, Work Order: HS19010541 ALS Environmental received 9 sample(s) on Jan 11, 2019 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, ~:::~:::::::~=--z,... t-{;-;...-, Generated By: JUMOKE.LAWAL Corey Grandits Project Manager Right Solutions Right Partnu www.a!sg!obaLcom Pagel of28 HFNA-000002886 EPA Inspection Report - Page 1337 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010541 lab Samp ID HS19010541-01 HS19010541-02 HS19010541-03 HS19010541-04 HS19010541-05 HS19010541-06 HS19010541-07 HS19010541-08 HS19010541-09 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Matrix Liquid Liquid Liquid Liquid Water Water Water Liquid Water Date: 17-Jan-19 SAMPLE SUMMARY TagNo Collection Date 1O-Jan-2019 08:53 10-Jan-2019 09:13 1O-Jan-2019 08:32 1O-Jan-2019 08:35 1O-Jan-2019 09:04 1O-Jan-2019 09:35 1O-Jan-2019 09:35 1O-Jan-2019 00:00 CG 101618 1O-Jan-2019 00:00 -95 Date Received 11-Jan-2019 09:00 11-Jan-2019 09:00 11-Jan-2019 09:00 11-Jan-2019 09:00 11-Jan-2019 09:00 11-Jan-2019 09:00 11-Jan-2019 09:00 11-Jan-2019 09:00 11-Jan-2019 09:00 Hold D D D D D D D D D Page 2 of28 HFNA-000002887 EPA Inspection Report - Page 1338 of 1969 ALS Houston, US Date: 17-Jan-19 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010541 GCMS Volatiles by Method SW8260 Batch ID: R331086 Sample ID: S-5 (T-40) (HS19010541-03) CASE NARRATIVE Surrogate failure for HS19010541-03 due to sample matrix. Sample ID: S-6 (T-41) (HS19010541-04) Surrogate failure for HS19010541-04 due to sample matrix. Batch ID: R331013 Sample ID: HS19010527-01 MS MSD is for an unrelated sample Batch ID: R331105 Sample ID: HS19010487-02MSD MSD is for an unrelated sample Batch ID: R331187 The test results meet requirements of the current NELAP standards, state requirements or programs where applicable. Page 3 of28 HFNA-000002888 EPA Inspection Report - Page 1339 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (API HC) 1O-Jan-2019 08:53 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 36 98.1 101 101 96.6 Method:SW8260 0.24 REPORT LIMIT 2.4 70-126 70-130 70-130 70-130 Date: 17-Jan-19 ANALYTICAL REPORT Work0rder:HS19010541 Lab ID:HS19010541-01 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 500 %REC 500 %REC 500 %REC 500 %REC 500 Analyst: WLR 15-Jan-2019 18:38 15-Jan-2019 18:38 15-Jan-2019 18:38 15-Jan-2019 18:38 15-Jan-2019 18:38 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of28 HFNA-000002889 EPA Inspection Report - Page 1340 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 10-Jan-2019 09:13 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 1.7 98.8 99.9 98.8 99.9 Method:SW8260 0.030 REPORT LIMIT 0.25 70-126 82-124 77-123 82-127 Date: 17-Jan-19 ANALYTICAL REPORT Work0rder:HS19010541 Lab ID:HS19010541-02 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: PC 17-Jan-2019 01:52 17-Jan-2019 01:52 17-Jan-2019 01:52 17-Jan-2019 01:52 17-Jan-2019 01:52 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of28 HFNA-000002890 EPA Inspection Report - Page 1341 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 1O-Jan-2019 08:32 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.024 91.8 110 68.2 91.5 Method:SW8260 0.024 s REPORT LIMIT 0.24 70-126 70-130 70-130 70-130 Date: 17-Jan-19 ANALYTICAL REPORT Work0rder:HS19010541 Lab ID:HS19010541-03 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 16-Jan-2019 09:53 16-Jan-2019 09:53 16-Jan-2019 09:53 16-Jan-2019 09:53 16-Jan-2019 09:53 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of28 HFNA-000002891 EPA Inspection Report - Page 1342 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-6 (T-41) 1O-Jan-2019 08:35 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.48 92.2 111 66.2 91.8 Method:SW8260 0.024 s REPORT LIMIT 0.24 70-126 70-130 70-130 70-130 Date: 17-Jan-19 ANALYTICAL REPORT Work0rder:HS19010541 Lab ID:HS19010541-04 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 16-Jan-2019 10:17 16-Jan-2019 10:17 16-Jan-2019 10:17 16-Jan-2019 10:17 16-Jan-2019 10:17 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of28 HFNA-000002892 EPA Inspection Report - Page 1343 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Field Blank 1O-Jan-2019 09:04 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 95.8 101 98.3 98.0 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 17-Jan-19 ANALYTICAL REPORT Work0rder:HS19010541 Lab ID:HS19010541-05 Matrix:Water UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 15-Jan-2019 17:07 15-Jan-2019 17:07 15-Jan-2019 17:07 15-Jan-2019 17:07 15-Jan-2019 17:07 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 8 of28 HFNA-000002893 EPA Inspection Report - Page 1344 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 1 1O-Jan-2019 09:35 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 97.2 98.6 98.0 105 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 17-Jan-19 ANALYTICAL REPORT Work0rder:HS19010541 Lab ID:HS19010541-06 Matrix:Water UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 15-Jan-2019 17:31 15-Jan-2019 17:31 15-Jan-2019 17:31 15-Jan-2019 17:31 15-Jan-2019 17:31 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 9 of28 HFNA-000002894 EPA Inspection Report - Page 1345 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 2 1O-Jan-2019 09:35 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 97.0 102 99.5 98.8 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 17-Jan-19 ANALYTICAL REPORT Work0rder:HS19010541 Lab ID:HS19010541-07 Matrix:Water UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 15-Jan-2019 17:55 15-Jan-2019 17:55 15-Jan-2019 17:55 15-Jan-2019 17:55 15-Jan-2019 17:55 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 10 of28 HFNA-000002895 EPA Inspection Report - Page 1346 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Duplicate 1O-Jan-2019 00:00 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.97 97.9 101 103 96.1 Method:SW8260 0.024 REPORT LIMIT 0.24 70-126 70-130 70-130 70-130 Date: 17-Jan-19 ANALYTICAL REPORT Work0rder:HS19010541 Lab ID:HS19010541-08 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 15-Jan-2019 19:00 15-Jan-2019 19:00 15-Jan-2019 19:00 15-Jan-2019 19:00 15-Jan-2019 19:00 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 11 of28 HFNA-000002896 EPA Inspection Report - Page 1347 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Trip Blank 1O-Jan-2019 00:00 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 98.4 99.0 98.8 102 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 17-Jan-19 ANALYTICAL REPORT Work0rder:HS19010541 Lab ID:HS19010541-09 Matrix:Water UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 15-Jan-2019 16:43 15-Jan-2019 16:43 15-Jan-2019 16:43 15-Jan-2019 16:43 15-Jan-2019 16:43 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 12 of28 HFNA-000002897 EPA Inspection Report - Page 1348 of 1969 ALS Houston, US Client: Navajo Refining Company Project: BWON Monthly Sampling (EOL) WorkOrder: HS19010541 Batch ID: 2867 SamplD HS19010541-01 HS19010541-03 HS19010541-04 HS19010541-08 Method: VOLATl LES BY SW8260C Container Sample Wt/Vol 5.222 (g) 5.104 (g) 5.12 (g) 5.296 (g) Final Volume 5 (ml) 5 (ml) 5 (ml) 5 (ml) Weight Factor 0.96 0.98 0.98 0.94 Container Type Bulk (5030B) Bulk (5030B) Bulk (5030B) Bulk (5030B) Date: 17-Jan-19 WEIGHT LOG Page 13 of28 HFNA-000002898 EPA Inspection Report - Page 1349 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010541 Sample ID Client Samp ID Collection Date TCLP Date Batch ID R331013 Test Name : VOLATILES BY SW8260C HS19010541-01 HS19010541-08 S-1 (API HC) Duplicate 1O Jan 2019 08:53 1O Jan 2019 00:00 Batch ID R331086 Test Name: VOLATILES BY SW8260C HS19010541-03 HS19010541-04 S-5 (T-40) S-6 (T-41) 1O Jan 2019 08:32 1O Jan 2019 08:35 Batch ID R331105 Test Name : VOLATILES - SW8260C HS19010541-05 HS19010541-06 HS19010541-07 HS19010541-09 Field Blank EQ Blank Port 1 EQ Blank Port 2 Trip Blank 1O Jan 2019 09:04 1O Jan 2019 09:35 1O Jan 2019 09:35 1O Jan 2019 00:00 Batch ID R331187 Test Name ; VOLATILES - SW8260C HS19010541-02 S-3 (API Water) 10 Jan 2019 09:13 Date: 17-Jan-19 DATES REPORT Prep Date Analysis Date DF Matrix: Liquid 15 Jan 201918:38 500 15 Jan 201919:00 50 Matrix: Liquid 16 Jan 2019 09:53 50 16 Jan 201910:17 50 Matrix: water 15 Jan 201917:07 15 Jan 201917:31 15 Jan 201917:55 15 Jan 201916:43 Matrix; Liquid 17 Jan 2019 01 :52 50 Page 14 of28 HFNA-000002899 EPA Inspection Report - Page 1350 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010541 Date: 17-Jan-19 QC BATCH REPORT Batch ID: R331013 Instrument: VOA8 Method; SW8260 MBLK Client ID: Analyte Sample ID: MBLKW1-011519 Units: ug/Kg Analysis Date: 15-Jan-2019 09:44 Run ID: VOA8_331013 SeqNo: 4908042 PrepDate: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 25 2381 2473 2446 2470 250 0 2500 0 2500 0 2500 0 2500 0 95.2 76 - 125 0 98.9 80 - 120 0 97.8 80 - 119 0 98.8 81 - 118 LCS Client ID: Analyte Sample ID: VLCSW1-011519 Units: ug/Kg Analysis Date: 15-Jan-2019 08:58 Run ID: VOA8_331013 SeqNo: 4908041 PrepDate: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 49.08 5.0 50 46.54 0 50 51.67 0 50 49.37 0 50 48.51 0 50 0 98.2 75 - 124 0 93.1 76 - 125 0 103 80 - 120 0 98.7 80 - 119 0 97.0 81 - 118 MS Client ID: Analyte Sample ID: HS19010527-01 MS Units: ug/Kg Analysis Date: 15-Jan-2019 11:14 Run ID: VOA8_331013 SeqNo: 4908303 Prep Date: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 3404 2453 2618 2478 2336 240 2450 0 2450 0 2450 0 2450 0 2450 638 113 70 - 130 0 100 70 - 126 0 107 70 - 130 0 101 70 - 130 0 95.3 70 - 130 Page 15 of28 HFNA-000002900 EPA Inspection Report - Page 1351 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010541 Date: 17-Jan-19 QC BATCH REPORT Batch ID: R331013 Instrument: VOA8 Method; SW8260 MSD Client ID: Analyte Sample ID: HS19010527-01 MSD Units: ug/Kg Analysis Date: 15-Jan-2019 11:35 Run ID: VOA8_331013 SeqNo: 4908304 PrepDate: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 3986 2510 2627 2399 2275 240 2450 0 2450 0 2450 0 2450 0 2450 638 137 70 -130 0 102 70 - 126 0 107 70 - 130 0 97.9 70 - 130 0 92.8 70 - 130 3404 15.8 30 s 2453 2.29 30 2618 0.317 30 2478 3.24 30 2336 2.64 30 The following samples were analyzed in this batch: ~f_s_19_0_10_s_4_1-_0_1_ _ _H_s_19_0_1o_s_4_1-_o_s- - - - - - - - - - - - - - - - - - - ~ Page 16 of28 HFNA-000002901 EPA Inspection Report - Page 1352 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010541 Date: 17-Jan-19 QC BATCH REPORT Batch ID: R331086 Instrument: VOA8 Method; SW8260 MBLK Client ID: Analyte Sample ID: MBLKW1-011619 Units: ug/Kg Analysis Date: 16-Jan-2019 09:32 Run ID: VOA8_331086 SeqNo: 4909866 PrepDate: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 25 2366 2511 2310 2383 250 0 2500 0 2500 0 2500 0 2500 0 94.7 76- 125 0 100 80 - 120 0 92.4 80 - 119 0 95.3 81 - 118 LCS Client ID: Analyte Sample ID: VLCSW1-011619 Units: ug/Kg Analysis Date: 16-Jan-2019 08:48 Run ID: VOA8_331086 SeqNo: 4909865 PrepDate: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 57.91 5.0 50 49.23 0 50 50.12 0 50 49.81 0 50 47.62 0 50 0 116 75 - 124 0 98.5 76 - 125 0 100 80 - 120 0 99.6 80 - 119 0 95.2 81 - 118 MS Client ID: Analyte Sample ID: HS19010443-06MS Units: ug/Kg Analysis Date: 16-Jan-2019 11:23 Run ID: VOA8_331086 SeqNo: 4910168 PrepDate: OF: 500000 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 50370000 23160000 25690000 24350000 23320000 2400000 O O O O 2.45e+007 2.45e+007 2.45e+007 2.45e+007 2.45e+007 22950000 0 0 0 0 112 94.5 105 99.4 95.2 70 - 130 70 - 126 70 - 130 70 - 130 70 - 130 Page 17 of28 HFNA-000002902 EPA Inspection Report - Page 1353 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010541 Date: 17-Jan-19 QC BATCH REPORT Batch ID: R331086 Instrument: VOAS Method; SW8260 MSD Client ID: Analyte Sample ID: HS19010443-06MSD Units: ug/Kg Analysis Date: 16-Jan-2019 11:45 Run ID: VOA8_331086 SeqNo: 4910169 PrepDate: OF: 500000 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene 49680000 2400000 Surr: 1,2-0ichloroethane-d4 23450000 0 Surr: 4-Bromofluorobenzene 25940000 0 Surr: Dibromofluoromethane 24830000 0 rs Surr: Toluene-dB 23320000 0 The following samples were analyzed in this batch: 19010541-03 2.45e+007 2.45e+007 2.45e+007 2.45e+007 2.45e+007 22950000 0 0 0 0 HS19010541-04 109 70 - 130 50370000 1.37 30 95.7 70 - 126 23160000 1.26 30 106 70 - 130 25690000 0.962 30 101 70 - 130 24350000 1.92 30 95.2 70 - 130 23320000 0.00119 30 Page 18 of28 HFNA-000002903 EPA Inspection Report - Page 1354 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010541 Date: 17-Jan-19 QC BATCH REPORT Batch ID: R331105 Instrument: VOA6 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-190115 Units: ug/L Analysis Date: 15-Jan-2019 12:19 Run ID: VOA6_331105 SeqNo: 4909977 Prep Date: OF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 48.23 0 50 50.01 0 50 48.71 0 50 50.84 0 50 0 96.5 70 - 130 0 100 82 - 115 0 97.4 73 - 126 0 102 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-190115 Units: ug/L Analysis Date: 15-Jan-2019 11:31 Run ID: VOA6_331105 SeqNo: 4909976 Prep Date: OF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 18.16 5.0 20 47.74 0 50 50.14 0 50 49.46 0 50 49.83 0 50 0 90.8 74 - 120 0 95.5 70 - 130 0 100 82 - 115 0 98.9 73 - 126 0 99.7 81 - 120 MS Client ID: Analyte Sample ID: HS19010487-02MS Units: ug/L Analysis Date: 15-Jan-2019 15:07 Run ID: VOA6_331105 SeqNo: 4909980 Prep Date: OF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 14.23 5.0 20 48.93 0 50 49.94 0 50 49.23 0 50 49.65 0 50 0 71.1 70 - 127 0 97.9 70 - 126 0 99.9 82 - 124 0 98.5 77 - 123 0 99.3 82 - 127 Page 19 of28 HFNA-000002904 EPA Inspection Report - Page 1355 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010541 Date: 17-Jan-19 QC BATCH REPORT Batch ID: R331105 Instrument: VOA6 Method; SW8260 MSD Client ID: Analyte Sample ID: HS19010487-02MSD Units: ug/L Analysis Date: 15-Jan-2019 15:31 Run ID: VOA6_331105 SeqNo: 4909981 PrepDate: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPK Val Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 13.92 5.0 20 48. 19 0 50 51. 18 0 50 49.6 0 50 48.62 0 50 0 69.6 70 -127 0 96.4 70- 126 0 102 82 - 124 0 99.2 77 - 123 0 97.2 82 - 127 14.23 2.19 20 s 48.93 1.52 20 49.94 2.46 20 49.23 0.749 20 49.65 2. 1 20 The following samples were analyzed in this batch: ~F_s_19_0_10_s_4_1-_o_s_ _ _H_s_19_0_1o_s_4_1-_0_ 6 _ _ _H_s_19_0_1o_s_4_1-_0_ 7 _ _ _H_s_19_0_10_s_4_1-_0_9- - - - ~ Page 20 of28 HFNA-000002905 EPA Inspection Report - Page 1356 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010541 Date: 17-Jan-19 QC BATCH REPORT Batch ID: R331187 Instrument: VOA6 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-190116 Units: ug/L Analysis Date: 16-Jan-2019 23:03 Run ID: VOA6_331187 SeqNo: 4911965 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 49.26 0 50 49.99 0 50 49.65 0 50 49.21 0 50 0 98.5 70 - 130 0 100.0 82 - 115 0 99.3 73 - 126 0 98.4 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-190116 Units: ug/L Analysis Date: 16-Jan-2019 22:15 Run ID: VOA6_331187 SeqNo: 4911964 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 17.79 5.0 20 50.45 0 50 49.57 0 50 50.02 0 50 49.62 0 50 0 88.9 74 - 120 0 101 70 - 130 0 99. 1 82 - 115 0 100 73 - 126 0 99.2 81 - 120 MS Client ID: Analyte Sample ID: HS19010524-22MS Units: ug/L Analysis Date: 17-Jan-2019 00:16 Run ID: VOA6_331187 SeqNo: 4911967 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 20.03 5.0 20 49. 18 0 50 50.24 0 50 49.79 0 50 49.76 0 50 0 100 70 - 127 0 98.4 70 - 126 0 100 82 - 124 0 99.6 77 - 123 0 99.5 82 - 127 Page 21 of28 HFNA-000002906 EPA Inspection Report - Page 1357 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010541 Date: 17-Jan-19 QC BATCH REPORT Batch ID: R331187 Instrument: VOA6 Method; SW8260 MSD Client ID: Analyte Sample ID: HS19010524-22MSD Units: ug/L Analysis Date: 17-Jan-2019 00:40 Run ID: VOA6_331187 SeqNo: 4911968 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene 19.43 5.0 20 0 97.2 70 - 127 20.03 3.01 20 Surr: 1,2-0ichloroethane-d4 49.22 0 50 0 98.4 70 - 126 49.18 0.0921 20 Surr: 4-Bromofluorobenzene 49.85 0 50 0 99.7 82 - 124 50.24 0.79 20 Surr: Dibromofluoromethane 49.87 0 50 0 99.7 77 - 123 49.79 0.162 20 Surr: Toluene-dB 49.6 0 50 0 99.2 82 - 127 49.76 0.32 20 The following samples were analyzed in this batch: ~f_s_19_0_10_s_4_1-_0_ 2 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _~ Page 22 of28 HFNA-000002907 EPA Inspection Report - Page 1358 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010541 Date: 17-Jan-19 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND O P R S U Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SOL TRRP Unit Reported mg/Kg mg/L Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL/SOL Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Description Milligrams per Kilogram Milligrams per Liter Page 23 of28 HFNA-000002908 EPA Inspection Report - Page 1359 of 1969 ALS Houston, US Agency Arkansas Texas North Dakota Illinois Louisiana Kentucky Kansas Oklahoma Date: 17-Jan-19 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number 88-0356 T10470231-18-21 R193 2018-2019 004438 03087 123043 - 2018 E-10352 2018-2019 2018-156 Expire Date 27-Mar-2019 30-Apr-2019 30-Apr-2019 29-Jun-2019 30-Jun-2019 30-Apr-2019 31-Jul-2019 31-Aug-2019 Page 24 of28 HFNA-000002909 EPA Inspection Report - Page 1360 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010541 Lab Sarnp ID HS19010541-01 HS19010541-02 HS19010541-03 HS19010541-04 HS19010541-05 HS19010541-06 HS19010541-07 HS19010541-08 HS19010541-09 Client Sample ID S-1 (API HG) S-3 (API Water) S-5 (T-40) S-6 (T-41) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Action Login Login Login Login Login Login Login Login Login Date 1/12/2019 2:25:39 PM 1/12/2019 2:25:39 PM 1/12/2019 2:25:39 PM 1/12/2019 2:25:39 PM 1/12/2019 2:25:39 PM 1/12/2019 2:25:39 PM 1/12/2019 2:25:39 PM 1/12/2019 2:25:39 PM 1/12/2019 2:25:39 PM Person JRM JRM JRM JRM JRM JRM JRM JRM JRM Date: 17-Jan-19 SAMPLE TRACKING New Location B070 B070 B070 B070 B070 B070 B070 B070 B070 Page 25 of28 HFNA-000002910 EPA Inspection Report - Page 1361 of 1969 ALS Houston, US Client Name: Work Order: Navajo Refining HS19010541 Date/Time Received: Received by: Date: 17-Jan-19 Sample Receipt Checklist 11-Jan-2019 09:00 JRM Checklist completed by: Jared R. Makan 12-Jan-2019 -e,:-S,-ig_n_a,-tu-re-------...---,D=-a..,.t_e_ _ Reviewed by: Corey Grandits eSignature 14-Jan-2019 Date Matrices: Carrier name: FedEx Priority Overnight Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Chain of custody present? Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? TX1005 solids received in hermetically sealed vials? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler( s )/Kit( s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ 1.0c/1.4c UC/C oam cooler 1/11/2019 20:40 Yes ;# Yes ~ Yes D No D No D No D No D No D No D No D No D No D No D No D No D No No D No~ D Not Present D Not Present Not Present ~ N/A ~ IR11 No VOA vials submitted N/A D N/A D Login Notes: Client Contacted: Date Contacted: Person Contacted: Contacted By: Comments: Regarding: Corrective Action: Page 26 of28 HFNA-000002911 EPA Inspection Report - Page 1362 of 1969 A Enuiranmental Chain of Custody Form Page _1_ of __j__ D +/ 513 733 5336 Cincinnati, OH D Everett, WA +1425356 2600 D Fort Collins, CO + I 970 490 757 7 D +16163996070 Holland, Ml D Houston, TX +I 287 530 5656 D Middletown, PA +l 717944 5541 ALS Project Manager: Erica Padilla : >Pi6ie~fNaifje BWON Monthly Sampling (EOL) Work Order#: :K VOLATILES (8260) Benzene D +7 801 266 7700 Salt Lake City, UT D Spring City, PA +-1 610 948 4903 D York, PA +I 717 505 5280 \<..G.o.n.ip.a.11.y..til.a.ir.ie Navajo Refining Company lLC Tyler Turner Gabi Combs ... ... P.O. Box 159 , >:: >> :;-'~;;.;;; (575) 748-3311 ... - .. ......... . ..: ::_:_. fax (575) 746-5451 : Emi T:<>?om.i:iany Holly Frontier Navajo Refining LLC ::: . ::: :-: 501 East Main, . .. .. ....... . CityJ~tat~IZip Artesia, New Mexico 88210 _<< :<> :F~~ (575) 146-5451 :::::e~Mail ,Ad~re_ss Suzanne.Aguilar@hollyfrontier.com : J_ I Ill III HS19010541 - - Navajo Refining Company - BWON Monthly Sampling (EOL) - - 11111111111111111 - . S-1 (API HC) : <<. S-3 (API Water) 3 ::: S-5 (T-40) .<4 S-6 (T-41) .: ~ < Field Blank ~ EQ Blank Port 1 7: EQB1ankPort2 ,.<f Duplicate 9:: Trip Blank 10 Temperature Blank 01/10/19 01/10/19 01/10/19 01/10/19 01/10/19 01/10/19 01/10/19 01/10/19 01/10/19 01/10/19 8:53 AM Liquid 8 9:13 AM Liquid 8,1 8:32 AM Liquid 8 8:35AM Liquid 8 9:04AM Liquid 8,1 9:35AM Liquid 8,1 9:35AM Liquid 8,1 XXX Liquid 8,1 XXX Liquid 8,1 liquid 1 X 1 X 1 X 1 X 1 X 1 X X 1 X 2 X 1 Oother _ _ __ D 2 Wk Days D 24 Hour :: <}O :> ::::: ....... < ::- .... ..... . . <: Relinquished by: Date: Time: Received by (laboratory): Cool_erTemp . Logged by !Laboratory): Preservative Key: 1-HCL . 2-HN03 Oaf&: I 3~H2S04; .. Time: Checked by (Laboratory): 4-NaOH 5-Na2S203 6NaHS04. 7-0ffier ~-4d&gtees C . 1 t.,;, ... LO 9.0035 Note: Any changes must be made in writing once samples and COC Form have been submitted to ALS laboratory Group. 1.::.1"0t,-i. (;,,,c.~ Page 27 of28 /!,(' /; /[::Cd' (l Cl9 P:ackage:(CheC:k E3ox:BetoW,_::::::: Level II: Standard QC Level III: Std QC+ Raw Data Level IV: SW846 CLP-Like ITRRP-Checklist ITRRP Level IV Other: Copyright 2009 by ALS laboratory Group HFNA-000002912 EPA Inspection Report - Page 1363 of 1969 Use of this system constitutes your agreement to the service conditions in the current FedEx Service Guide, available on fedex.com. FedEx will not be responsible for any claim in excess of $100 per package, whether the result of loss, damage, de!av, non-dell very, misdelivery, or ~is1nformation, unless you declare a higherva!ue, pay an additional charge, document your actual loss and file a timely claim. Limitations found in the current FedEx Service Guide apply. Your right to recover from FedEx for any loss, induding intrinsic value of the package, loss of sales, income interest, profit, attorney's fees, costs, and other forms of damage whether direct, incidental, consequential, or sped al is limited to the greater of $100 or the authorized declared value, Recovery cannot exceed actual documented loss. Maximum for items of extraordinary value is $1,000, e.g. jewelry, precious metals, negotiable instruments and other items listed in our Service Guide. Written claims must be filed within strict time limits, see current Fed Ex Service Gulde. 1'13S AOOl.SOO CONSIGNEE COPY PLEASE PLACE !N FRONT OF POUCH 1 Feld the printed page along th~ Moriwntel line. 2. Prace label in shipping pouch end affix i.t to your shipment )> CD CJ) G) ~ L889 oss ,81: (+ ~ ;'"'\t.~-d 9ggg 09 Ul1: \+ 1a1. 660LL Sl?X0J. 'UO\SnoH 0 (i; a11ns ''Pl:l JJ!PU1'1S 091'0 I 1-e::iuawuoJ1nu3 s,'1 VS, V =---== -I 0 CJ> 6~~ -='::C en .... )>(") z::o ::,-1 mm ~o C: 0 ro ol<l u,? "'c: :::::j t; en ;:o -;z g;en m 0 m ~;:: g:-l N en -< rn~ 0 .... -l G') c- ;;;;; z 0 )> "'"' .... -l z (") ~ == >< z ~ ,;;,;,;,;.; r :;; 0 ~ ""0"""" "Tl :::::j ~ ;;;;; <D en tJ1"" 1i! =~~ = ~ Page 28 of28 55iC2JD74C/i04C HFNA-000002913 EPA Inspection Report - Page 1364 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 January 18, 2019 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling (EOL) Dear Gabriela, Work Order: HS19010542 ALS Environmental received 4 sample(s) on Jan 11, 2019 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, ~:::~:::::::~=--z,... t-{;-;...-, Generated By: JUMOKE.LAWAL Corey Grandits Project Manager Right Solutions Right Partnu www.a!sg!obaLcom Pagel of25 HFNA-000002914 EPA Inspection Report - Page 1365 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010542 lab Samp ID HS19010542-01 HS19010542-02 HS19010542-03 HS19010542-04 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Matrix Liquid Liquid Liquid Liquid Date: 18-Jan-19 SAMPLE SUMMARY TagNo Collection Date 1O-Jan-2019 09:53 10-Jan-2019 09:13 1O-Jan-2019 08:32 1O-Jan-2019 08:35 Date Received 11-Jan-2019 09:00 11-Jan-2019 09:00 11-Jan-2019 09:00 11-Jan-2019 09:00 Hold D D D D Page 2 of25 HFNA-000002915 EPA Inspection Report - Page 1366 of 1969 ALS Houston, US Dale: 18-Jan-19 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010542 Work Order Comments CASE NARRATIVE The analysis for Specific Gravity was subcontracted lo ALS Environmental in Holland, Ml. Final report attached. Page 3 of25 HFNA-000002916 EPA Inspection Report - Page 1367 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (API HC) 1O-Jan-2019 09:53 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 18-Jan-19 ANALYTICAL REPORT Work0rder:HS19010542 Lab ID:HS19010542-01 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 18-Jan-2019 09:41 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of25 HFNA-000002917 EPA Inspection Report - Page 1368 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 10-Jan-2019 09:13 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 18-Jan-19 ANALYTICAL REPORT Work0rder:HS19010542 Lab ID:HS19010542-02 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 18-Jan-2019 09:41 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of25 HFNA-000002918 EPA Inspection Report - Page 1369 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 1O-Jan-2019 08:32 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 18-Jan-19 ANALYTICAL REPORT Work0rder:HS19010542 Lab ID:HS19010542-03 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 18-Jan-2019 09:41 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of25 HFNA-000002919 EPA Inspection Report - Page 1370 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-6 (T-41) 1O-Jan-2019 08:35 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 18-Jan-19 ANALYTICAL REPORT Work0rder:HS19010542 Lab ID:HS19010542-04 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 18-Jan-2019 09:41 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of25 HFNA-000002920 EPA Inspection Report - Page 1371 of 1969 ALS Houston, US Date: 18-Jan-19 Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010542 DATES REPORT Sample ID Client Samp ID Collection Date TCLP Date Prep Date Analysis Date DF Batch ID R331272 Test Name: SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY HS19010542-01 HS19010542-02 HS19010542-03 HS19010542-04 S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) 1O Jan 2019 09:53 10 Jan 2019 09:13 1O Jan 2019 08:32 1O Jan 2019 08:35 Matrix: Liquid 18 Jan 2019 09:41 18 Jan 2019 09:41 18 Jan 2019 09:41 18 Jan 2019 09:41 Page 8 of25 HFNA-000002921 EPA Inspection Report - Page 1372 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010542 Date: 18-Jan-19 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND 0 p R s u Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SOL TRRP Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL/SOL Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Page 9 of25 HFNA-000002922 EPA Inspection Report - Page 1373 of 1969 ALS Houston, US Agency Arkansas Texas North Dakota Illinois Louisiana Kentucky Kansas Oklahoma Date: 18-Jan-19 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number 88-0356 T10470231-18-21 R193 2018-2019 004438 03087 123043 - 2018 E-10352 2018-2019 2018-156 Expire Date 27-Mar-2019 30-Apr-2019 30-Apr-2019 29-Jun-2019 30-Jun-2019 30-Apr-2019 31-Jul-2019 31-Aug-2019 Page 10 of25 HFNA-000002923 EPA Inspection Report - Page 1374 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19010542 Lab Sarnp ID HS19010542-01 HS19010542-02 HS19010542-03 HS19010542-04 Client Sample ID S-1 (API HG) S-3 (API Water) S-5 (T-40) S-6 (T-41) Action Login Login Login Login Date 1/12/2019 2:33:43 PM 1/12/2019 2:33:43 PM 1/12/2019 2:33:43 PM 1/12/2019 2:33:43 PM Person JRM JRM JRM JRM Date: 18-Jan-19 SAMPLE TRACKING New Location WET255 WET255 WET255 WET255 Page 11 of25 HFNA-000002924 EPA Inspection Report - Page 1375 of 1969 ALS Houston, US Client Name: Work Order: Navajo Refining HS19010542 Date/Time Received: Received by: Date: 18-Jan-19 Sample Receipt Checklist 11-Jan-2019 09:00 JRM Checklist completed by: Jared R. Makan 12-Jan-2019 -e,:-S,-ig_n_a,-tu-re-------...---,D=-a..,.t_e_ _ Reviewed by: Corey Grandits eSignature 14-Jan-2019 Date Matrices: Carrier name: FedEx Priority Overnight Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Chain of custody present? Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? TX1005 solids received in hermetically sealed vials? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler( s )/Kit( s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ 1.0c/1.4c UC/C oam cooler 1/11/2019 20:40 Yes D Yes D No D No D No D No D No D No D No D No D No D No D No D No D No No D No D D Not Present D Not Present Not Present ~ N/A ~ IR11 No VOA vials submitted 4 N/A ~ N/A ~ Login Notes: Client Contacted: Date Contacted: Person Contacted: Contacted By: Comments: Regarding: Corrective Action: Page 12 of25 HFNA-000002925 EPA Inspection Report - Page 1376 of 1969 Chain of Custody Form D +1513733 5336 Cincinnati, OH D +l 616 399 6070 Holland, Ml D +I 801 266 7700 Salt Lake City, UT Page _1_ of - 1 _ D Everett, WA +I 425 356 2600 D Houston, TX +1 2815305656 D Spring City, PA +I 610 948 4903 Enuironmental >> .w.or~ orci~t : Cornpari{Nam.e .. . . . . . .. . -. . . . .. Navajo Refining Company LLC D Fort Collins, CO + I 970 490 1511 D Middletown, PA +I 717944 5541 D York, PA +I 717 505 5280 ALS Project Manager: Erica Padilla Work Order#: .. / <.. . .. ....... Pfoiect lnform~tion ........ ..... .. ...............>parameter/Method RequesH6rAnalysis .. F'~ojecf~anie BWON Monthly Sampling (EOL) ){ Specific Gravity .......... .... {13ill T:~C:Ollli>any Holly Frontier Navajo Refining LLC ...... ....... .<..... Tyler Turner Gabl Combs , P.O. Box 159 .... ... <> . . . ....C.l.tyi$t.ii.i.~.I.Z.ip. Artesia, NM 88211-0159 ....... < /P:iio:ne (575) 745.3311 . ... ,501 East Main <Qifyl$fat~l.!ip Artesia, New Mexico 88210 << </PJiO:Oe (575) 748-3311 ::: :>: : <f~li (575) 746-5451 HS19010542 Navajo Refining Company - ... BWON Monthly Sampling (EOL) - :<? - H: :>I< 111111111111111 IH 111111 - >1 :> S-1 (API HC) : 2 S-3 (API Water) >3 < S-5 (T-40) :-- S-6 (T-41) .~ .... 01/10/19 01110/19 01110/19 01110/19 9:53AM Liquid 8 9:13 AM liquid 8 8:32 AM liquid 8 8:35AM liquid 8 X 1 X 1 X X I!Required Turnaround Time: D STD 10 Wk Days 0 5 Wk Days Oother _ _ __ D 2 Wk Days D 24 Hour Received by: Notes: -----~-,-- Relinquished by: I . Logged by (Laboratory): .. . . .. Oat(!; / Time: Time: Received by (Laboratory): .. oc:Packa e:'Check:BoxBetow,:. Cooler[~me' \~~;:i rt St~~dard QC ..... TRRP-Checklist . Level III: Std QC + Raw Data TRRP Level IV . Level IV: SW846 CLP-Like . 3,,H2S04 4~NaOH s;.Na2S203 6-NaHS04 7-0tner .. .. : . Other: Note: Any changes must be made in writing once samples and COC Form have been submitted to ALS Laboratory Group. Copyright 2009 by ALS Laboratory Group Page 13 of 25 HFNA-000002926 EPA Inspection Report - Page 1377 of 1969 SHIPPER'S DECLARATION FOR DANGEROUS GOODS Shipper NAVAJO REFINING COMPANY C/0 AQUA MICROBICS 501 E MAIN ARTESIA NM88210 US Consignee Corey Grandits ALS 10450 Stancliff Suite 210 HOUSTON TX77099 US Two completed and signed copies of this Declaration must be handed to the operator (Provide at least three copies to airline.) Air Waybill No. 709308590729 Page 1 of 1 Page(s) ~ : x Shipper's Reference Number (optional) 18 Compliant Express CAFE3211 WARNING TRANSPORT DETAILS This shipment is within the limitations prescribed for: {delete non applicable) Airport of Departure ARTESIA T y ~ Airport ofDostlnation: HOUSTON . ABSGRA Failure to comply with all respects with the applicable Dangerous Goods Regulations may be in breach of the applicable law ,subject to legal penalties. Shloment !voe: (delete non applicable) .o, NATURE AND QUANTITY OF DANGEROUS GOODS UN Number or identification Number, propershipping name, Class or Division (subs;diary risk}, packing group (If required), and all other required information. UN 3266, Corrosive liquid, basic, inorganic, n.o.s.(Sodium Hydroxide),8,111 UN 1268, Petroleum distillates, n.o.s.,3,1111/ 0.04 U/366 All Packed In One FIBREBOARD BOX Q = 0.1 0.08 U/854 -A-d--d-it-i-o-n-a-l--H-a...n-d--li-n-g--I-n-fo--r-m-a--ti-o-n----------------~------------------------------------~----------------~----------~----------------- 24-Hour Emergency Response- CHEMTREC f-800-424-9300. CCN 201319 I hereby declare that the contents of this consignment are fully and accurately described above by the proper shipping name, and are classified, packaged, marked and labelled/placarded, and are in all respects in proper condition for transport according to applicable International and National Governmental RQgu!ations. I declare that all of the applicable air transport requirements have been met. 18004249300 emerg&ncy Telephone Nvmber Name/Title of Signatory Brady Hubbard/Environmental Coordinator Place and Date Artesia, NM 01/10/2019 B R ~ P ~ Signature {&lf<l wsrninu above) FOR RADIOACTIVE MATERIAL SHIPMENT ACCEPTAB!..E: FOR PASSENGER AIRCRAFT, niE SHIPMENT CONTAINS RADIOACTIVE MATER!AL tNTENOEO FOR USE IN OR INCIDENT TO Rl:SEARCH, MEDICAL OIAGNOSIS OR TREATMENT. AOR EUROPEAN TRANSPORT STATEMENT; CARRIAGE IN ACCORDANCE WITH 1.1.4.2.1 LOGOS 11-157295 11/12 Page 14 of 25 HFNA-000002927 EPA Inspection Report - Page 1378 of 1969 Use of this system constitutes your agreement to the service conditions In the current FedEx Service Gulde, available on fedex.com. FedEx wit! not be responsible for any claim in excess of $100 per package, whether the result of loss, damage, delay, non--delivery, misdelivery, or ~isinformation, unless you dedare a higher va!ue1 pay an additional charge, document your actual loss and file a timely claim. Limitations found in the current FedEx Service Guide apply. Your right to recover from FedEx for any loss, induding intrinsic value of the package, loss of sales, income interest, profit, attorne/s fees, costs, and other f<;>rms of damage whether direct, incidental, consequential, or special is limited to the greater of $100 or the authorized declared value. Recovery cannot exceed actual documented loss. Maximum far items of extraordinar1 value is $1,000, e.g. jewelry, precious meta is, negotiable instruments and other items listed in our Service Guide. Written claims must be Wed within strict time limits, see current Pt:dEx Service Guide. ---------:7'-t::==r.:;f.;;;;r,~, :aweN oc.J, :aiea 1V3S A<JOJ.sno . '"- r'"'' ..""l:)" ....-"r...-- CONSIGNEE COPY PLEASE PLACE IN FRONT OF POUCH 1. Fold the- printed page along ihe horizontal Hne 2. P!a,:a tabe! in shipping pouch and affix it to your shipment. ;,o ~r )> """' men -i 0 (,0 w 0 c , G) u (,0 .0... N ~ (,0 X.... t: "' .... _-i )>,O > C :c~ 0 .,, ::0 ,, 5 ;31 2:! -l -< .......... g ... m z> ::0 z ..... 0 c5 w ::x: -l !i; I .... .... ~ .... 0 q~~::r.: (/) ..... )> (') ~~ m=I.m,, :,:,:c:o:: c:: 0 .i::,. (J'I ro en :;o ~;ii - g; (I) =i m 0 -<z m ~s:: > = 0:z g;-l "0 ' en -< ma, G) c("J')~"O' = = -I : ::z ~ tnO = >< (") z """ -.I r- C ~ --= -.I "ii =i -<~ = 0 "T1 u:> en = ~ (D' ~ = = ~g ,-, 551C21D74Cn04c Page 15 of 25 HFNA-000002928 EPA Inspection Report - Page 1379 of 1969 18-Jan-2019 Corey Grandits ALS Environmental 10450 Stancliff Rd Suite 210 Houston, TX 77099 Re: HS19010542 Dear Corey, Work Order: 1901729 ALS Environmental received 4 samples on 15-Jan-2019 12:00 PM for the analyses presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental - Holland and for only the analyses requested. Sample results are compliant with industry accepted practices and Quality Control results achieved laboratory specifications. Any exceptions are noted in the Case Narrative, or noted with qualifiers in the report or QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained from ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. The total number of pages in this report is 10. If you have any questions regarding this report, please feel free to contact me: ADDRESS: 3352 128th Avenue, Holland, Ml, USA PHONE: +1 (616) 399-6070 FAX: +1 (616) 399-6185 Sincerely, Electronically approved by: Chad Whelton Chad Whelton Project Manager Report of Laboratory Analysis Certificate No: MN 026-999-449 ~:>.c:Bf}H'J %Ul.t.t'J~t:3P% ::::::::. :.:: : .,.... Page 16 of25 HFNA-000002929 EPA Inspection Report - Page 1380 of 1969 ALS Group, USA Client: Project: \VorkOrder: ALS Environmental HS19010542 1901729 Lab Samp ID Client Sample ID 1901729-01 HS19010542-0l 1901729-02 HS19010542-02 1901729-03 HS19010542-03 1901729-04 HS19010542-04 Date: 18-Jan-19 Matrix Liquid Liquid Liquid Liquid Work Order Sample Summary Tag Number S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Collection Date 1/10/2019 09:53 1/10/2019 09: 13 1/10/2019 08:32 1/10/2019 08:35 Date Received 1/15/2019 12:00 1/15/2019 12:00 1/15/2019 12:00 1/15/2019 12:00 Hold Page 17 of25 Sample Summary Pagel of 1 HFNA-000002930 EPA Inspection Report - Page 1381 of 1969 ALS Group, USA Client: Project: WorkOrder: ALS Environmental HS19010542 1901729 Date: 18-Jan-19 QUALIFIERS, ACRONYl\1S, UNITS Qualifier ** a B E H Hr J ND 0 p R s u X Description Value exceeds Regulatory Limit Estimated Value Analyte is non-accredited Analyle detected in the associakd Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time BOD/CBOD - Sample was reset outside Hold Time, value should be considered estimated. Anal)1e is present al an estimated concentration between the MDL and Report Limit Not Detected at the Reporting Limit Sample amount is > 4 times amount spiked Dual Column results percent difference > 40% RPD above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL Analyte was detected in the Method Blank between the MDL and Reporting Limit, sample results may exhibit background or reagent contamination at the observed level. Acronym Description DUP Method Duplicate LCS Laboratory Control Sample LCSD Laboratory Control Sample Duplicate LOD Limit of Detection (see MDL) LOQ Limit ofQuantitation (see PQL) MBLK Method Blank MDL Method Detection Limit MS Matrix Spike MSD Matrix Spike Duplicate PQL Practical Quantitation Limit RPD Relative Percent Difference TDL Target Detection Limit TNTC Too Numerous To Count A APHA Standard Methods D ASTM E EPA SW SW-846 Update III Units Reported none Description Page 18 of25 QFPage 1 o/1 HFNA-000002931 EPA Inspection Report - Page 1382 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS19010542 HS19010542-0l 1/10/2019 09:53 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: J8-Jan-19 Result Qual Report Limit Work Order: 1901729 Lab ID: 1901729-01 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.944 D5057-90 none Analyst: RZM 1/17/201901:15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 19 of25 Analytical Results Page l of 4 HFNA-000002932 EPA Inspection Report - Page 1383 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS19010542 HS19010542-02 1/10/2019 09:13 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: J8-Jan-19 Result Qual Report Limit Work Order: 1901729 Lab ID: 1901729-02 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.01 none Analyst: RZM 1/17/201901:15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 20 of25 Analytical Results Page 2 of 4 HFNA-000002933 EPA Inspection Report - Page 1384 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS19010542 HS19010542-03 1/10/2019 08:32 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: J8-Jan-19 Result Qual Report Limit Work Order: 1901729 Lab ID: 1901729-03 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.15 none Analyst: RZM 1/17/201901:15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 21 of25 Analytical Results Page 3 of 4 HFNA-000002934 EPA Inspection Report - Page 1385 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS19010542 HS19010542-04 1/10/2019 08:35 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: J8-Jan-19 Result Qual Report Limit Work Order: 1901729 Lab ID: 1901729-04 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.14 none Analyst: RZM 1/17/201901:15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 22 of25 Analytical Results Page 4 of 4 HFNA-000002935 EPA Inspection Report - Page 1386 of 1969 ALS Group, USA Client: ALS Environmental Work Order: 1901729 Project: HS19010542 Batch ID: R253305 Instrument ID WETCHEM Method: D5057-90 Date: 18-Jan-19 QC BATCH REPORT DUP Client ID: Analyte Sample ID: 1901550-01A DUP Run ID: WETCHEM_190117K Units: none SeqNo: 5484733 Analysis Date: 1/17/2019 01:15 PM Prep Date: OF: 1 Result SPK Ref PQL SPK Val Value %REC Control Limit RPO Ref Value %RPO RPO Limit Qual Specific Gravity 1.001 0 0 0 0 0-0 1.001 0.02 20 ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------1 DUP Sample ID: 1901729-02A DUP Units: none Analysis Date: 1/17/2019 01:15 PM Client ID: HS19010542-02 Run ID: WETCHEM_190117K SeqNo: 5484748 Prep Date: OF: 1 Analyte Result SPK Ref PQL SPK Val Value %REC Control Limit RPO Ref Value %RPO RPO Limit Qual Specific Gravity 0.9931 0 0 0 0 0-0 1.01 1.71 20 The following samples were analyzed in this batch: 1901729-01A 1901729-04A 1901729-02A 1901729-03A Note: See Qualifiers Page for a list of Qualifiers and their explanation. Page 23 of25 QC Page: 1 of 1 HFNA-000002936 EPA Inspection Report - Page 1387 of 1969 10450 Stancliff Rd, Ste 210 Houston, TX 77099 T: + 1 281 530 5656 F: +1 281 530 5887 www.alsglobal.com Subcontract Chain of Custody COC ID: 10595 SUBCONTRACT TO: ALS Laboratory Group 3352 128th Ave. Holland, MI 494249263 CUSTOMER INFORMATION: Company: ALS Houston Contact: Address: Corey Grandits 10450 Stancliff Rd, Ste 210 Phone: + 1 281 530 5656 Email: Alternate Contact: Email: Corey.Grandits@alsglobal.com Jumoke M. Lawal jumoke.lawal@alsglobal.com LA~ SAMPLE 10 . cLIENT SAMPLE ~er. . ANALYSIS REQUESTED 1. HS19010542-01 S-1 (API HC) Sub Specific Gravity to ALS Holland 2. HS19010542-02 S-3 (API Water) Sub Specific Gravity to ALS Holland 3. HS19010542-03 S-5 (T-40) Sub Specific Gravity to ALS Holland 4. S-6 {T-41) Sub Specific Gravity to ALS Holland Phone: + 1 616 399 6070 INVOICE INFORMATION: Company: ALS Houston Contact: Accounts Payable Address: 10450 Stancliff Rd, Ste 210 Phone: +1 281 530 5656 Reference: TSR: HS19010542 Houston House Acct ..MATRIX Liquid Liquid Liquid Liquid ... COLLECT JDATE ..bweoi'"r~'e" : 10 Jan 2019 09:53 18 Jan 2019 10 Jan 2019 09:13 18 Jan 2019 10 Jan 2019 08:32 18 Jan 2019 10 Jan 2019 08:35 18 Jan 2019 Comments: Please analyze for the analysis listed above. Send report to the emails shown above. QC Level: STD (Laboratory Standard QC: method blank and LCS required} Relinquished By: Received By: Cooler ID(s): ~ Date/Time: Date/Time: Ternperature(s): 'J 1ttj;e; J&:o::> UaA1 1200 Page 24 of25 ~&\ 5Rl fu15 HFNA-000002937 EPA Inspection Report - Page 1388 of 1969 ALS Group, USA Client Name: Work Order: ALS - HOUSTON 1901729 Sample Receipt Checklist Date/Time Received: Received by: 15-Jan-19 12:00 Checklist completed by CA:'ue yJ~-z:u-u eSignature Matrices: Carrier name: Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Chain of custody present? Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Sample(s) received on ice? Temperature(s)/Thermometer(s): Cooler(s)/Kit(s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Login Notes: 15-Jan-19 Date Reviewed by: eSignature Yes [i,] Yes [i,] Yes Yes [i,] Yes [i,] Yes [i,] Yes [i,] Yes [i,] Yes [i,] Yes [i,] Yes [i,] Yes [i,] No No No No No D No D No D No No No No No Not Present D Not Present D Not Present [i,] r1/15/2019 3:09:08 PM Yes No VOA vials submitted [i,] Yes Yes D No N/A No D N/A 15-Jan-19 Date Client Contacted: Contacted By: Comments: Date Contacted: Regarding: Person Contacted: CorrectiveAction: ~agc=of'.15~ SRC Page 1 of 1 HFNA-000002938 EPA Inspection Report - Page 1389 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 February 18, 2019 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling (EOL) Dear Gabriela, Work Order: HS19020431 ALS Environmental received 9 sample(s) on Feb 08, 2019 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, ~:::~:::::::~=--z,... t-{;-;...-, Generated By: JUMOKE.LAWAL Corey Grandits Project Manager Right Solutions Right Partnu www.a!sg!obaLcom Pagel of33 HFNA-000002939 EPA Inspection Report - Page 1390 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 lab Samp ID HS19020431-01 HS19020431-02 HS19020431-03 HS19020431-04 HS19020431-05 HS19020431-06 HS19020431-07 HS19020431-08 HS19020431-09 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Matrix Liquid Liquid Liquid Liquid Water Water Water Liquid Water Date: 18-Feb-19 SAMPLE SUMMARY TagNo Collection Date 07-Feb-2019 09:08 07-Feb-2019 09:25 07-Feb-2019 08:46 07-Feb-2019 08:51 07-Feb-2019 09:21 07-Feb-2019 09:40 07-Feb-2019 09:40 07-Feb-2019 00:00 07-Feb-2019 00:00 Date Received 08-Feb-2019 09:00 08-Feb-2019 09:00 08-Feb-2019 09:00 08-Feb-2019 09:00 08-Feb-2019 09:00 08-Feb-2019 09:00 08-Feb-2019 09:00 08-Feb-2019 09:00 08-Feb-2019 09:00 Hold D D D D D D D D D Page 2 of33 HFNA-000002940 EPA Inspection Report - Page 1391 of 1969 ALS Houston, US Date: 18-Feb-19 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 GCMS Volatiles by Method SW8260 Batch ID: R332681,R332699,R332762,R332986 CASE NARRATIVE The test results meet requirements of the current NELAP standards, state requirements or programs where applicable. Batch ID: R332646 Sample ID: S-5 (T-40) (HS19020431-03) Lowest practical dilution for HS19020431-03 due to sample matrix. Surrogate failure due to matrix. Sample ID: S-6 (T-41) (HS19020431-04) Lowest practical dilution for HS19020431-04 due to sample matrix Page 3 of33 HFNA-000002941 EPA Inspection Report - Page 1392 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (API HC) 07-Feb-2019 09:08 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 5.5 93.9 96.8 90.4 104 Method:SW8260 0.024 REPORT LIMIT 0.24 70-126 70-130 70-130 70-130 Date: 18-Feb-19 ANALYTICAL REPORT Work0rder:HS19020431 Lab ID:HS19020431-01 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 12-Feb-2019 17:41 12-Feb-2019 17:41 12-Feb-2019 17:41 12-Feb-2019 17:41 12-Feb-2019 17:41 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of33 HFNA-000002942 EPA Inspection Report - Page 1393 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 07-Feb-2019 09:25 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.46 87.9 97.1 93.4 98.3 Method:SW8260 0.030 REPORT LIMIT 0.25 70-126 82-124 77-123 82-127 Date: 18-Feb-19 ANALYTICAL REPORT Work0rder:HS19020431 Lab ID:HS19020431-02 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: PC 15-Feb-2019 16:07 15-Feb-2019 16:07 15-Feb-2019 16:07 15-Feb-2019 16:07 15-Feb-2019 16:07 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of33 HFNA-000002943 EPA Inspection Report - Page 1394 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 07-Feb-2019 08:46 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.024 92.5 103 68.9 97.4 Method:SW8260 0.024 s REPORT LIMIT 0.24 70-126 70-130 70-130 70-130 Date: 18-Feb-19 ANALYTICAL REPORT Work0rder:HS19020431 Lab ID:HS19020431-03 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 11-Feb-2019 22:54 11-Feb-2019 22:54 11-Feb-2019 22:54 11-Feb-2019 22:54 11-Feb-2019 22:54 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of33 HFNA-000002944 EPA Inspection Report - Page 1395 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-6 (T-41) 07-Feb-2019 08:51 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.21 98.2 100 77.3 97.0 Method:SW8260 J 0.024 REPORT LIMIT 0.24 70-126 70-130 70-130 70-130 Date: 18-Feb-19 ANALYTICAL REPORT Work0rder:HS19020431 Lab ID:HS19020431-04 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 11-Feb-2019 23:19 11-Feb-2019 23:19 11-Feb-2019 23:19 11-Feb-2019 23:19 11-Feb-2019 23:19 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of33 HFNA-000002945 EPA Inspection Report - Page 1396 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Field Blank 07-Feb-2019 09:21 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 86.5 99.8 94.1 95.1 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 18-Feb-19 ANALYTICAL REPORT Work0rder:HS19020431 Lab ID:HS19020431-05 Matrix:Water UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 12-Feb-2019 10:18 12-Feb-2019 10:18 12-Feb-2019 10:18 12-Feb-2019 10:18 12-Feb-2019 10:18 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 8 of33 HFNA-000002946 EPA Inspection Report - Page 1397 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 1 07-Feb-2019 09:40 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 85.9 97.9 93.6 97.6 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 18-Feb-19 ANALYTICAL REPORT Work0rder:HS19020431 Lab ID:HS19020431-06 Matrix:Water UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 12-Feb-2019 10:42 12-Feb-2019 10:42 12-Feb-2019 10:42 12-Feb-2019 10:42 12-Feb-2019 10:42 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 9 of33 HFNA-00000294 7 EPA Inspection Report - Page 1398 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 2 07-Feb-2019 09:40 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 86.4 97.2 92.5 97.3 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 18-Feb-19 ANALYTICAL REPORT Work0rder:HS19020431 Lab ID:HS19020431-07 Matrix:Water UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 12-Feb-2019 16:29 12-Feb-2019 16:29 12-Feb-2019 16:29 12-Feb-2019 16:29 12-Feb-2019 16:29 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 10 of33 HFNA-000002948 EPA Inspection Report - Page 1399 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Duplicate 07-Feb-2019 00:00 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.43 87.8 99.7 94.4 95.4 Method:SW8260 0.030 REPORT LIMIT 0.25 70-126 82-124 77-123 82-127 Date: 18-Feb-19 ANALYTICAL REPORT Work0rder:HS19020431 Lab ID:HS19020431-08 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: PC 15-Feb-2019 16:31 15-Feb-2019 16:31 15-Feb-2019 16:31 15-Feb-2019 16:31 15-Feb-2019 16:31 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 11 of33 HFNA-000002949 EPA Inspection Report - Page 1400 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Trip Blank 07-Feb-2019 00:00 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 86.1 96.6 93.0 97.5 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 18-Feb-19 ANALYTICAL REPORT Work0rder:HS19020431 Lab ID:HS19020431-09 Matrix:Water UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 12-Feb-2019 16:53 12-Feb-2019 16:53 12-Feb-2019 16:53 12-Feb-2019 16:53 12-Feb-2019 16:53 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 12 of33 HFNA-000002950 EPA Inspection Report - Page 1401 of 1969 ALS Houston, US Client: Navajo Refining Company Project: BWON Monthly Sampling (EOL) WorkOrder: HS19020431 Batch ID: 2910 SamplD HS19020431-01 HS19020431-03 HS19020431-04 Method: VOLATl LES BY SW8260C Container Sample Wt/Vol 5.127 (g) 5.16 (g) 5.188 (g) Final Volume 5 (ml) 5 (ml) 5 (ml) Weight Factor 0.98 0.97 0.96 Container Type Bulk (5030B) Bulk (5030B) Bulk (5030B) Date: 18-Feb-19 WEIGHT LOG Page 13 of33 HFNA-000002951 EPA Inspection Report - Page 1402 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 Sample ID Client Samp ID Collection Date TCLP Date Batch ID R332646 Test Name : VOLATILES BY SW8260C HS 19020431-03 HS19020431-04 S-5 (T-40) S-6 (T-41) 07 Feb 2019 08:46 07 Feb 2019 08:51 Batch ID R332681 Test Name: VOLATILES BY SW8260C HS19020431-01 S-1 (API HC) 07 Feb 2019 09:08 Batch ID R332699 Test Name : VOLATILES - SW8260C HS19020431-05 HS19020431-06 Field Blank EQ Blank Port 1 07 Feb 2019 09:21 07 Feb 2019 09:40 Batch ID R332762 Test Name ; VOLATILES - SW8260C HS19020431-07 HS19020431-09 EQ Blank Port 2 Trip Blank 07 Feb 2019 09:40 07 Feb 2019 00:00 Batch ID R332986 Test Name: VOLATILES- SW8260C HS19020431-02 HS19020431-08 S-3 (API Water) Duplicate 07 Feb 2019 09:25 07 Feb 2019 00:00 Date: 18-Feb-19 DATES REPORT Prep Date Analysis Date DF Matrix: Liquid 11 Feb 2019 22:54 50 11 Feb201923:19 50 Matrix: Liquid 12 Feb 2019 17:41 50 Matrix: water 12 Feb201910:18 12 Feb 2019 10:42 Matrix; Water 12 Feb 2019 16:29 12 Feb 2019 16:53 Matrix: Liquid 15 Feb 2019 16:07 50 15 Feb 2019 16:31 50 Page 14 of33 HFNA-000002952 EPA Inspection Report - Page 1403 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 Date: 18-Feb-19 QC BATCH REPORT Batch ID: R332646 Instrument: VOA8 Method; SW8260 MBLK Client ID: Analyte Sample ID: MBLKW1-021119 Units: ug/Kg Analysis Date: 11-Feb-2019 14:08 Run ID: VOA8_332646 SeqNo: 4944906 Prep Date: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 25 2859 2473 2576 2643 250 0 2500 0 2500 0 2500 0 2500 0 114 76 - 125 0 98.9 80 - 120 0 103 80 - 119 0 106 81 - 118 LCS Client ID: Analyte Sample ID: VLCSW1-021119 Units: ug/Kg Analysis Date: 11-Feb-2019 13:18 Run ID: VOA8_332646 SeqNo: 4944905 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 46.92 5.0 50 46.99 0 50 50.17 0 50 50.53 0 50 49.17 0 50 0 93.8 75 - 124 0 94.0 76 - 125 0 100 80 - 120 0 101 80 - 119 0 98.3 81 - 118 MS Client ID: Analyte Sample ID: HS19011582-02MS Units: ug/Kg Analysis Date: 11-Feb-2019 17:04 Run ID: VOA8_332646 SeqNo: 4945581 Prep Date: OF: 500 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 20400 18040 18770 18990 18700 1900 0 0 0 0 19250 19250 19250 19250 19250 216.2 0 0 0 0 105 93.7 97.5 98.6 97.1 70 - 130 70 - 126 70 - 130 70 - 130 70 - 130 Page 15 of 33 HFNA-000002953 EPA Inspection Report - Page 1404 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 Date: 18-Feb-19 QC BATCH REPORT Batch ID: R332646 Instrument: VOA8 Method; SW8260 MSD Client ID: Analyte Sample ID: HS19011582-02MSD Units: ug/Kg Analysis Date: 11-Feb-2019 17:29 Run ID: VOA8_332646 Seq No: 4945582 PrepDate: OF: 500 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene 21380 1900 19250 216.2 110 70 - 130 20400 4.7 30 Surr: 1,2-0ichloroethane-d4 17420 0 19250 0 90.5 70 - 126 18040 3.45 30 Surr: 4-Bromofluorobenzene 19850 0 19250 0 103 70 - 130 18770 5.6 30 Surr: Dibromofluoromethane 18620 0 19250 0 96.7 70 - 130 18990 1.97 30 Surr: Toluene-dB 19230 0 19250 0 99.9 70 - 130 18700 2.81 30 The following samples were analyzed in this batch: ~f_s_19_0_20_4_3_1-_0_ 3 _ _ _ HS _ 190_ 204_ 31-_ 04 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _~ Page 16 of33 HFNA-000002954 EPA Inspection Report - Page 1405 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 Date: 18-Feb-19 QC BATCH REPORT Batch ID: R332681 Instrument: VOA8 Method; SW8260 MBLK Client ID: Analyte Sample ID: MBLKW1-021219 Units: ug/Kg Analysis Date: 12-Feb-2019 10:12 Run ID: VOA8_332681 SeqNo: 4945869 Prep Date: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 25 2687 2524 2508 2565 250 0 2500 0 2500 0 2500 0 2500 0 107 76 - 125 0 101 80 - 120 0 100 80 - 119 0 103 81 - 118 LCS Client ID: Analyte Sample ID: VLCSW1-021219 Units: ug/Kg Analysis Date: 12-Feb-2019 09:22 Run ID: VOA8_332681 SeqNo: 4945868 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 42.79 5.0 50 46.34 0 50 49.09 0 50 50.35 0 50 49.69 0 50 0 85.6 75 - 124 0 92.7 76 - 125 0 98.2 80 - 120 0 101 80 - 119 0 99.4 81 - 118 MS Client ID: Analyte Sample ID: HS19020429-01 MS Units: ug/Kg Analysis Date: 12-Feb-2019 12:17 Run ID: VOA8_332681 SeqNo: 4946400 Prep Date: OF: 50000 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 4216000 2332000 2402000 2497000 2534000 250000 0 0 0 0 2.5e+006 2.5e+006 2.5e+006 2.5e+006 2.5e+006 1722000 0 0 0 0 99.7 93.3 96. 1 99.9 101 70 - 130 70 - 126 70 - 130 70 - 130 70 - 130 Page 17 of33 HFNA-000002955 EPA Inspection Report - Page 1406 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 Date: 18-Feb-19 QC BATCH REPORT Batch ID: R332681 Instrument: VOAS Method; SW8260 MSD Client ID: Analyte Sample ID: HS19020429-01 MSD Units: ug/Kg Analysis Date: 12-Feb-2019 12:42 Run ID: VOA8_332681 SeqNo: 4946401 Prep Date: OF: 50000 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene 4185000 250000 Surr: 1,2-0ichloroethane-d4 2245000 0 Surr: 4-Bromofluorobenzene 2455000 0 Surr: Dibromofluoromethane 2438000 0 rs Surr: Toluene-dB 2481000 0 The following samples were analyzed in this batch: 19020431-01 2.5e+006 2.5e+006 2.5e+006 2.5e+006 2.5e+006 1722000 0 0 0 0 98.5 89.8 98.2 97.5 99.2 70 - 130 70 - 126 70 - 130 70 - 130 70 - 130 4216000 2332000 2402000 2497000 2534000 0.736 30 3.83 30 2.19 30 2.38 30 2.12 30 Page 18 of 33 HFNA-000002956 EPA Inspection Report - Page 1407 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 Date: 18-Feb-19 QC BATCH REPORT Batch ID: R332699 Instrument: VOA6 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-190211 Units: ug/L Analysis Date: 12-Feb-2019 01 :04 Run ID: VOA6_332699 SeqNo: 4946079 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 44.55 0 50 48.48 0 50 47.15 0 50 49.21 0 50 0 89.1 70 - 130 0 97.0 82 - 115 0 94.3 73 - 126 0 98.4 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-190211 Units: ug/L Analysis Date: 12-Feb-2019 00:16 Run ID: VOA6_332699 SeqNo: 4946078 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 19.46 5.0 20 44.14 0 50 49.62 0 50 48.02 0 50 48.72 0 50 0 97.3 74 - 120 0 88.3 70 - 130 0 99.2 82 - 115 0 96.0 73 - 126 0 97.4 81 - 120 MS Client ID: Analyte Sample ID: HS19020131-01MS Units: ug/L Analysis Date: 12-Feb-2019 01 :52 Run ID: VOA6_332699 SeqNo: 4946081 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 20.57 5.0 20 43.86 0 50 48.28 0 50 47.71 0 50 49.68 0 50 0 103 70 - 127 0 87.7 70 - 126 0 96.6 82 - 124 0 95.4 77 - 123 0 99.4 82 - 127 Page 19 of33 HFNA-000002957 EPA Inspection Report - Page 1408 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 Date: 18-Feb-19 QC BATCH REPORT Batch ID: R332699 Instrument: VOAG Method; SW8260 MSD Client ID: Analyte Sample ID: HS19020131-01MSD Units: ug/L Analysis Date: 12-Feb-2019 02:16 Run ID: VOA6_332699 SeqNo: 4946082 PrepDate: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 19.94 5.0 20 43.46 0 50 49.53 0 50 47.34 0 50 48.22 0 50 0 99.7 70 - 127 0 86.9 70 - 126 0 99.1 82 - 124 0 94.7 77 - 123 0 96.4 82 - 127 20.57 43.86 48.28 47.71 49.68 3.1 20 0.921 20 2.56 20 0.774 20 2.99 20 The following samples were analyzed in this batch: ~f_s_19_0_20_4_3_1-_o_s- - -H- S 1- 902- 043-1-0- 6 - - - - - - - - - - - - - - - - - - - ~ Page 20 of33 HFNA-000002958 EPA Inspection Report - Page 1409 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 Date: 18-Feb-19 QC BATCH REPORT Batch ID: R332762 Instrument: VOA6 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-190212 Units: ug/L Analysis Date: 12-Feb-2019 13:40 Run ID: VOA6_332762 SeqNo: 4947689 Prep Date: OF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 43.28 0 50 48.21 0 50 46.64 0 50 48.57 0 50 0 86.6 70 - 130 0 96.4 82 - 115 0 93.3 73 - 126 0 97.1 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-190212 Units: ug/L Analysis Date: 12-Feb-2019 12:52 Run ID: VOA6_332762 SeqNo: 4947688 Prep Date: OF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 18.26 5.0 20 42.61 0 50 47.72 0 50 47.29 0 50 49.32 0 50 0 91.3 74 - 120 0 85.2 70 - 130 0 95.4 82 - 115 0 94.6 73 - 126 0 98.6 81 - 120 MS Client ID: Analyte Sample ID: HS19020369-01 MS Units: ug/L Analysis Date: 12-Feb-2019 14:53 Run ID: VOA6_332762 SeqNo: 4947692 Prep Date: OF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 20.51 5.0 20 43.13 0 50 48.79 0 50 47.1 0 50 49.49 0 50 0 103 70 - 127 0 86.3 70 - 126 0 97.6 82 - 124 0 94.2 77 - 123 0 99.0 82 - 127 Page 21 of33 HFNA-000002959 EPA Inspection Report - Page 1410 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 Date: 18-Feb-19 QC BATCH REPORT Batch ID: R332762 Instrument: VOA6 Method; SW8260 MSD Client ID: Analyte Sample ID: HS19020369-01 MSD Units: ug/L Analysis Date: 12-Feb-2019 15:17 Run ID: VOA6_332762 SeqNo: 4947693 PrepDate: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 19.54 5.0 20 43.69 0 50 49.59 0 50 47.71 0 50 48.11 0 50 0 97.7 70 - 127 0 87.4 70 - 126 0 99.2 82 - 124 0 95.4 77 - 123 0 96.2 82 - 127 20.51 43.13 48.79 47.1 49.49 4.83 20 1.28 20 1.63 20 1.28 20 2.83 20 The following samples were analyzed in this batch: ~ f _ s _ 1 9 _ 0 _H2S0190_20443_1-039 _ 1 - _ 0 7 - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ Page 22 of33 HFNA-000002960 EPA Inspection Report - Page 1411 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 Date: 18-Feb-19 QC BATCH REPORT Batch ID: R332986 Instrument: VOA6 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-190215 Units: ug/L Analysis Date: 15-Feb-2019 12:30 Run ID: VOA6_332986 SeqNo: 4952463 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 43.57 0 50 49.02 0 50 47.09 0 50 48.27 0 50 0 87.1 70 - 130 0 98.0 82 - 115 0 94.2 73 - 126 0 96.5 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-190215 Units: ug/L Analysis Date: 15-Feb-2019 11:42 Run ID: VOA6_332986 SeqNo: 4952462 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 18.29 5.0 20 43.43 0 50 49.96 0 50 47.65 0 50 48.08 0 50 0 91.5 74 - 120 0 86.9 70 - 130 0 99.9 82 - 115 0 95.3 73 - 126 0 96.2 81 - 120 MS Client ID: Analyte Sample ID: HS19020270-01 MS Units: ug/L Analysis Date: 15-Feb-2019 15:18 Run ID: VOA6_332986 SeqNo: 4952468 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 20.15 5.0 20 43.32 0 50 48.59 0 50 47.44 0 50 48.76 0 50 0 101 70 - 127 0 86.6 70 - 126 0 97.2 82 - 124 0 94.9 77 - 123 0 97.5 82 - 127 Page 23 of33 HFNA-000002961 EPA Inspection Report - Page 1412 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 Date: 18-Feb-19 QC BATCH REPORT Batch ID: R332986 Instrument: VOA6 Method; SW8260 MSD Client ID: Analyte Sample ID: HS19020270-01 MSD Units: ug/L Analysis Date: 15-Feb-2019 15:42 Run ID: VOA6_332986 SeqNo: 4952469 PrepDate: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene 19.74 5.0 20 0 98.7 70 - 127 20.15 2.05 20 Surr: 1,2-0ichloroethane-d4 43.73 0 50 0 87.5 70 - 126 43.32 0.929 20 Surr: 4-Bromofluorobenzene 49.43 0 50 0 98.9 82 - 124 48.59 1.71 20 Surr: Dibromofluoromethane 47.29 0 50 0 94.6 77 - 123 47.44 0.33 20 Surr: Toluene-dB 48.07 0 50 0 96.1 82 - 127 48.76 1.41 20 The following samples were analyzed in this batch: ~f_s_19_0_20_4_3_1-_0_ 2 _ _ _ HS1_90_ 204_ 31-_ 08 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _~ Page 24 of33 HFNA-000002962 EPA Inspection Report - Page 1413 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 Date: 18-Feb-19 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND O P R S U Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SOL TRRP Unit Reported mg/Kg mg/L Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL/SOL Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Description Milligrams per Kilogram Milligrams per Liter Page 25 of33 HFNA-000002963 EPA Inspection Report - Page 1414 of 1969 ALS Houston, US Agency Arkansas Texas North Dakota Illinois Louisiana Dept of Defense Kentucky Kansas Oklahoma North Carolina California Maryland Date: 18-Feb-19 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number 88-0356 T10470231-18-21 R193 2018-2019 004438 03087 ANAB L2231 123043 - 2018 E-10352 2018-2019 2018-156 624-2019 2919, 2018-2019 343, 2018-2019 Expire Date 27-Mar-2019 30-Apr-2019 30-Apr-2019 29-Jun-2019 30-Jun-2019 20-Dec-2021 30-Apr-2019 31-Jul-2019 31-Aug-2019 31-Dec-2019 30-Apr-2019 30-Jun-2019 Page 26 of33 HFNA-000002964 EPA Inspection Report - Page 1415 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020431 Lab Sarnp ID HS19020431-01 HS19020431-02 HS19020431-03 HS19020431-04 HS19020431-05 HS19020431-06 HS19020431-07 HS19020431-08 HS19020431-09 Client Sample ID S-1 (API HG) S-3 (API Water) S-5 (T-40) S-6 (T-41) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Action Login Login Login Login Login Login Login Login Login Date 2/8/2019 3:02:47 PM 2/8/2019 3:02:47 PM 2/8/2019 3:02:47 PM 2/8/2019 3:02:47 PM 2/8/2019 3:02:47 PM 2/8/2019 3:02:47 PM 2/8/2019 3:02:47 PM 2/8/2019 3:02:47 PM 2/8/2019 3:02:47 PM Date: 18-Feb-19 SAMPLE TRACKING Person PMG PMG PMG PMG PMG PMG PMG PMG PMG New Location VOA060 VOA060 VOA060 VOA060 VOA060 VOA060 VOA060 VOA060 VOA060 Page 27 of33 HFNA-000002965 EPA Inspection Report - Page 1416 of 1969 ALS Houston, US Client Name: Work Order: Navajo Refining HS19020431 Date/Time Received: Received by: Date: 18-Feb-19 Sample Receipt Checklist 08-Feb-2019 09:00 NDR Checklist completed by: Paresh M. Giga eSignature Matrices: Soil/water 8-Feb-2019 Date Reviewed by: Carrier name: Corey Grandits eSignature FedEx 13-Feb-2019 Date Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? VOA/TX1005/TX1006 Solids in hermetically sealed vials? Chain of custody present? Chain of custody signed when relinquished and received? Samplers name present on COG? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler( s )/Kit( s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Login Notes: Client Contacted: Date Contacted: Contacted By: Regarding: Comments: Yes ~ Yes D Yes D Yes D Yes ~ Yes ~ Yes [] Yes ~ Yes ~ Yes ~ Yes @ Yes ~ Yes @ 0.8c/1.1 c U/C Hazmatpac 2/8/19 15:20 Yes~ Yes~ Yes D No D No D No D No D No D No D No D No D No D No D No D No D No D Not Present D Not Present ~ Not Present ~ Not Present @ 1 Page(s) COC 1Ds:None ll1R25 No D No D No ~ D No VOA vials submitted N/A D N/A D Person Contacted: Corrective Action: Page 28 of33 HFNA-000002966 EPA Inspection Report - Page 1417 of 1969 Chain of Custody Form Page _1_ of HS19020431 Navajo Refining Company BWON Monthly Sampling (EOL) Enuironmentaa ALS Project Manager: Eric.a Padilla 1111111111111 IIH IIIIIIIH II :: P.urc;tiase Oi:der .......... Pr6j~i:tNani~ BWON Monthly Sampling (EOL) A.'. VOLATILES (8260) Benzene >~~rnpaWNarrie Navajo Refining Company LLC <~il(ToCcimpany Holly Frontier Navajo Refining LLC .. .. ............... c Tyler Turner Gabi Combs . ... ....... << P.O. Box 159 , ......... ... ... 501 East Main , >< <: ~ityiS:t~tet#ip Artesia, NM 88211-0159 ): >~ityJS1ateiZip Artesia, New Mexico 88210 >< ::i>~ciiie (575) 748-3311 ' > Phone (575) 748-3311 .....< :~ax (575) 746-5451 <Ii f::,iic (575) 746-5451 I +Niaii.Ad~res~: Suzanne.Aguilar@hollyfrontier.com :J N~: : .... ::<<. : ~~Af~i~~~~tttptib~: >.. < : /ci~te 'fi~~ :: <NiatnX: /Pres. :ii~oi~.;J t }fl. f I f S-1 (API HC) 02/07/19 9:08AM Liquid 8 X t S-3 (API Water) 02/07/19 9:25AM Liquid 8,1 X ::r S-5 (T-40) 02/07/19 8:46AM Liquid 8 1 X . 4 S-6 (T-41) 02/07/19 8:51 AM Liquid 8 1 X ;5: : Field Blank 02/07/19 9:21 AM liquid 8,1 1 X if: EQ Blank Port 1 02/07/19 9:40 AM liquid 8,1 1 X i : EQ Blank Port 2 02/07/19 9:40 AM Liquid 8,1 1 X <:S: Duplicate 02/07/19 XXX Liquid 8,1 1 X : :9::: Trip Blank 02/07/19 XXX liquid 8,1 2 X /10:< Temperature Blank 02/07/19 Liquid D .. :: f: I I. H 1::::i:: ) UIf or I ,aJ ! i sq i -- I I ::H;1f I i ! .--i Ji Relinquished by: lJt4tJ., l{,bbA,rcJl Date: .,t.. L- ., t111 I Relinquished by: ' Date: - - Log1;1ed by (Laboi;a.toty): . .... i .. !?at&: . .. . .. Preservative Kay; .1-HCl . . '. 2-HN03 ... . Note: Any changes must be made in writing once samples Time: Received by: Time: . Tim.e: .. . 4-NaOH .5-Na2S203 6-NaHS04 ' . .. and COC Form have been submitted to ALS !Required Turnaround Time: D STD 10 Wk Days 0 5 Wk Days D Notes: Ii , ' 1-Qther 8-4 degrees C < ::... ~.:~!is:"" ' '11: 2,.-; Laboratory Group. Oother _ _ __ 2 Wk Days D 24 Hour :Gl~ f>:ackag:e: (C.he61d3ox Below}::::: Level III: Std QC+ Raw Data Level IV: SW846 CLP-Like jTRRP-Checklist ITRRP Level IV Other: Copyright 2009 by ALS Laboratory Group Page 29 of33 HFNA-000002967 EPA Inspection Report - Page 1418 of 1969 Shipper NAVAJO REFINING COMPANY C/0 AQUA MICROBICS 501 E MAIN ARTESIA NM88210 US Consignee Corey Grandits ALS 10450 Stancliff Suite 210 HOUSTON TX77099 US Two completed and signed copies of this Declaration must be handed to the operator TRANSPORT DETAILS This shipment is within the limitations prescribed for: (delete non applicable) Airport of Departure ARTESIA (Provide at least three copies to airline.) Air Waybill No. 709308590740 Page 1 of 1 Page(s) ~ : x Shipper's Reference Number {optional) 18 Compliant Express CAFE3211 WARNING Failure to comply with all respects with the applicable Dangerous Goods Regulations may be in breach of the applicable law ,subject to legal penalties. ~ 1 FT ' Airport ofDestination: HOUSTON ABSGRA Shioment tvoe: (delete 11011 applicable) I NON. NATURE AND QUANTITY OF DANGEROUS GOODS UN Number or identification Number, proper shipping riame, Class or Division (subsidiary risk), packing group (if required), and all other required information. UN 3266, Corrosive liquid. basic, inorganic, n.o.s.(Sodium Hydroxide),8,1/1 UN 1268, Petroleum distillates, n.o.s.,3,!11// 0.04 U/366 All Packed In One FIBREBOARD BOX Q = 0.1 0.08 U/854 . -A--d-d-i~tio-n--a-l-H--a-n-d-l-in-g--I-n-f-o-r-m--a-t-io-n---------------------------------------------------------------------------------------------------- 24Hour Emergency Respcnse-CHEMTREC 1~800-424-9300, CCN 201319 I hereby declare that the contents of this consignment are fully and accurately described above by the proper shipping name, and are classified1 packaged, marked and labelledlplacarded, and are in all respects in proper condition for transport according to applicable !nte-mational and National Governmental Regulations. I declare that all of the applicable alr transport requirements have been met. 18004249300 Emo;gency Telephone Number Name/Title of Signatory Brady Hubbard/Environmenia! Coordinator Place and Date Artesia, NM 02/07/2019 Signature (:res warning above) Brady Hubbard i~~ FOR RADIOACTIVE MATERIAL SHIPMENT ACCEPTABLE FOR PASSENGER AIRCRAFT, THE SHIPMENT CONTAINS RAOlOACTlVE MATERIAL INTENDED FOR. USE !NOR INCIDENT TO RESEARCH, MEDICAL DIAGNOSIS OR TR.EAThllENT. ADR EUROPEAN TRANSPORT STATEMENT: CARRIAGE IN ACCORDANCE WlTH 1.1.4.2.1 LOG05 J/1S7295 11112 Page 30 of33 HFNA-000002968 EPA Inspection Report - Page 1419 of 1969 --------- ~--- :::::~R'S DECLARATION FOR DANGEROUS GOODS (Provide at least three copies to airline.) NAVAJO REFINING COMPANY C/0 AQUA MICROBICS 5D1 E MAIN Air Waybill No. 709308590740 Page 1 of 1 Page(s) - ARTESIA NM88210 US Shipper's Reference Number (optional} Consignee - Corey Grandits ALS 10450 Stancliff Suite 210 HOUSTON TX77099 US ~:X18Compliant Express CAFE3211 Two completed and signed copies of this Declaration must be handed to the operator WARNING TRANSPORT DETAILS This shipment is within the limitations orescribed for:: (delete non applicable} Airport of Departure ARTESIA Failure to comply with all respects with the applicable Dangerous Goods Regulations may be in breach of the applicable law ,subject to legal penalties. Airport of Destioation: HOUSTON ABSGRA Shiomen! tvoe: (delete non applicable) NATURE AND QUANTITY OF DANGEROUS GOODS UN Number or ;de11tifir:ation Number, proper shipping name, Class or Division (subsidiary risk), packing group (if required}, and ali other required informaUon. UN 3266, Corrosive liquid, basic, inorganic, n.o.s.(Sodium Hydroxide),8,1// UN 1268, Petroleum distillates. n.Q.S.,3,111/1 0.04 U/366 All Packed In One FIBREBOARD BOX Q = 0.1 0.08 U/854 Additional Handling Information 24-Hour Emergency Response-- CHEMTREC 1-800-424-9300, CCN 201319 I hereby declare that the contents of this consignment are fully and Name/Title of Signatory accurately described above by the proper shipping name, and are Brady Hubbard/Environmenta! Coordinator classified, packaged, marked and labelled/placarded, and are in all respects in proper condition for transport according to applicable International and National Governmental Regulations. l declare that Place and Date Artesia, NM 02/07/2019 all of the appHcable air transport requirements have been met. 1 - - - - - - - - - - - - - - - - - - - - - 1 (seewamingabovej Signature 18004249300 Emergency Telephone Numb6r Brady Hubbard ~~ FOR RADIOACTIVE MATERIAi.. SHlPMENT ACCEPTABLE FOR PASSENGERAIRCRA.FT, THE SHIPMENT CONTAINS RAO!OACTIVE MATERIAL INTENDED FOR USE IN OR INC!OENTTO RESEARCH, MEDICAL DIAGNOSIS OR TREATMENT. AOR EUROPEAN TRANSPORT STATEMENT: CARR1AGE IN ACCORDANCE WITH 1.1.4.2.1 tOG0,#15729511/12 Page 31 of33 HFNA-000002969 EPA Inspection Report - Page 1420 of 1969 Shipper NAVAJO REF!NING COMPANY C/0 AQUA MICROBICS 501 E MAIN ARTESIA NM85210 US . Consignee Corey Grandits ALS 10450 Stancliff Suite 210 HOUSTON TX77099 US (Provide at least three copies to airline.) Air Waybill No. 709308590740 Page 1 of 1 Page(s) ~ : x Shipper's Reference Number (optional) 18 Compliant Express CAFE3211 Two completed and signed copies of this Declaration mu$t be handed to the operato I r WARNING TRANSPORT DETAILS This shipment ls within the limitations prescribed for: (delete non applicable) Airport of Departure ARTESIA ~ y FT Airport of Destination: HOUSTON . ABSGRA Failure to comply with all respects with the applicable Dangerous Goods Regulations may be in breach of the applicable law ,subject to legal penalties. Shioment tvno; (delete non applicable) n. NATURE AND QUANTITY OF DANGEROUS GOODS UN Number or identification Numbe,~ proper shipping name, Class or Division (subsidiary risk), packing group (if required), and all other required information. UN 3266, Corrosive liquid, basic, i[lorganic, n.o.s.(Sodium Hydroxide).8,11/ UN 1268, Petroleum distillates, n.o.s.. 3,llli/ 0.04 U/366 All Packed In One FIBREBOARD BOX Q =0.1 0.08 U/854 -A-d--d-it-i-o-n-a-l--H-a-n-d--li-n-g--In--fo--rm--a-t-i-o-n--~------------------------------------------------------------------------------------------------ 24-Hour Emergency Response-- CHEMTREC 1--800-4249300, CCN 201319 I hereby declare that the contents of this consignment are fully and accurately described above by the proper shipping name, and are classified, packaged, marked and labelled/placarded:, and are in all respects in proper condition tor transport according to applicable International and National Governmental Regulations. I declare that all of the applicable air transport requireffients have been met. Name/Tltle of Signatory Brady Hubbard/Environmental Coordinator Place and Date Artesia. NM 02/07/2019 Signature Brady Hubbard 18004249300 Emergor1cy Tolophone Numb&r (soe w:1ming abovo) ~~ FOR RADIOACTIVE MATERIAL SHIPMENT ACCEPTABLE FOR PASSENGER AIR.CRAFT, THE SHIPMENT CONTAINS RADIOACTIVE MATERIAL INTENDED FOR USE IN OR !NC!OENT TO RESEARCH, MEDICAL DIAGNOSIS OR TREATMENT. AOR EUROPEAN TRANSPORT STATEMENT: CARRIAGE IN ACCORDANCE WITH 1.1.4.2.1 LOGOS #157295 11/i2 Page 32 of33 HFNA-000002970 EPA Inspection Report - Page 1421 of 1969 Use of this system constitutes your agreement to the service conditions in the current Fed Ex Service Guide, available on fedex.com. FedEx will not be responsible for any claim in excess of $100 per package, whether the result of !oss, damage, delav, non-delivery, rnisdelivery, or misinformation, unless you declare a higher vaiue, pay an additional charge, document your actual loss and fne a timely c!aim. Limitations found in the current FedEx Service Guide apply. Your right to recover from FedEx for any loss, induding intrinsic value of the package, loss of sales, income interest. profit, attorney's fees, costs, and other forms of damage whether direct, incidental, consequential, or special ts limited to the greater of $100 or the authorized declared va!ue. Recovery cannot exceed actual documented loss. Maximum for items of extraordinary value is $1,000, e.g. jewelry, precious metals, negotiable instruments and other items listed in our Service Guide. Written claims must be filed within strict time limits, see current FedEx Service Gulde. After printir:g this label. CONSIGNEE COPY PLEASE Pl.ACE lij FRONT OF POUCH 1, ~o!d lh~ printed page along the noriioma! !ine. 2 Place !abal m shfpplrrg pouch and affix it to your -shipme-nt ~t en f )> ~;;::,j: "" DJ 0..... U) w ~ 0 ~ co G) <.n U) ~ 0 ....... ~ t ~1 r ~_ I =C: 0 G) '"ti <;J ;;o 0 "Tl ~ "'Tl 2!:! m ~ 0 to ... -< co 0 X -n C: ~ m 00 ......, "' .............. m ;;o .C..D. z 0 )>O > 5 i:., c.o 0 ::i:: ::c: ~ G') -I !i; Page 33 of33 HFNA-000002971 EPA Inspection Report - Page 1422 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 March 13, 2019 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling (EOL) Dear Gabriela, Work Order: HS19030263 ALS Environmental received 4 sample(s) on Mar 06, 2019 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, ~:::~:::::::~=--z,... t-{;-;...-, Generated By: DAYNA.FISHER Corey Grandits Project Manager Right Solutions Right Partnu www.a!sg!obaLcom Pagel of25 HFNA-000002972 EPA Inspection Report - Page 1423 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030263 lab Samp ID HS 19030263-01 HS 19030263-02 HS 19030263-03 HS 19030263-04 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Matrix Liquid Liquid Liquid Liquid Date: 13-Mar-19 SAMPLE SUMMARY TagNo Collection Date 05-Mar-201910:13 05-Mar-2019 10:21 05-Mar-2019 09:39 05-Mar-2019 09:45 Date Received 06-Mar-2019 12:50 06-Mar-2019 12:50 06-Mar-2019 12:50 06-Mar-2019 12:50 Hold D D D D Page 2 of25 HFNA-000002973 EPA Inspection Report - Page 1424 of 1969 ALS Houston, US Dale: 13-Mar-19 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030263 CASE NARRATIVE Work Order Comments The analysis for Specific Gravity was subcontracted lo ALS Environmental in Holland, Ml. Final report attached. Page 3 of25 HFNA-00000297 4 EPA Inspection Report - Page 1425 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (API HC) 05-Mar-2019 10:13 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 13-Mar-19 ANALYTICAL REPORT Work0rder:HS19030263 Lab ID:HS19030263-01 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 13-Mar-2019 10:14 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of25 HFNA-000002975 EPA Inspection Report - Page 1426 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 05-Mar-2019 10:21 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 13-Mar-19 ANALYTICAL REPORT Work0rder:HS19030263 Lab ID:HS19030263-02 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 13-Mar-2019 10:14 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of25 HFNA-000002976 EPA Inspection Report - Page 1427 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 05-Mar-2019 09:39 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 13-Mar-19 ANALYTICAL REPORT Work0rder:HS19030263 Lab ID:HS19030263-03 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 13-Mar-2019 10:14 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of25 HFNA-000002977 EPA Inspection Report - Page 1428 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-6 (T-41) 05-Mar-2019 09:45 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 13-Mar-19 ANALYTICAL REPORT Work0rder:HS19030263 Lab ID:HS19030263-04 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 13-Mar-2019 10:14 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of25 HFNA-000002978 EPA Inspection Report - Page 1429 of 1969 ALS Houston, US Date: 13-Mar-19 Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030263 DATES REPORT Sample ID Client Samp ID Collection Date TCLP Date Prep Date Analysis Date DF Batch ID R334423 Test Name: SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY HS19030263-01 HS19030263-02 HS 19030263-03 HS 19030263-04 S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41 ) 05 Mar201910:13 05 Mar 2019 10:21 05 Mar 2019 09:39 05 Mar 2019 09:45 Matrix: Liquid 13 Mar201910:14 13 Mar201910:14 13 Mar201910:14 13 Mar201910:14 Page 8 of25 HFNA-000002979 EPA Inspection Report - Page 1430 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030263 Date: 13-Mar-19 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND 0 p R s u Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SOL TRRP Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL/SOL Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Page 9 of25 HFNA-000002980 EPA Inspection Report - Page 1431 of 1969 ALS Houston, US Agency Arkansas Texas North Dakota Illinois Louisiana Dept of Defense Kentucky Kansas Oklahoma North Carolina California Maryland Date: 13-Mar-19 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number 88-0356 T10470231-18-21 R193 2018-2019 004438 03087 ANAB L2231 123043 - 2018 E-10352 2018-2019 2018-156 624-2019 2919, 2018-2019 343, 2018-2019 Expire Date 27-Mar-2019 30-Apr-2019 30-Apr-2019 29-Jun-2019 30-Jun-2019 20-Dec-2021 30-Apr-2019 31-Jul-2019 31-Aug-2019 31-Dec-2019 30-Apr-2019 30-Jun-2019 Page 10 of25 HFNA-000002981 EPA Inspection Report - Page 1432 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030263 Lab Sarnp ID HS 19030263-01 HS 19030263-02 HS 19030263-03 HS 19030263-04 Client Sample ID S-1 (API HG) S-3 (API Water) S-5 (T-40) S-6 (T-41) Action Login Login Login Login Date 3/6/2019 2:52:28 PM 3/6/2019 2:52:28 PM 3/6/2019 2:52:28 PM 3/6/2019 2:52:28 PM Date: 13-Mar-19 SAMPLE TRACKING Person JRM JRM JRM JRM New Location Sub Sub Sub Sub Page 11 of25 HFNA-000002982 EPA Inspection Report - Page 1433 of 1969 ALS Houston, US Client Name: Work Order: Navajo Refining HS19030263 Date/Time Received: Received by: Date: 13-Mar-19 Sample Receipt Checklist 06-Mar-2019 12:50 JRM Checklist completed by: Jared R. Afakan 6-Mar-2019 -e,:-S,-ig_n_a,-tu-re-------...-D-a-t=e--,--- Reviewed by: Matrices: Carrier name: Corey Grandits eSignature ALS Courier 7-Mar-2019 Date Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? VOA/TX1005/TX1006 Solids in hermetically sealed vials? Chain of custody present? Chain of custody signed when relinquished and received? Samplers name present on COG? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler( s )/Kit( s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Login Notes: Client Contacted: Date Contacted: Contacted By: Regarding: Comments: Yes ~ Yes D Yes D Yes D Yes ~ Yes ~ Yes [] Yes ~ Yes ~ Yes ~ Yes @ Yes ~ Yes @ 0.4c/0.4c UC/C ==oam cooler 03/06/2019 14:55 Yes D Yes D Yes D No D No D No D No D No D No D No D No D No D No D No D No D No D No D No D No D Not Present D Not Present ~ Not Present ~ Not Present @ 1 Page(s) ll1R11 No VOA vials submitted ~ N/A ~ N/A ~ Person Contacted: Corrective Action: Page 12 of25 HFNA-000002983 EPA Inspection Report - Page 1434 of 1969 Chain of Custody Form D +I 513 733 5336 Cincinnati, OH Enuiranmental Page _1_ of ___1__J D Everett, WA +I 425 356 2600 D Fort Collins, CO +I 970 490 1511 .....> Cu$tomer lt1formatt6n.. . .. . . .. . . . . . . . . ... > Projec(tJl:lnie BWON Monthly Sampling (EOL) )i: Specific Gravity D +16163996070 fiollcmd, Ml 0 Houston, TX +I 2815305656 D Middletown, PA +I 717 944 5541 D + I 801 266 7700 Salt Lake City, UT D Spring City, PA +16109484903 D York, PA +J n 7 505 5280 >~oifrpa~{~arrie Navajo Refining Company LLC { S~rti:( R~pi>rt T(i Tyler Turner, Gabi Combs P.O. Box 159 . <: Fa~ {575) 746-5451 -:-:-: ::-:-:---:-~-:--.:-:-:-:-:- tturner.am@gmail.com :::::::.: e~M3:1l:)\d<:ires1>: Gabriela.Combs@hollyfrontier.com : Bili i:~ :on:i~~ny Holly Frontier Navajo Refining LLC 50~ East Main } 1fy1is;tat~IZ!i> Artesia, New Mexico 88210 << >< >:>: >P.h~n~ (575) 748-3311 ~ Navajo Refining Company HS19030263 B1NON Monthly Sampling (EOL) 1111111111111111111 11111111 II S-1 (API HC) S-3 (API Water) S-6 (T-41) 03/05/19 10:13AM Liquid 8 03/05/19 10:21AM liquid 8 03/05/19 9:39AM liquid 8 03/05/19 9:45AM liquid 8 1 X 1 X 1 X 1 X FedEx Received by: Required Turnaround Time: D SID 10 Wk Days Note: Any changes must be made in writing once samples and COC Form have been submitted to ALS Laboratory Group. Page 13 of 25 !kt Oother _ _ __ D 2 Wk Days D 24Hour Level JI: Standard QC Level Ill: Std QC+ Raw Data Level IV: SW846 CLP-Like TRRP-Checklist TRRP level IV Other: Copyright 2009 by ALS Laboratory Group HFNA-000002984 EPA Inspection Report - Page 1435 of 1969 SHIPPER'S DECLARATION FOR DANGEROUS GOODS Shipper NAVAJO REFINING COMPANY C/0 AQUA MICROBICS 501 E MAIN ARTESIA NM88210 US Consignee Corey Grandits ALS 10450 Stancliff Suite 210 HOUSTON TX 77099 US Two completed and signed copies of this Declaration must be handed to the operator (Provide at least three copies to airline.) AirWaybil! No. 709308590751 Page 1 of 1 Page(s) ~ : x Shipper's Reference Number (optional) 18 Compliant Express CAFE3211 WARNING TRANSPORT DETAILS This shipment is within the Umitations prescribed for: (delete non appllcable} Airport of Departure ARTESIA Failure to comply with all respects with the applicable Dangerous Goods Regulations may be in breach of the applicable law ,subject to legal penalties. FT y ~ Airport of Destination: HOUSTON ABSGRA Sh~ment ffi!: (delete non applicable} J NN-RA010 iivE NATURE AND QUANTITY OF DANGEROUS GOODS UN Number or ldentificatiOn Number, prdp r e eq r s u h ir i e p d pi i n n g fo n rm am a e ti , o C n. lass or Division {subsidiary risk), packing group (if required), and all other UN 3266, Corrosive liquid, basic, inorganic, n.o.s.(Sodium Hydroxide),8,1// UN 1268, Petroleum distillates, n.o.s.,3,111/i 0.04 U/366 . All Packed In One FIBREBOARD BOX Q =0.1 0.08 U/854 . -A--d-d-i-ti-o-n-a--l -H-a--n-d-l-in-g-~In-f-o-r-m--a-t-io--n----------------------------~-------------------~-------------------------------------------------- 24~Hour Emergency Response- CHEr..>ITREC 1~80D-424-9300, CCN 201319 I hereby declare that the contents of this consignment are fully and accurately described above by the proper shipping name, and are classified, packaged, marked and labelled/placarded, and are in all respects in proper condition for transport according to applicable International and National Governmental Regulations.! declare that all of the app!!c:able air transport requirements have been met. 18004249300 Emergency Tefophone Number IName/Title of Signatory Brady Hubbard/Enviror:menta! Coordinator Place and Dale Artesia, NM 03!05/2019 Signature (soe warning abow1) Brad?J;~ AJJ ,,,_ - 7 vJb{? FOR RADIOACTIVE MATERIAL SHIPMENT ACCEPrABLE FOR PASSENGER AJRCR.AFT, THE SH!PMENTCONTAINS RADIOACTIVE MATERIAL !NTENOED FOR USE IN OR !NC!OENTTO RESEARCH.MEDICAL DIAGNOSIS OR TREATMENT.AOR EUROPEAN TRANSPORTSTATFMENT: CARRIAGE IN ACCORDANCE WITH 1.1.4.2.1 LOGO~ U~',729'> 11/12 Page 14 of 25 HFNA-000002985 EPA Inspection Report - Page 1436 of 1969 Use of this system const\tutes your agreement to the service conditions in the current FedEx Service Guide, availabfe on fedex.Com. FedEx wil! not be responsible for any claim in excess of $100 per package, whether the result of loss, damage, deiay, non-delivery, misdelivery, or ffiisinformatlon, unless you declare a higher value, pay an addltional charge, document your actual !os.s and file a timely claim. Limitations found in the current FedEx Service Guide apply. Your rJght to recover from FedEx for any loss, Including intrinsic value of the package1 loss of sales, income !nteres.t, profit, attorney's fees, costs, and other forms of damage whether direct, !n~idental, consequential, or special is limited to the greater of $100 or the authorized declared value. Recovery cannot exceed actual documented loss. Maximum for items of extraordina1y value ls $1,000, e.g. jewelry, precious metals, negotiable instruments and other Items listed ln our Service Guide. Written claims must beflled within strict time ltmits, see current FedEx Service Guide. After printing this 'fubs!: CONSIGNEE COPY PLEASE PLACE IN FRONT OF POUCH 1. P"old the p1inleci page along the horiz.onta! l!ne 2. P!ace label !n shipping pouch and affix ii to your shlpmeni --. f~:;::i:i =C') "=...".. = )> CD (/) G) ~ ;:! C: "_' ..._..,, )>O :r.: ~ ;;o ~-< ." . -.j 0 (,I) w 0 CIO (II (,I) 0 -.j ()'I ..... .,, :::0 0 :::0 =i -< ~ m ;;CJ z :,,, G) 0 :::t: Q -I l i [ m ,,: Gt0 ) . '? :;E ":,', m 0 0 0 C, ~ )> ;;o ..... C ..:, C )> -< 0 c lJ'IO:ZO .... -- 25~~:c fl) ~~ S'.O~~ )>O ffi:t>fil ... t::O C 0 ro mw :20~ - ?C ::::j U'I fl) :::0 ~ z;fl:i~ = m C, m 8 =""" ~~ _N.. en -< mm <I)~ ~~ 0 -I G) c'.'.r @~p v,o = z 0 ::t> Oo . -I z <llO = '""' >< (") ~ z SH ~ -..I r C ~ -..I 'Ti ::::j 0 ~ ""' <D "'TI Cl) = ~(D ~ =~ ~if Jtt11lll)&l>S~11l1 551 C1 /46D3/1C4C >,-i ("))::-(1} ~ ;;u ~~~ m ~s; "'ii' ;::~[D m ~ ~~~ "TIO, ~~$ :::z Page 15 of 25 HFNA-000002986 EPA Inspection Report - Page 1437 of 1969 13-Mar-2019 Corey Grandits ALS Environmental 10450 Stancliff Rd Suite 210 Houston, TX 77099 Re: HS19030263 Dear Corey, Work Order: 1903326 ALS Environmental received 4 samples on 07-Mar-2019 10:00 AM for the analyses presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental - Holland and for only the analyses requested. Sample results are compliant with industry accepted practices and Quality Control results achieved laboratory specifications. Any exceptions are noted in the Case Narrative, or noted with qualifiers in the report or QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained from ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. The total number of pages in this report is 10. If you have any questions regarding this report, please feel free to contact me: ADDRESS: 3352 128th Avenue, Holland, Ml, USA PHONE: +1 (616) 399-6070 FAX: +1 (616) 399-6185 Sincerely, Electronically approved by: Chad Whelton Chad Whelton Project Manager Report of Laboratory Analysis Certificate No: MN 026-999-449 ~:>.c:Bf}H'J %Ul.t.t'J~t:3P% ::::::::. :.:: : .,.... Page 16 of25 HFNA-000002987 EPA Inspection Report - Page 1438 of 1969 ALS Group, USA Client: Project: Work Order: ALS Environmental HS 19030263 1903326 Lab Samp ID Client Sample ID 1903326-01 HS19030263-0l 1903326-02 HS l 9030263-02 1903326-03 HS19030263-03 1903326-04 HS l 9030263-04 Date: 13-Mar-19 Matrix Liquid Liquid Liquid Liquid Work Order Sample Summary Tag Number S-1 (API-HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Collection Date 3/5/2019 10:13 3/5/2019 10:13 3/5/2019 10:13 3/5/2019 10:13 Date Received 3/7/2019 10:00 3/7/2019 10:00 3/7/2019 10:00 3/7/2019 10:00 Hold D Page 17 of25 Sample Summary Pagel of l HFNA-000002988 EPA Inspection Report - Page 1439 of 1969 ALS Group, USA Client: Project: WorkOrder: ALS Environmental HS19030263 1903326 Date: 13-Mar-19 QUALIFIERS, ACRONYMS, UNITS Qualifier ** a B E H Hr J ND 0 p R s u X Description Value exceeds Regulatory Limit Estimated Value Analyte is non-accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time BOD/CBOD - Sample was reset outside Hold Time, value should be considered estimated. Analyte is present at an estimated concentration between the MDL and Report Limit Not Detected at the Reporting Limit Sample amount is > 4 times amount spiked Dual Column results percent difference > 40% RPD above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL Analyte was detected in the Method Blank between the MDL and Reporting Limit, sample results may exhibit background or reagent contamination at the observed level. Acronym Description DUP Method Duplicate LCS Laboratory Control Sample LCSD Laboratory Control Sample Duplicate LOD Limit of Detection (see MDL) LOQ Limit ofQuantitation (see PQL) MBLK Method Blank MDL Method Detection Limit MS Matrix Spike MSD Matrix Spike Duplicate PQL Practical Quantitation Limit RPD Relative Percent Difference TDL Target Detection Limit TNTC Too Numerous To Count A APHA Standard Methods D ASTM E EPA SW SW-846 Update III Units Reported none Description Page 18 of25 QFPage 1 of1 HFNA-000002989 EPA Inspection Report - Page 1440 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS19030263 HS19030263-0l 3/5/2019 10:13 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 13-A1ar-19 Result Qual Report Limit Work Order: 1903326 Lab ID: 1903326-01 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.00 none Analyst: RZM 3/12/2019 02:50 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 19 of25 Analytical Results Page l of 4 HFNA-000002990 EPA Inspection Report - Page 1441 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS19030263 HS19030263-02 3/5/2019 10:13 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 13-A1ar-19 Result Qual Report Limit Work Order: 1903326 Lab ID: 1903326-02 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.01 none Analyst: RZM 3/12/2019 02:50 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 20 of25 Analytical Results Page 2 of 4 HFNA-000002991 EPA Inspection Report - Page 1442 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS19030263 HS19030263-03 3/5/2019 10:13 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 13-A1ar-19 Result Qual Report Limit Work Order: 1903326 Lab ID: 1903326-03 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.15 none Analyst: RZM 3/12/2019 02:50 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 21 of25 Analytical Results Page 3 of 4 HFNA-000002992 EPA Inspection Report - Page 1443 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS19030263 HS19030263-04 3/5/2019 10:13 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 13-A1ar-19 Result Qual Report Limit Work Order: 1903326 Lab ID: 1903326-04 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.13 none Analyst: RZM 3/12/2019 02:50 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 22 of25 Analytical Results Page 4 of 4 HFNA-000002993 EPA Inspection Report - Page 1444 of 1969 ALS Group, USA Client: ALS Environmental Work Order: 1903326 Project: HS19030263 Date: 13-Mar-19 QC BATCH REPORT Batch ID: R256327 Instrument ID WETCHEM Method: D5057-90 DUP Sample ID: 1903326-02A DUP Client ID: HS19030263-02 Run ID: WETCHEM_190312K Units: none SeqNo: 5555297 Analysis Date: 3/12/2019 02:50 PM Prep Date: OF: 1 Analyte Result SPK Ref PQL SPK Val Value %REC Control Limit RPO Ref Value %RPO RPO Limit Qual Specific Gravity 1.011 0 0 0 0 0-0 1.014 0.346 20 The following samples were analyzed in this batch: 1903326-01A 1903326-04A 1903326-02A 1903326-03A Note: See Qualifiers Page for a list of Qualifiers aud their explauation. Page 23 of25 QC Page: 1 of 1 HFNA-000002994 EPA Inspection Report - Page 1445 of 1969 10450 Stancliff Rd, Ste 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 www.alsglobal.com Subcontract Chain of Custody COC ID: 10878 SUBCONTRACT TO: ALS Group USA, Corp. 3352 - 128th Ave Holland, MI 494249263 CUSTOMER INFORMATION: Company: ALS Houston Contact: Address: Corey Grandits 10450 Stancliff Rd, Ste 210 Phone: +1 281 530 5656 Email: Alternate Contact: Email: Corey.Grandits@alsglobal.com Jumoke M. Lawal jumoke.lawal@alsglobal.com Phone: +1 616 399 6070 INVOICE INFORMATION: Company: ALS Houston Contact:: Address: Accounts Payable 10450 Stancliff Rd, Ste 210 Phone: +1 281 530 5656 Reference: TSR: HS19030263 Houston House Acct LAB SAMPLE ID CLIENT SAMPLE ID ANALYSIS REQUESTED 1. HS19030263-01 S-1 (API HC) Sub Specific Gravity to ALS Holland 2. HS19030263-02 S-3 {API Water) Sub Specific Gravity to ALS Hofland 3. HS19030263-03 S-5 (T-40) Sub Specific Gravity to ALS Holland 4. HS19030263-04 S-6 (T-41) Sub Specific Gravity to ALS Holland MATRIX Liquid liquid liquid Liquid COLLECT DATE DUE DATE 05 Mar 2019 10:13 13 Mar 2019 05 Mar 2019 10:13 13 Mar 2019 05 Mar 2019 10:13 13 Mar 2019 05 Mar 2019 10:13 13 Mar 2019 Comments: Please analyze for the analysis listed above. Send report to the emails shown above. QC Level: STD (Laboratory Standard QC: method blank and LCS required) Relinquished By: Received By: Cooler ID(s): Date/Time: Date/Time: Temperature{s): (50 Page 24 of25 HFNA-000002995 EPA Inspection Report - Page 1446 of 1969 ALS Group, USA Client Name: Work Order: ALS - HOUSTON 1903326 Sample Receipt Checklist Date/Time Received: Received by: 07-Mar-19 10:00 Checklist completed by _LlULK</ '-c;',e'-""" 07-Mar-19 -------------~----- eSignature Date Matrices: Carrier name: Liquid FedEx Reviewed by: eSignature Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Yes [i,] Yes [i,] Yes No Not Present D No Not Present D No Not Present [i,] Chain of custody present? Yes [i,] No Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Yes [i,] Yes [i,] Yes [i,] Yes [i,] No D No D No D No Sufficient sample volume for indicated test? Yes [i,] No All samples received within holding time? Yes [i,] No Container/Temp Blank temperature in compliance? Yes [i,] No Sample(s) received on ice? Temperature(s)/Thermometer(s): Yes [i,] No Cooler(s)/Kit(s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? r3/7/2019 11 :07:23 AM Yes No VOA vials submitted [i,] Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Yes Yes D No N/A No D N/A Login Notes: 07-Mar-19 Date Client Contacted: Contacted By: Comments: Date Contacted: Regarding: Person Contacted: Co rrectiveActio n: ~agc=of'.15~ SRC Page 1 of 1 HFNA-000002996 EPA Inspection Report - Page 1447 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 March 14, 2019 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling (EOL) Dear Gabriela, Work Order: HS19030352 ALS Environmental received 9 sample(s) on Mar 06, 2019 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, ~:::~:::::::~=--z,... t-{;-;...-, Generated By: DAYNA.FISHER Corey Grandits Project Manager Right Solutions Right Partnu www.a!sg!obaLcom Pagel of28 HFNA-000002997 EPA Inspection Report - Page 1448 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030352 lab Samp ID HS19030352-01 HS19030352-02 HS19030352-03 HS19030352-04 HS19030352-05 HS19030352-06 HS19030352-07 HS19030352-08 HS19030352-09 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Matrix Liquid Liquid Liquid Liquid Water Water Water Liquid Water Date: 14-Mar-19 SAMPLE SUMMARY TagNo Collection Date 05-Mar-201910:13 05-Mar-2019 10:21 05-Mar-2019 09:39 05-Mar-2019 09:45 05-Mar-201910:16 05-Mar-2019 10:39 05-Mar-2019 10:39 05-Mar-2019 00:00 C&G 101618-84 05-Mar-2019 00:00 Date Received 06-Mar-2019 12:50 06-Mar-2019 12:50 06-Mar-2019 12:50 06-Mar-2019 12:50 06-Mar-2019 12:50 06-Mar-2019 12:50 06-Mar-2019 12:50 06-Mar-2019 12:50 06-Mar-2019 12:50 Hold D D D D D D D D D Page 2 of28 HFNA-000002998 EPA Inspection Report - Page 1449 of 1969 ALS Houston, US Dale: 14-Mar-19 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030352 GCMS Volatiles by Method SW8260 Batch ID: R334415 Sample ID: HS19030318-01 MS CASE NARRATIVE MS and MSD are for an unrelated sample Sample ID: S-5 (T-40) (HS19030352-03), S-6 (T-41) (HS19030352-04) Lowest practical dilution for HS19030252-03, 04 due lo sample matrix. Sample ID: S-6 (T-41) (HS19030352-04) Surrogate failure due to sample matrix. Batch ID: R334531 The test results meet requirements of the current NELAP standards, state requirements or programs where applicable. Batch ID: R334329 The test results meet requirements of the current NELAP standards, state requirements or programs where applicable. Batch ID: R334272 The test results meet requirements of the current NELAP standards, state requirements or programs where applicable. Page 3 of28 HFNA-000002999 EPA Inspection Report - Page 1450 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (API HC) 05-Mar-2019 10:13 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 1.9 107 101 91.3 104 Method:SW8260 0.025 REPORT LIMIT 0.25 70-126 70-130 70-130 70-130 Date: 14-Mar-19 ANALYTICAL REPORT Work0rder:HS19030352 Lab ID:HS19030352-01 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 12-Mar-2019 22:43 12-Mar-2019 22:43 12-Mar-2019 22:43 12-Mar-2019 22:43 12-Mar-2019 22:43 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of28 HFNA-000003000 EPA Inspection Report - Page 1451 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 05-Mar-2019 10:21 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.78 107 99.9 103 101 Method:SW8260 0.030 REPORT LIMIT 0.25 70-126 82-124 77-123 82-127 Date: 14-Mar-19 ANALYTICAL REPORT Work0rder:HS19030352 Lab ID:HS19030352-02 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: PC 13-Mar-2019 20:57 13-Mar-2019 20:57 13-Mar-2019 20:57 13-Mar-2019 20:57 13-Mar-2019 20:57 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of28 HFNA-000003001 EPA Inspection Report - Page 1452 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 05-Mar-2019 09:39 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.024 107 104 75.0 101 Method:SW8260 0.024 REPORT LIMIT 0.24 70-126 70-130 70-130 70-130 Date: 14-Mar-19 ANALYTICAL REPORT Work0rder:HS19030352 Lab ID:HS19030352-03 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 12-Mar-2019 23:08 12-Mar-2019 23:08 12-Mar-2019 23:08 12-Mar-2019 23:08 12-Mar-2019 23:08 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of28 HFNA-000003002 EPA Inspection Report - Page 1453 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-6 (T-41) 05-Mar-2019 09:45 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.29 105 107 68.2 100 Method:SW8260 0.024 s REPORT LIMIT 0.24 70-126 70-130 70-130 70-130 Date: 14-Mar-19 ANALYTICAL REPORT Work0rder:HS19030352 Lab ID:HS19030352-04 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 12-Mar-2019 23:33 12-Mar-2019 23:33 12-Mar-2019 23:33 12-Mar-2019 23:33 12-Mar-2019 23:33 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of28 HFNA-000003003 EPA Inspection Report - Page 1454 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Field Blank 05-Mar-2019 10:16 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 111 99.0 103 102 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 14-Mar-19 ANALYTICAL REPORT Work0rder:HS19030352 Lab ID:HS19030352-05 Matrix:Water UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 11-Mar-2019 15:42 11-Mar-2019 15:42 11-Mar-2019 15:42 11-Mar-2019 15:42 11-Mar-2019 15:42 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 8 of28 HFNA-000003004 EPA Inspection Report - Page 1455 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 1 05-Mar-2019 10:39 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 108 97.9 98.3 101 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 14-Mar-19 ANALYTICAL REPORT Work0rder:HS19030352 Lab ID:HS19030352-06 Matrix:Water UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 11-Mar-2019 14:02 11-Mar-2019 14:02 11-Mar-2019 14:02 11-Mar-2019 14:02 11-Mar-2019 14:02 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 9 of28 HFNA-000003005 EPA Inspection Report - Page 1456 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 2 05-Mar-2019 10:39 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 112 98.5 102 101 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 14-Mar-19 ANALYTICAL REPORT Work0rder:HS19030352 Lab ID:HS19030352-07 Matrix:Water UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 11-Mar-2019 14:27 11-Mar-2019 14:27 11-Mar-2019 14:27 11-Mar-2019 14:27 11-Mar-2019 14:27 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 10 of28 HFNA-000003006 EPA Inspection Report - Page 1457 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Duplicate 05-Mar-2019 00:00 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.80 106 99.3 100.0 99.3 Method:SW8260 0.030 REPORT LIMIT 0.25 70-126 82-124 77-123 82-127 Date: 14-Mar-19 ANALYTICAL REPORT Work0rder:HS19030352 Lab ID:HS19030352-08 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: PC 13-Mar-2019 21 :22 13-Mar-2019 21:22 13-Mar-2019 21:22 13-Mar-2019 21:22 13-Mar-2019 21:22 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 11 of28 HFNA-000003007 EPA Inspection Report - Page 1458 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Trip Blank 05-Mar-2019 00:00 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 80.7 99.5 82.3 108 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 14-Mar-19 ANALYTICAL REPORT Work0rder:HS19030352 Lab ID:HS19030352-09 Matrix:Water UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 08-Mar-2019 18:05 08-Mar-2019 18:05 08-Mar-2019 18:05 08-Mar-2019 18:05 08-Mar-2019 18:05 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 12 of28 HFNA-000003008 EPA Inspection Report - Page 1459 of 1969 ALS Houston, US Client: Navajo Refining Company Project: BWON Monthly Sampling (EOL) WorkOrder: HS19030352 Batch ID: 2951 SamplD HS19030352-01 HS19030352-03 HS19030352-04 Method: VOLATl LES BY SW8260C Container Sample Wt/Vol 4.964 (g) 5.223 (g) 5.099 (g) Final Volume 5 (ml) 5 (ml) 5 (ml) Weight Factor 1.01 0.96 0.98 Container Type Bulk (5030B) Bulk (5030B) Bulk (5030B) Date: 14-Mar-19 WEIGHT LOG Page 13 of28 HFNA-000003009 EPA Inspection Report - Page 1460 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030352 Sample ID Client Samp ID Collection Date TCLP Date Batch ID R334272 Test Name : VOLATILES - SW8260C HS19030352-09 Trip Blank 05 Mar 2019 00:00 Batch ID R334329 Test Name: VOLATILES- SW8260C HS19030352-05 HS19030352-06 HS19030352-07 Field Blank EQ Blank Port 1 EQ Blank Port 2 05 Mar201910:16 05 Mar 2019 10:39 05 Mar 2019 10:39 Batch ID R334415 Test Name : VOLATILES BY SW8260C HS19030352-01 HS19030352-03 HS19030352-04 S-1 (API HC) S-5 (T-40) S-6 (T-41) 05 Mar201910:13 05 Mar 2019 09:39 05 Mar 2019 09:45 Batch ID R334531 Test Name ; VOLATILES - SW8260C HS19030352-02 HS19030352-08 S-3 (API Water) Duplicate 05 Mar 2019 10:21 05 Mar 2019 00:00 Date: 14-Mar-19 DATES REPORT Prep Date Analysis Date DF Matrix: water 08 Mar 2019 18:05 Matrix: water 11 Mar201915:42 11 Mar201914:02 11 Mar201914:27 Matrix: Liquid 12 Mar 2019 22:43 50 12 Mar 2019 23:08 50 12 Mar 2019 23:33 50 Matrix; Liquid 13 Mar 2019 20:57 50 13 Mar 2019 21 :22 50 Page 14 of28 HFNA-000003010 EPA Inspection Report - Page 1461 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030352 Date: 14-Mar-19 QC BATCH REPORT Batch ID: R334272 Instrument: VOA6 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-190308 Units: ug/L Analysis Date: 08-Mar-2019 12:05 Run ID: VOA6_334272 SeqNo: 4984668 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 41.37 0 50 50.23 0 50 40.97 0 50 53.9 0 50 0 82.7 70 - 130 0 100 82 - 115 0 81.9 73 - 126 0 108 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-190308 Units: ug/L Analysis Date: 08-Mar-2019 11:17 Run ID: VOA6_334272 SeqNo: 4984667 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 20.74 5.0 20 51.89 0 50 53.23 0 50 51.27 0 50 47.66 0 50 0 104 74 - 120 0 104 70 - 130 0 106 82 - 115 0 103 73 - 126 0 95.3 81 - 120 MS Client ID: Analyte Sample ID: HS19030163-01 MS Units: ug/L Analysis Date: 08-Mar-2019 16:29 Run ID: VOA6_334272 SeqNo: 4984671 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 18.1 5.0 20 42.6 0 50 50.07 0 50 42.23 0 50 54.26 0 50 0 90.5 70 - 127 0 85.2 70 - 126 0 100 82 - 124 0 84.5 77 - 123 0 109 82 - 127 Page 15 of28 HFNA-000003011 EPA Inspection Report - Page 1462 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030352 Date: 14-Mar-19 QC BATCH REPORT Batch ID: R334272 Instrument: VOA6 Method; SW8260 MSD Client ID: Analyte Sample ID: HS19030163-01 MSD Units: ug/L Analysis Date: 08-Mar-2019 16:53 Run ID: VOA6_334272 SeqNo: 4984672 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene 19.25 5.0 20 0 96.2 70 - 127 18.1 6.17 20 Surr: 1,2-0ichloroethane-d4 41.92 0 50 0 83.8 70 - 126 42.6 1.62 20 Surr: 4-Bromofluorobenzene 50.79 0 50 0 102 82 - 124 50.07 1.42 20 Surr: Dibromofluoromethane 41.48 0 50 0 83.0 77 - 123 42.23 1.8 20 Surr: Toluene-dB 52.71 0 50 0 105 82 - 127 54.26 2.9 20 The following samples were analyzed in this batch: ~f_s_19_o_3o_3_s_2-_0_9 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _~ Page 16 of28 HFNA-000003012 EPA Inspection Report - Page 1463 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030352 Date: 14-Mar-19 QC BATCH REPORT Batch ID: R334329 Instrument: VOA9 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-190311 Units: ug/L Analysis Date: 11-Mar-2019 12:23 Run ID: VOA9_334329 SeqNo: 4985860 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 59.2 0 50 49.58 0 50 52.99 0 50 51.02 0 50 0 118 70 - 130 0 99.2 82 - 115 0 106 73 - 126 0 102 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-190311 Units: ug/L Analysis Date: 11-Mar-2019 11:34 Run ID: VOA9_334329 SeqNo: 4985859 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 20.84 5.0 20 57.22 0 50 51.46 0 50 53.8 0 50 51.15 0 50 0 104 74 - 120 0 114 70 - 130 0 103 82 - 115 0 108 73 - 126 0 102 81 - 120 MS Client ID: Analyte Sample ID: HS19030101-41MS Units: ug/L Analysis Date: 11-Mar-2019 14:52 Run ID: VOA9_334329 SeqNo: 4985864 Prep Date: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 1219 2755 2540 2652 2537 250 1000 107.4 111 70 - 127 0 2500 0 110 70 - 126 0 2500 0 102 82 - 124 0 2500 0 106 77 - 123 0 2500 0 101 82 - 127 Page 17 of28 HFNA-000003013 EPA Inspection Report - Page 1464 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030352 Date: 14-Mar-19 QC BATCH REPORT Batch ID: R334329 Instrument: VOA9 Method; SW8260 MSD Client ID: Analyte Sample ID: HS19030101-41MSD Units: ug/L Analysis Date: 11-Mar-2019 15:17 Run ID: VOA9_334329 SeqNo: 4985865 Prep Date: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene 1176 250 Surr: 1,2-0ichloroethane-d4 2738 0 Surr: 4-Bromofluorobenzene 2536 0 Surr: Dibromofluoromethane 2623 0 rs Surr: Toluene-dB 2530 0 The following samples were analyzed in this batch: 19030352-05 1000 2500 2500 2500 2500 107.4 0 0 0 0 107 70 - 127 110 70 - 126 101 82 - 124 105 77 - 123 101 82 - 127 HS 19030352-06 HS19030352-07 1219 2755 2540 2652 2537 3.56 20 0.629 20 0.189 20 1.12 20 0.286 20 Page 18 of28 HFNA-000003014 EPA Inspection Report - Page 1465 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030352 Date: 14-Mar-19 QC BATCH REPORT Batch ID: R334415 Instrument: VOA8 Method; SW8260 MBLK Client ID: Analyte Sample ID: MBLKW1-031219 Units: ug/Kg Analysis Date: 12-Mar-2019 16:31 Run ID: VOA8_334415 SeqNo: 4987955 PrepDate: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 25 2434 2413 2177 2422 250 0 2500 0 2500 0 2500 0 2500 0 97.3 76 - 125 0 96.5 80 - 120 0 87.1 80 - 119 0 96.9 81 - 118 LCS Client ID: Analyte Sample ID: VLCSW1-031219 Units: ug/Kg Analysis Date: 12-Mar-2019 15:41 Run ID: VOA8_334415 SeqNo: 4987954 PrepDate: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 41.54 5.0 50 48.87 0 50 50.55 0 50 50.83 0 50 49.27 0 50 0 83.1 75 - 124 0 97.7 76 - 125 0 101 80 - 120 0 102 80 - 119 0 98.5 81 - 118 MS Client ID: Analyte Sample ID: HS19030318-01 MS Units: ug/Kg Analysis Date: 12-Mar-2019 18:34 Run ID: VOA8_334415 SeqNo: 4987960 Prep Date: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene 1335 250 2475 0 53.9 70 - 130 s Surr: 1,2-0ichloroethane-d4 556.8 0 2475 0 22.5 70 - 126 s Surr: 4-Bromofluorobenzene 1511 0 2475 0 61.1 70 - 130 s Surr: Dibromofluoromethane 774.3 0 2475 0 31.3 70 - 130 s Surr: Toluene-dB 2829 0 2475 0 114 70 - 130 Page 19 of28 HFNA-000003015 EPA Inspection Report - Page 1466 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030352 Date: 14-Mar-19 QC BATCH REPORT Batch ID: R334415 Instrument: VOA8 Method; SW8260 MSD Client ID: Analyte Sample ID: HS19030318-01MSD Units: ug/Kg Analysis Date: 12-Mar-2019 18:57 Run ID: VOA8_334415 SeqNo: 4987961 PrepDate: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane 1069 462 1170 718.4 250 2475 0 2475 0 2475 0 2475 0 43.2 70 -130 0 18.7 70- 126 0 47.3 70 - 130 0 29.0 70 - 130 1335 22.1 30 s 556.8 18.6 30 s 1511 25.5 30 s 774.3 7.49 30 s Surr: Toluene-dB 2507 0 2475 0 101 70 - 130 2829 12.1 30 The following samples were analyzed in this batch: ~F_s_19_o_3o_3_s_2-_0_1_ _ _H_s_19_o_3o_3_s_2-_0_ 3 _ _ _H_s_19_o_3o_3_s_2-_0_ 4 _ _ _ _ _ _ _ _ _ _ _~ Page 20 of28 HFNA-000003016 EPA Inspection Report - Page 1467 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030352 Date: 14-Mar-19 QC BATCH REPORT Batch ID: R334531 Instrument: VOA9 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-190313 Units: ug/L Analysis Date: 13-Mar-2019 12:21 Run ID: VOA9_334531 SeqNo: 4990302 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 58.75 0 50 49.45 0 50 53.28 0 50 50.93 0 50 0 117 70 - 130 0 98.9 82 - 115 0 107 73 - 126 0 102 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-190313 Units: ug/L Analysis Date: 13-Mar-2019 11:31 Run ID: VOA9_334531 SeqNo: 4990301 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 20.78 5.0 20 57.91 0 50 51.25 0 50 54.71 0 50 50.51 0 50 0 104 74 - 120 0 116 70 - 130 0 103 82 - 115 0 109 73 - 126 0 101 81 - 120 MS Client ID: Analyte Sample ID: HS19030561-01MS Units: ug/L Analysis Date: 13-Mar-2019 16:49 Run ID: VOA9_334531 SeqNo: 4990308 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 21.01 5.0 20 52.58 0 50 51.89 0 50 52.88 0 50 50.91 0 50 0 105 70 - 127 0 105 70 - 126 0 104 82 - 124 0 106 77 - 123 0 102 82 - 127 Page 21 of28 HFNA-000003017 EPA Inspection Report - Page 1468 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030352 Date: 14-Mar-19 QC BATCH REPORT Batch ID: R334531 Instrument: VOA9 Method; SW8260 MSD Client ID: Analyte Sample ID: HS19030561-01MSD Units: ug/L Analysis Date: 13-Mar-2019 17:14 Run ID: VOA9_334531 SeqNo: 4990309 PrepDate: OF: 1 Result PQL SPK Val SPK Ref Value %REC Control Limit RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 20.33 5.0 20 51.08 0 50 50.5 0 50 52.21 0 50 50.33 0 50 0 102 70 -127 0 102 70 - 126 0 101 82 - 124 0 104 77 - 123 0 101 82 - 127 21.01 52.58 51.89 52.88 50.91 3.27 20 2.91 20 2.72 20 1.28 20 1.15 20 The following samples were analyzed in this batch: ~F_s_19_o_3o_3_s_2-_0_2 _ _ _H_s_19_o_3o_3_s_2-_o_s- - - - - - - - - - - - - - - - - - - ~ Page 22 of28 HFNA-000003018 EPA Inspection Report - Page 1469 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030352 Date: 14-Mar-19 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND O P R S U Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SOL TRRP Unit Reported mg/Kg mg/L Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL/SOL Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Description Milligrams per Kilogram Milligrams per Liter Page 23 of28 HFNA-000003019 EPA Inspection Report - Page 1470 of 1969 ALS Houston, US Agency Arkansas Texas North Dakota Illinois Louisiana Dept of Defense Kentucky Kansas Oklahoma North Carolina California Maryland Date: 14-Mar-19 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number 88-0356 T10470231-18-21 R193 2018-2019 004438 03087 ANAB L2231 123043 - 2018 E-10352 2018-2019 2018-156 624-2019 2919, 2018-2019 343, 2018-2019 Expire Date 27-Mar-2019 30-Apr-2019 30-Apr-2019 29-Jun-2019 30-Jun-2019 20-Dec-2021 30-Apr-2019 31-Jul-2019 31-Aug-2019 31-Dec-2019 30-Apr-2019 30-Jun-2019 Page 24 of28 HFNA-000003020 EPA Inspection Report - Page 1471 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19030352 Lab Sarnp ID HS19030352-01 HS19030352-02 HS19030352-03 HS19030352-04 HS19030352-05 HS19030352-06 HS19030352-07 HS19030352-08 HS19030352-09 Client Sample ID S-1 (API HG) S-3 (API Water) S-5 (T-40) S-6 (T-41) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Action Login Login Login Login Login Login Login Login Login Date 3/7/2019 6:04:48 PM 3/7/2019 6:04:48 PM 3/7/2019 6:04:48 PM 3/7/2019 6:04:48 PM 3/7/2019 6:04:48 PM 3/7/2019 6:04:48 PM 3/7/2019 6:04:48 PM 3/7/2019 6:04:48 PM 3/7/2019 6:04:48 PM Date: 14-Mar-19 SAMPLE TRACKING Person JRM JRM JRM JRM JRM JRM JRM JRM JRM New Location VOA243 VOA243 VOA243 VOA243 VOA243 VOA243 VOA243 VOA243 VOA243 Page 25 of28 HFNA-000003021 EPA Inspection Report - Page 1472 of 1969 ALS Houston, US Client Name: Work Order: Navajo Refining HS19030352 Date/Time Received: Received by: Date: 14-Mar-19 Sample Receipt Checklist 06-Mar-2019 12:50 JRM Checklist completed by: Jared R. Afakan 7-Mar-2019 -e,:-S,-ig_n_a,-tu-re-------...-D-a-t=e--,--- Reviewed by: Matrices: Water. Product Carrier name: Corey Grandits eSignature FedEx Priority Overnight 8-Mar-2019 Date Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? VOA/TX1005/TX1006 Solids in hermetically sealed vials? Chain of custody present? Chain of custody signed when relinquished and received? Samplers name present on COG? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler( s )/Kit( s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Login Notes: Client Contacted: Date Contacted: Contacted By: Regarding: Comments: Yes ~ Yes D Yes D Yes D Yes ~ Yes ~ Yes [] Yes ~ Yes ~ Yes ~ Yes @ Yes ~ Yes @ 0.4c/0.4c UC/C ==oam 03/07/2019 18:20 Yes~ Yes~ Yes D No D No D No D No D No D No D No D No D No D No D No D No D No D No D No D No ~ Not Present D Not Present ~ Not Present ~ Not Present @ 1 Page(s) COC 1Ds:N/A ll1R11 D No VOA vials submitted N/A D N/A D Person Contacted: Corrective Action: Page 26 of28 HFNA-000003022 EPA Inspection Report - Page 1473 of 1969 Enuironmental customer hiformaft()if ...... Chain of Custody Form Page _1_ of _L__ D +15137335336 Cincinnati, OH D Everett, WA +I 425 356 2600 D Fort Collins, CO +19704901511 D +16163996070 Holland, Ml El Houston, TX +I 281 530 5656 D Middletown, PA +I 717 944 5541 D +I 801 266 7700 Salt Lake City, UT D Spring City, PA +I 610 948 4903 D York, PA +I 717 505 5280 .. .. .-.-.. .. ... .. .... >. ~oinpar.i{Na~e Navajo Refining Company LLC >: $~ii~ R~~ort:f:~ Tyler Turner, Gabi Combs P.O. Box 159, :.:9 .: Trip Blank /10: Temperature Blank :cf :H: 03/05/19 03/05/19 03/05/19 03/05/19 03/05/19 03/05/19 03/05/19 03/05/19 03/05/19 10:13AM 10:21AM 9:39AM 9:45AM 10:16AM 10:39AM 10:39AM XXX XXX FedEx Received by: , ......... Pres: : i i3ouies< liquid 8 Liquid 8, l 1 X 1 X Liquid 8 1 X Liquid 8 1 X Liquid 8,1 1 X Liquid B,1 1 X Liquid 8,1 1 X Liquid 8,1 1 X Liquid 8,1 2 X Liquid l Required Turnaround Time: D STD 10 Wk Days , - - - - -.. HS19030352 Navajo Refining Company BWON Monthly Sampling (EOL) I1111111111111111 H 111111 00ther _ _ __ D 2 Wk Days D 24 Hour Received by (Laboratory): Note: Any changes must be made in writing once samples and COC Form have been submitted to ALS Laboratory Group. Page 27 of28 Cyo,o Level JI: Standard QC Level III: Std QC + Raw Data Level IV: SW846 CLP-Like TRRP-Checklist TRRP Level IV Other: Copyright 2009 by ALS laboratory Group HFNA-000003023 EPA Inspection Report - Page 1474 of 1969 Use of this system constitutes your agreement to the service conditions in the current FedEx Service Guide, available on fedex.com. FedEx will not be responsible for any claim m excess of $100 per package, whether the result of loss, damage, delay, non--deHvery, misde!ivery, or rTI!sinformation, unless you declare a higher value, pay an additional charge, document your actual loss and file a timely claim. Umitations found in the current FedEx Service Guide app!y. Your right to recover from FedEx for any loss, including intrinsic value of the package, loss of sales, income interest, profit, attorney's fees, costs, and other forms of damage whether direct, incidental, consequential, or special is limited to the greater of $100 or the authorized declared va[ue. Recovery cannot exceed actual documented loss. Maximum for ltems of extraordinary value ts $1,000, e.g. jewelry, precious metals, negotiable instruments and other items listed in our Service Guide. Written claims must be filed within strict time limits, see current Ped Ex Service Guide. After printing this label. CONSIGNEE COPY PLEASE PLACE IN FRONT OF POUCH 1. Fold the pdnted page along the horizontal line. 2. Place- labe.l in shipping po~ch and affix il io your shipment Page 28 of28 HFNA-000003024 EPA Inspection Report - Page 1475 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 February 14, 2019 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling (EOL) Dear Gabriela, Work Order: HS19020432 ALS Environmental received 4 sample(s) on Feb 08, 2019 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, ~:::~:::::::~=--z,... t-{;-;...-, Generated By: JUMOKE.LAWAL Corey Grandits Project Manager Right Solutions Right Partnu www.a!sg!obaLcom Pagel of24 HFNA-000003025 EPA Inspection Report - Page 1476 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020432 lab Samp ID HS19020432-01 HS19020432-02 HS19020432-03 HS19020432-04 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Matrix Liquid Liquid Liquid Liquid Date: 14-Feb-19 SAMPLE SUMMARY TagNo Collection Date 07-Feb-2019 09:08 07-Feb-2019 09:25 07-Feb-2019 08:46 07-Feb-2019 08:51 Date Received 08-Feb-2019 09:00 08-Feb-2019 09:00 08-Feb-2019 09:00 08-Feb-2019 09:00 Hold D D D D Page 2 of24 HFNA-000003026 EPA Inspection Report - Page 1477 of 1969 ALS Houston, US Date: 14-Feb-19 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020432 CASE NARRATIVE Work Order Comments The analyses for Specific Gravity was subcontracted to ALS Environmental in Holland, Ml. Final report attached. Page 3 of24 HFNA-000003027 EPA Inspection Report - Page 1478 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (API HC) 07-Feb-2019 09:08 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Feb-19 ANALYTICAL REPORT Work0rder:HS19020432 Lab ID:HS19020432-01 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Feb-2019 09:30 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of24 HFNA-000003028 EPA Inspection Report - Page 1479 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 07-Feb-2019 09:25 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Feb-19 ANALYTICAL REPORT Work0rder:HS19020432 Lab ID:HS19020432-02 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Feb-2019 09:30 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of24 HFNA-000003029 EPA Inspection Report - Page 1480 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 07-Feb-2019 08:46 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Feb-19 ANALYTICAL REPORT Work0rder:HS19020432 Lab ID:HS19020432-03 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Feb-2019 09:30 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of24 HFNA-000003030 EPA Inspection Report - Page 1481 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-6 (T-41) 07-Feb-2019 08:51 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Feb-19 ANALYTICAL REPORT Work0rder:HS19020432 Lab ID:HS19020432-04 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Feb-2019 09:30 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of24 HFNA-000003031 EPA Inspection Report - Page 1482 of 1969 ALS Houston, US Date: 14-Feb-19 Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020432 DATES REPORT Sample ID Client Samp ID Collection Date TCLP Date Prep Date Analysis Date DF Batch ID R332838 Test Name: SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY HS19020432-01 HS19020432-02 HS19020432-03 HS19020432-04 S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) 07 Feb 2019 09:08 07 Feb 2019 09:25 07 Feb 2019 08:46 07 Feb 2019 08:51 Matrix: Liquid 14 Feb 2019 09:30 14 Feb 2019 09:30 14 Feb 2019 09:30 14 Feb 2019 09:30 Page 8 of24 HFNA-000003032 EPA Inspection Report - Page 1483 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020432 Date: 14-Feb-19 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND 0 p R s u Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SOL TRRP Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL/SOL Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Page 9 of24 HFNA-000003033 EPA Inspection Report - Page 1484 of 1969 ALS Houston, US Agency Arkansas Texas North Dakota Illinois Louisiana Dept of Defense Kentucky Kansas Oklahoma North Carolina California Maryland Date: 14-Feb-19 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number 88-0356 T10470231-18-21 R193 2018-2019 004438 03087 ANAB L2231 123043 - 2018 E-10352 2018-2019 2018-156 624-2019 2919, 2018-2019 343, 2018-2019 Expire Date 27-Mar-2019 30-Apr-2019 30-Apr-2019 29-Jun-2019 30-Jun-2019 20-Dec-2021 30-Apr-2019 31-Jul-2019 31-Aug-2019 31-Dec-2019 30-Apr-2019 30-Jun-2019 Page 10 of24 HFNA-000003034 EPA Inspection Report - Page 1485 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19020432 Lab Sarnp ID HS19020432-01 HS19020432-02 HS19020432-03 HS19020432-04 Client Sample ID S-1 (API HG) S-3 (API Water) S-5 (T-40) S-6 (T-41) Action Login Login Login Login Date 2/8/2019 3:03:32 PM 2/8/2019 3:03:32 PM 2/8/2019 3:03:32 PM 2/8/2019 3:03:32 PM Date: 14-Feb-19 SAMPLE TRACKING Person PMG PMG PMG PMG New Location Sub Sub Sub Sub Page 11 of24 HFNA-000003035 EPA Inspection Report - Page 1486 of 1969 ALS Houston, US Client Name: Work Order: Navajo Refining HS19020432 Date/Time Received: Received by: Date: 14-Feb-19 Sample Receipt Checklist 08-Feb-2019 09:00 NDR Checklist completed by: Paresh M. Giga eSignature Matrices: 8-Feb-2019 Date Reviewed by: Carrier name: Corey Grandits eSignature FedEx 13-Feb-2019 Date Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? VOA/TX1005/TX1006 Solids in hermetically sealed vials? Chain of custody present? Chain of custody signed when relinquished and received? Samplers name present on COG? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler( s )/Kit( s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Login Notes: Client Contacted: Date Contacted: Contacted By: Regarding: Comments: Yes ~ Yes D Yes D Yes D Yes ~ Yes ~ Yes [] Yes ~ Yes ~ Yes ~ Yes @ Yes ~ Yes @ 0.8c/1.1 c U/c Hazmatpac 2/8/19 15:35 Yes D Yes D Yes D No D No D No D No D No D No D No D No D No D No D No D No D No D Not Present D Not Present ~ Not Present ~ Not Present @ 1 Page(s) COC 1Ds:None ll1R25 No D No D No D No VOA vials submitted ~ N/A ~ N/A ~ Person Contacted: Corrective Action: Page 12 of24 HFNA-000003036 EPA Inspection Report - Page 1487 of 1969 Chain of Custody Form HS19020432 UT Navajo Refining Company oo Page _1~ of ~ BVVON Monthly Sampling (EOL) 03 A III IHI HI Enuiranmental ALS Project Manager: Erica Padl!.la 80 I~ 11111111111111111111 1111111 : : pJ;.c:;~a~e Otd~r : -------------~-'-'-,., <>Pt6JecfNaiti~ BWON Monthly Sampling (EOL) <A Specific Gravity ... :::wcirfor~~r .:-:-.: >. -:- --<<<< :::-:<-f,'rb-J'~.e,(t,-itj-~Q, ~-r' - ' - , - c - ' - ' - , c ' - + - - - - - - - - - - - - - r ' - ' - + - - - - - - - - - - - - - - - - - - - - - - - - - - - 1 >j;j: .... '' ........... . : <oinpan{Name Navajo Refining Company LLC Elili T:<>Corripaii~ Holly Frontier Navajo Refining LLC C Tyler Turner Gabi Combs P.O. Box 159 >:: \ \ \ityi~taiel~ip Artesia, NM 88211-0159 :.. : <: P66iie (575) 748-3311 : > J".ait (575) 746-5451 . .. .. . .. . . Na.::::::: < :: >: sam:i:m{oesiription\ :>> .... >> S-1 (AP! HC) >( S-3 (API Water) :>3< > S-5 (T-40) 501 East Maln /cityJS~telZii> Artesia, New Mexico 88210 <: : < ::: r:i-iooe (575) 748-3311 . . . . . . . . . . . . :fa)! (575) 746-5451 ::: e~~allAd~~ss Suzanne.Aguilar@hollyfrontier.com 1:.. i 02/07 /19 02/07/19 02/07/19 02107/19 9:08 AM Liquid 8 9:25AM Liquid 8 8:46AM Liquid 8 8:51 AM Liquid 8 1 X X X X : 10:: Oother _ _ __ 02 Wk Days D 24 Hour Relinquished by: ., D,i_\e: Time: Received by ( aborato.1/ 7 . . N \0 f- 2 \~\ \".{ 0 '\ .. "' .. D~t&r , 'rilne: ChecklidllY(labotatory); / . <C .. . . ... . .. ,... . .... . > . . .. . . .. , ..... . Preservative .Key: .. . 6'-Na2s203 '6-NaHS04 7-0ther 8'4degrees c .. .... . .. Note: Any changes must be made in writing once samples and COC Form have been submitted to ALS Laboratory Group. !{ .. . ( '; (;IC:P:aci~ilg~:JC.h~pk !31ii(~e.!ovvf \: ::> . i~ 3'is./~/ I .~.'.:t': '."".'\,, ,7 !1-soaa ,r, e. ((" <;i .-.;;, Level II: Standard QC Level lll: Std QC + Raw Data Level IV: SW846 CLP-Like Other: ITRRP-Checklist ITRRP Level IV Copyright 2009 by ALS laboratory Group Page 13 of 24 HFNA-000003037 EPA Inspection Report - Page 1488 of 1969 Use ofthls system constitutes your agreement to the service conditions in the current FedEx Service Guide, available on fedex.com. FedEx vA!I not be responsible for any daim in excess of $100 per package, whether the result of loss1 damage, delay, nor-1-de!lvery, misde!ivery, or misinformation, unless you declare a higher value, pay an add!tiona! charge, document your actual loss and file a timely claim, Limitations found in the current FedEx Service Guide apply. Your right to recover from FedEx for any loss, including intrinsic value of the package, loss of sales, income mterest, profit, attorney's fees, costs, and other farms of damage whether direct, incidentaf, cor:isequential, or special is limited to the greater of $100 or the authorized declared value. Recovery cannot exceed actual documented loss. Maximum for items of extraordinary value is $1,000, e.g. jewelry1 precious meta!s1 negotiable instruments and other items listed in our Service Guide. Written claims must be Wed wlthin strict time limits, see current Fed Ex Service Guide. After printing this !abel CONSIGNEE COPY PLEASE PLACE lij FRONT OF POUCH 1. Fold !he printl?d page along the horizontal line 2. Place labe: in shipping pouch and affrx lt to your shipment. )> i;i d~ t . OJ G) ....i 0 c.o U ) 0(.,,) ~ 01 0:, ~ U) 0 l ....i ~ .,:,. ~ l 0 1 r ~ ig_ ~ 0 (i) -0 '? ;:c ,0, 5 'TI 0 "Tl ;:c 2:! m =i 0 c:o .... -< 00 X 0 'TI = C: < m 00 "' m ;:c OJ -..i z .... _-..i 0 :":;' )>O ::i::, G'5 ...::. <.a 0 ::c C :t::~ Q -I )> Page 14 of 24 HFNA-000003038 EPA Inspection Report - Page 1489 of 1969 14-Feb-2019 Corey Grandits ALS Environmental 10450 Stancliff Rd Suite 210 Houston, TX 77099 Re: HS19020432 Dear Corey, Work Order: 1902589 ALS Environmental received 4 samples on 12-Feb-2019 11 :30 AM for the analyses presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental - Holland and for only the analyses requested. Sample results are compliant with industry accepted practices and Quality Control results achieved laboratory specifications. Any exceptions are noted in the Case Narrative, or noted with qualifiers in the report or QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained from ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. The total number of pages in this report is 10. If you have any questions regarding this report, please feel free to contact me: ADDRESS: 3352 128th Avenue, Holland, Ml, USA PHONE: +1 (616) 399-6070 FAX: +1 (616) 399-6185 Sincerely, Electronically approved by: Chad Whelton Chad Whelton Project Manager Report of Laboratory Analysis Certificate No: MN 026-999-449 ~:>.c:Bf}H'J %Ul.t.t'J~t:3P% ::::::::. :.:: : .,.... Page 15 of24 HFNA-000003039 EPA Inspection Report - Page 1490 of 1969 ALS Group, USA Client: Project: Work Order: ALS Environmental HS 19020432 1902589 Lab Samp ID Client Sample ID 1902589-0 l HS l 9020432-0 l 1902589-02 HS l 9020432-02 1902589-03 HS l 9020432-03 1902589-04 HS l 9020432-04 Date: 14-Feb-19 Matrix Liquid Liquid Liquid Liquid Work Order Sample Summary Tag Number S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Collection Date 2/7/2019 09:08 2/7/2019 09:25 2/7/2019 08:46 2/7/2019 08:51 Date Received 2/12/2019 11 :30 2/12/2019 11:30 2/12/2019 11 :30 2/12/2019 11:30 Hold D Page 16 of24 Sample Summary Pagel of l HFNA-000003040 EPA Inspection Report - Page 1491 of 1969 ALS Group, USA Client: Project: WorkOrder: ALS Environmental HS19020432 1902589 Date: 14-Feb-19 QUALIFIERS, ACRONYMS, UNITS Qualifier ** a B E H Hr J ND 0 p R s u X Description Value exceeds Regulatory Limit Estimated Value Analyte is non-accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time BOD/CBOD - Sample was reset outside Hold Time, value should be considered estimated. Analyte is present at an estimated concentration between the MDL and Report Limit Not Detected at the Reporting Limit Sample amount is > 4 times amount spiked Dual Column results percent difference > 40% RPD above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL Analyte was detected in the Method Blank between the MDL and Reporting Limit, sample results may exhibit background or reagent contamination at the observed level. Acronym Description DUP Method Duplicate LCS Laboratory Control Sample LCSD Laboratory Control Sample Duplicate LOD Limit of Detection (see MDL) LOQ Limit ofQuantitation (see PQL) MBLK Method Blank MDL Method Detection Limit MS Matrix Spike MSD Matrix Spike Duplicate PQL Practical Quantitation Limit RPD Relative Percent Difference TDL Target Detection Limit TNTC Too Numerous To Count A APHA Standard Methods D ASTM E EPA SW SW-846 Update III Units Reported none Description Page 17 of24 QFPage 1 of1 HFNA-000003041 EPA Inspection Report - Page 1492 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS19020432 HS19020432-0l 2/7/2019 09:08 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Feb-19 Result Qual Report Limit Work Order: 1902589 Lab ID: 1902589-01 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.975 D5057-90 none Analyst: RZM 2/14/201912:14 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 18 of24 Analytical Results Page l of 4 HFNA-000003042 EPA Inspection Report - Page 1493 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS19020432 HS19020432-02 2/7/2019 09:25 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Feb-19 Result Qual Report Limit Work Order: 1902589 Lab ID: 1902589-02 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.00 none Analyst: RZM 2/14/201912:14 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 19 of24 Analytical Results Page 2 of 4 HFNA-000003043 EPA Inspection Report - Page 1494 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS19020432 HS19020432-03 2/7/2019 08:46 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Feb-19 Result Qual Report Limit Work Order: 1902589 Lab ID: 1902589-03 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.14 none Analyst: RZM 2/14/201912:14 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 20 of24 Analytical Results Page 3 of 4 HFNA-000003044 EPA Inspection Report - Page 1495 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS19020432 HS19020432-04 2/7/2019 08:51 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Feb-19 Result Qual Report Limit Work Order: 1902589 Lab ID: 1902589-04 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.14 none Analyst: RZM 2/14/201912:14 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 21 of24 Analytical Results Page 4 of 4 HFNA-000003045 EPA Inspection Report - Page 1496 of 1969 ALS Group, USA Client: ALS Environmental Work Order: 1902589 Project: HS19020432 Date: 14-Feb-19 QC BATCH REPORT Batch ID: R254869 Instrument ID WETCHEM Method: D5057-90 DUP Sample ID: 1902589-02A DUP Client ID: HS19020432-02 Run ID: WETCHEM_190214D Units: none SeqNo: 5521226 Analysis Date: 2/14/2019 12:14 PM Prep Date: OF: 1 Analyte Result PQL SPK Val SPK Ref Value %REC Control Limit RPO Ref Value %RPO RPO Limit Qual Specific Gravity 0 0 0 0 0-0 1.002 0.16 20 The following samples were analyzed in this batch: 1902589-01 A 1902589-04A 1902589-02A 1902589-03A Note: See Qualifiers Page for a list of Qualifiers aud their explauation. Page 22 of24 QC Page: 1 of 1 HFNA-000003046 EPA Inspection Report - Page 1497 of 1969 10450 Stancliff Rd, Ste 210 Houston, TX 77099 T: + 1 281 530 5656 F: +1 281 530 5887 www.alsglobal.com Subcontract Chain of Custody COC ID: 10716 SUBCONTRACT TO: ALS Environmental 3352 128th Ave Holland, MI 49424 CUSTOMER INFORMATION: Company: ALS Houston Contact: Address: Phone: Corey Grandits 10450 Stancliff Rd, Ste 210 +1 281 530 5656 Email: Alternate Contact: Email: Corey .Grand its@alsglobal.com Phone: +1 616 399 6070 INVOICE INFORMATION: Company: ALS Houston Contact: Address: Accounts Payable 10450 Stancliff Rd, Ste 210 Phone: +l 281 530 5656 Reference: TSR: HS19020432 Houston House Acct lASSAMPLEID CUENT SAMPLE ID . tfl-Ni\l'(Sl$ ~EQUESTED 1, HS19020432-01 S-1 (API HC) Sub Specific Gravity to ALS Holland 2. HS19020432-02 S-3 (API Water) Sub Specific Gravity to ALS Holland 3. HS19020432-03 Sub Specific Gravity to ALS Holland 4, HS1902043204 S-6 (T-41) Sub Specific Gravity to ALS Holland . MATRIX> Liquid Liquid Liquid Liquid c:pp~Ec:T DATE OUEOATE .. > 07 Feb 2019 09:08 15 Feb 2019 07 Feb 2019 09:25 15 Feb 2019 07 Feb 2019 08:46 15 Feb 2019 07 Feb 2019 08:51 15 Feb 2019 Comments: Please analyze for the analysis listed above. Send report to the emails shown above. SDS Sheets attached QC Level: STD (Laboratory Stan d QC: method blank and LCS required) Relinquished By: Received By: Cooler ID(s): Date/Time: Date/Time: Temperature(s): Page 23 of24 HFNA-00000304 7 EPA Inspection Report - Page 1498 of 1969 ALS Group, USA Client Name: Work Order: ALS - HOUSTON 1902589 Sample Receipt Checklist Date/Time Received: Received by: 12-Feb-19 11 :30 Checklist completed by _LlULK</ '-c;',e'-""" 13-Feb-19 ------------~----- eSignature Date Matrices: Carrier name: Liquid FedEx Reviewed by: eSignature Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Yes [i,] Yes [i,] Yes No Not Present D No Not Present D No Not Present [i,] Chain of custody present? Yes [i,] No Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Yes [i,] Yes [i,] Yes [i,] Yes [i,] No D No D No D No Sufficient sample volume for indicated test? Yes [i,] No All samples received within holding time? Yes [i,] No Container/Temp Blank temperature in compliance? Yes [i,] No Sample(s) received on ice? Temperature(s)/Thermometer(s): Yes [i,] No Cooler(s)/Kit(s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? r2/13/2019 9:56:24 AM Yes No VOA vials submitted [i,] Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Yes Yes D No N/A No D N/A Login Notes: 13-Feb-19 Date Client Contacted: Contacted By: Comments: Co rrectiveActio n: Date Contacted: Regarding: Person Contacted: SRC Page 1 of 1 HFNA-000003048 EPA Inspection Report - Page 1499 of 1969 ATTACHMENT 6 - Provided in Enclosed CD 2018 TAB ANALYTICAL RESULTS HFNA-000003049 EPA Inspection Report - Page 1500 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 December 14, 2018 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Annual Sampling Dear Gabriela, Work Order: HS18120496 ALS Environmental received 12 sample(s) on Dec 07, 2018 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, ~:::~:::::::~=--z,... t-{;-;...-, Generated By: DAYNA.FISHER Corey Grandits Project Manager Right Solutions Right Partnu www.a!sg!obaLcom Pagel of 43 HFNA-000003050 EPA Inspection Report - Page 1501 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Annual Sampling HS18120496 lab Samp ID HS18120496-01 HS18120496-02 HS18120496-03 HS18120496-04 HS18120496-05 HS18120496-06 HS18120496-07 HS18120496-08 HS18120496-09 HS18120496-10 HS18120496-11 HS18120496-12 Client Sample ID D-2101 Desalter Water D-2101 Desalter HC D-130 Desalter Water D-130 Desalter HC D-482 Water P-185 Strainer Water T-401 ISOM T-401 Water T-401 Sump Water T-401 Sump Gasoline Blend D-180 Naptha 70-C-350 Naptha Matrix Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Date: 14-Dec-18 SAMPLE SUMMARY TagNo Collection Date 06-Dec-2018 10:59 06-Dec-2018 10:42 06-Dec-2018 09: 15 06-Dec-2018 08:54 06-Dec-2018 09:29 06-Dec-2018 10:04 05-Dec-2018 03:09 05-Dec-2018 03:04 05-Dec-2018 03: 15 05-Dec-2018 03: 15 06-Dec-2018 11 :30 06-Dec-2018 08:50 Date Received 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 Hold D D D D D D D D D D D D Page 2 of 43 HFNA-000003051 EPA Inspection Report - Page 1502 of 1969 ALS Houston, US Date: 14-Dec-18 Client: Project: Work Order: Navajo Refining Company BWON Annual Sampling HS18120496 CASE NARRATIVE Work Order Comments The analysis for specific gravity was subcontracted to ALS Environmental in Holland, Ml. Final report attached. Page 3 of 43 HFNA-000003052 EPA Inspection Report - Page 1503 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling D-2101 Desalter Water 06-Dec-2018 10:59 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-18 ANALYTICAL REPORT Work0rder:HS18120496 Lab ID:HS18120496-01 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Dec-2018 11 :40 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of 43 HFNA-000003053 EPA Inspection Report - Page 1504 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling D-2101 Desalter HC 06-Dec-2018 10:42 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-18 ANALYTICAL REPORT Work0rder:HS18120496 Lab ID:HS18120496-02 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Dec-2018 11 :40 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of 43 HFNA-000003054 EPA Inspection Report - Page 1505 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling D-130 Desalter Water 06-Dec-2018 09:15 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-18 ANALYTICAL REPORT Work0rder:HS18120496 Lab ID:HS18120496-03 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Dec-2018 11 :40 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of 43 HFNA-000003055 EPA Inspection Report - Page 1506 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling D-130 Desalter HC 06-Dec-2018 08:54 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-18 ANALYTICAL REPORT Work0rder:HS18120496 Lab ID:HS18120496-04 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Dec-2018 11 :40 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of 43 HFNA-000003056 EPA Inspection Report - Page 1507 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling D-482 Water 06-Dec-2018 09:29 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-18 ANALYTICAL REPORT Work0rder:HS18120496 Lab ID:HS18120496-05 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Dec-2018 11 :40 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 8 of 43 HFNA-000003057 EPA Inspection Report - Page 1508 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling P-185 Strainer Water 06-Dec-2018 10:04 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-18 ANALYTICAL REPORT Work0rder:HS18120496 Lab ID:HS18120496-06 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Dec-2018 11 :40 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 9 of 43 HFNA-000003058 EPA Inspection Report - Page 1509 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling T-401 ISOM 05-Dec-2018 03:09 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-18 ANALYTICAL REPORT Work0rder:HS18120496 Lab ID:HS18120496-07 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Dec-2018 11 :40 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 10 of 43 HFNA-000003059 EPA Inspection Report - Page 1510 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling T-401 Water 05-Dec-2018 03:04 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-18 ANALYTICAL REPORT Work0rder:HS18120496 Lab ID:HS18120496-08 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Dec-2018 11 :40 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 11 of 43 HFNA-000003060 EPA Inspection Report - Page 1511 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling T-401 Sump Water 05-Dec-2018 03: 15 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-18 ANALYTICAL REPORT Work0rder:HS18120496 Lab ID:HS18120496-09 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Dec-2018 11 :40 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 12 of 43 HFNA-000003061 EPA Inspection Report - Page 1512 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling T-401 Sump Gasoline Blend 05-Dec-2018 03: 15 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-18 ANALYTICAL REPORT Work0rder:HS18120496 Lab ID:HS18120496-10 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Dec-2018 11 :40 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 13 of 43 HFNA-000003062 EPA Inspection Report - Page 1513 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling D-180 Naptha 06-Dec-2018 11 :30 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-18 ANALYTICAL REPORT Work0rder:HS18120496 Lab ID:HS18120496-11 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Dec-2018 11 :40 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 14 of 43 HFNA-000003063 EPA Inspection Report - Page 1514 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling 70-C-350 Naptha 06-Dec-2018 08:50 ANALYSES RESULT QUAL MDL SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 14-Dec-18 ANALYTICAL REPORT Work0rder:HS18120496 Lab ID:HS18120496-12 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Dec-2018 11 :40 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 15 of 43 HFNA-000003064 EPA Inspection Report - Page 1515 of 1969 ALS Houston, US Date: 14-Dec-18 Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120496 DATES REPORT Sample ID Client Samp ID Collection Date TCLP Date Prep Date Analysis Date DF Batch ID R329249 Test Name: SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY HS18120496-01 HS18120496-02 HS18120496-03 HS18120496-04 HS18120496-05 HS18120496-06 HS18120496-07 HS18120496-08 HS18120496-09 HS18120496-10 HS18120496-11 HS18120496-12 D-2101 Desalter Water D-2101 Desalter HC D-130 Desalter Water D-130 Desalter HC D-482 Water P-185 Strainer Water T-401 ISOM T-401 Water T-401 Sump Water T-401 Sump Gasoline Blend D-180 Naptha 70-C-350 Naptha 06 Dec 2018 10:59 06 Dec 2018 10:42 06 Dec 2018 09:15 06 Dec 2018 08:54 06 Dec 2018 09:29 06 Dec 2018 10:04 05 Dec 2018 03:09 05 Dec 2018 03:04 05 Dec 2018 03:15 05 Dec 2018 03:15 06 Dec 2018 11 :30 06 Dec 2018 08:50 Matrix: Liquid 14 Dec 2018 11 :40 14 Dec 2018 11 :40 14 Dec 2018 11 :40 14 Dec 2018 11 :40 14 Dec 2018 11 :40 14 Dec 2018 11 :40 14 Dec 2018 11 :40 14 Dec 2018 11 :40 14 Dec 2018 11 :40 14 Dec 2018 11 :40 14 Dec 2018 11 :40 14 Dec 2018 11 :40 Page 16 of 43 HFNA-000003065 EPA Inspection Report - Page 1516 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120496 Date: 14-Dec-18 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND 0 p R s u Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SOL TRRP Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL/SOL Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Page 17 of 43 HFNA-000003066 EPA Inspection Report - Page 1517 of 1969 ALS Houston, US Agency North Carolina Arkansas Texas North Dakota Illinois Louisiana Dept of Defense Kentucky Kansas Oklahoma Date: 14-Dec-18 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number 624-2018 88-0356 T10470231-18-21 R193 2018-2019 004438 03087 ANAB L2231 123043 - 2018 E-10352 2018-2019 2018-156 Expire Date 31-Dec-2018 27-Mar-2019 30-Apr-2019 30-Apr-2019 29-Jun-2019 30-Jun-2019 22-Dec-2018 30-Apr-2019 31-Jul-2019 31-Aug-2019 Page 18 of 43 HFNA-000003067 EPA Inspection Report - Page 1518 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Annual Sampling HS18120496 Lab Sarnp ID HS18120496-01 HS18120496-02 HS18120496-03 HS18120496-04 HS18120496-05 HS18120496-06 HS18120496-07 HS18120496-09 HS18120496-11 HS18120496-12 Client Sample ID D-2101 Desalter Water D-2101 Desalter HC D-130 Desalter Water D-130 Desalter HC D-482 Water P-185 Strainer Water T-401 ISOM T-401 Sump Water D-180 Naptha 70-C-350 Naptha Date: 14-Dec-18 SAMPLE TRACKING Action Login Login Login Login Login Login Login Login Login Login Date 12/10/2018 4:03: 12 PM 12/10/2018 4:03: 12 PM 12/10/2018 4:03: 12 PM 12/10/2018 4:03: 12 PM 12/10/2018 4:03: 12 PM 12/10/2018 4:03: 12 PM 12/10/2018 4:03: 12 PM 12/10/2018 4:03: 12 PM 12/10/2018 4:03: 12 PM 12/10/2018 4:03: 12 PM Person JRM JRM JRM JRM JRM JRM JRM JRM JRM JRM New Location Sub Sub Sub Sub Sub Sub Sub Sub Sub Sub Page 19 of 43 HFNA-000003068 EPA Inspection Report - Page 1519 of 1969 ALS Houston, US Client Name: Work Order: Navajo Refining HS18120496 Date/Time Received: Received by: Date: 14-Dec-18 Sample Receipt Checklist 07-Dec-2018 10:00 JRM Checklist completed by: Jared R. Makan 1O-Dec-2018 -e,:-S,-ig_n_a,-tu-re-------...---,D=-a..,.t_e_ _ Reviewed by: Corey Grandits eSignature 12-Dec-2018 Date Matrices: Carrier name: ALS Courier Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Chain of custody present? Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? TX1005 solids received in hermetically sealed vials? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler( s )/Kit( s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Login Notes: f:;oc 2 of 2 not relinquished. Client Contacted: Date Contacted: Yes ~ Yes D Yes D Yes ~ Yes D Yes ~ Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ 1.3c/1.6c UC/C oam cooler 12/10/2018 16:00 Yes 4 Yes D Yes D No D No D No D No D No ~ No D No D No D No D No D No D No D No No D No D Not Present D Not Present ~ Not Present ~ N/A ~ IR25 No VOA vials submitted N/A ~ N/A ~ Person Contacted: Contacted By: Comments: Regarding: Corrective Action: Page 20 of 43 HFNA-000003069 EPA Inspection Report - Page 1520 of 1969 Chain of Custody Form D +1 513 733 5336 Cincinnati, OH D +16163996070 Holland, Ml D +I 801 266 7700 Salt Lake City, UT Page _1_ of __2_ D Everett, WA +I 425 356 2600 D Houston, TX +1281 5305656 D Spring City, PA +16109484903 D Fort Collins, CO +I 970 490 1511 D Middletown, PA + 1 717 944 5541 D York, PA + I 71 7 505 5280 A Enuiranmenltal ALS Project Manager: Work Order#: . < .....: : custoroor:informatfon < : > ~r,oj~ctinformatfon .. . >>>>> << <PariurietertMethc:,d ~~uestfoi' An:dys1:s / P.uri;tias.e Orde/ :Projecf~aitie BWON Annual Sampling A. Specific Gravity :+'--'--'-'+-------------*.-;--'-c-'-'-:+'-~-'--'-'-,-'--c-'--j---------------l-~1---------------------------1 >w.bri< orci~r: .... : J?r(!j~~t. N.1Jl'fli:?~f . !;\: . . . . . . . .. . . . .......... . : (;ompariy ~arne Navajo Refining Company LLC '.:...$.i.ii.'.ti./..c.i.m..p.a.n.y. Holly Frontier Navajo Refining LLC . .... ' ... : :S~ricl:Rep<>rt:f:q Gabi Combs Tyler Turner Susie Aguilar ........ <; ..... lti: - P.O. Box 159 501 East Main HS18120496 \ :}Clty1$tiai~l2:ip Artesia, NM 88211-0159 :: : ::: :F > .>...q..it.y'J.St.a.te.il{.p. Artesia, New Mexico 88210 :d Navajo Refining Company - BWON Annual Sampling - : ...... :Pli1>J1e (575) 748-3311 - I .. : < : f'i!X. (575) 746-5451 :<:: : Fax !575) 746-5451 > < Ill IIII II 11111111111111<1J. i-J( 1: :: ... : ><~~~~I~ ~~~c;:i~ti~~ : e~MaliAdd$s Suzanne.Aguilar@hollyfrontier.com IJ l)ate ....... "J"iine ..... MatriX .Pres:<. ,;~;1~/ :: .... 6:. ...... ... I) > E }= .. G i>H < >I <Hcild . :-1 . D-2101 DesalterWater 12/06118 10:59AM Liquid 8 1 X > 2 D-2101 Desalter HC 12106118 10:42AM Liquid 8 1 X >) D-130 Desalter Water 12106/ - 18 - - - - - - 9: - 15 - A - M - - - - - Li - qu + id 8 - - - - - - + - - - - - - - + - - - - + - - - - + - - - 1 X l - - - - + - - - - , e - - - + - - - - + - - - l - - - - + - - - + - - - - - + - - - + - - - - - + - - - 1 >4 D-130 Desalter HC 12106/18 8:54AM Liquid 8 ~ D-482 Water :e:: P-185 Strainer Water :7: T-401 ISOM 12106/18 12106/18 12/05118 9:29AM Liquid 8 10:04AM Liquid 8 3:09AM Liquid 8 8: T-401 Water 12/05118 3:04AM Liquid 8 12/05118 3:15 AM Liquid 8 Jo T-401 Sump Gasoline Blend 12105118 3:15AM Liquid 8 Required Turnaround Time: D STD 10 Wk Days 0 s Wk Days D Other _ _ _ __ D 2 Wk Days D 24 Hour __ ! Reei.ined by.,:., .,,_..l Relinquished by: --- Logged by (Laboratory): Time: Received by: Date: ,_ / / {')--/ 7//x Date: ' Time: /(); cn Time: Received by (Laboratory): ::::r . rvv,::, .,,./,";,., Cheeked by {laboratory): Notes: . G)C) P:ackage: (CJ1ee:k E!o~:13~101119:/>:: . Cooler Temp. 1--......;.,;.;....;...;...;.......;......;...,...;.;,,..;.;.......;......;...,.....;,...;..;.,_........;..........;..;.....,.- u;t.C... Level I!: Standard QC ITRRP-Checklist Level Ill: Std QC + Raw Data ITRRP Level IV . ...!_ Level IV: SW846 CLP-Like 1-p-re""s_e_rv_a""t1-..,-1:1."'"K""e'"'y:-'"'t-"'H""c""t--2--~H""'N"'o'""..s.........a...""'H""2""s""o""4........,.4._..N'!"a""o""H-...S..,...,,.N-a2"'"s"'"2""0~3-..,..6.,.N...a"'"H~s"'"o"'"4~-1"'"-0t-h_e..r........8..-.4...d...e..g..r..e..e..s."'"c~~9..00-35....._ __._ _ _ _ _ _ _ _ _ _ _ __ : .... . . Other: Note: Any changes must be made in writing once samples and COC Form have been submitted to ALS laboratory Group. Copyright 2009 by ALS Laboratory Group Page 21 of 43 HFNA-000003070 EPA Inspection Report - Page 1521 of 1969 A Enuironmental Chain of Custody Form Page _2_ of _2_ D +1 513 733 5336 Cincinnati, OH D Everett, WA +I 425 356 2600 D Fort Collins, CO +1970490 1511 D +16163996070 Holland, Ml D Houston, TX +I 2815305656 D Middletown, PA +I 717944 5541 D +1 801 266 7700 Salt Lake City, UT D Spring City, PA +I 610 948 4903 D York, PA +I 717 505 5280 <: ..P..ii.r.~.~..s.e. 'otd..~.r. w~riio,iii- < Coinparif ~arne Navajo Refining Company LLC 1: ....... : P.O. Box 159 . P~o.ne (575) 748-3311 . . . .... ....... ........ . <:: :-:: >:<:::::::F~if (575) 746-5451 :::::::::::-: j:::-: -:-.--:: Gabriela.Combs@hollyfrontier.com . .: : e:,IVl~.1.J\ddress: !turner am@gmail.com ) ( D-180 Naptha I: :~ 70-C-350 Naptha .~ .... > P:roje~i~afu.6 BWON Annual Sampling /: E!ill T~(:{)~p~llY Holly Frontier Navajo Refining LLC 501 East Main ))t:ifyl$tat~iZip Artesia, New Mexico 88210 >> .. Pfioiie (575) 143.3311 ........ :<: ::::::: >fax (575) 746-5451 :::::ecM~li Address: Suzanne.Aouilar@hollyfront[ercom 12/06118 12/06118 11:30 AM Liquid 8 8:50AM Liquid 8 A: Specific Gravity C: - HS18120496 Navajo Refining Company BWON Annual Sampling iH: - IIIIII I II 111111111111111 - X X A: Relinquished by: ! . . !Shipment Method: Required Turnaround Time: D0ther ____ FedEX ... D STD 10 Wk Days 0 5 Wk Days D 2 Wk Days D 24Hour Date: Time: Received by: Notes: ... . . . . Relinquished by: Date: Time: Received by (Laboratory): Logged by {Laboratory): Time: Check~d by (Laboratory): PreservativeKey: . 1-HCL . 2~HN03 .. 3,,H2S04 5-Na2S203 . . . .. 6~aHS04 . 7-0ther ' Mdegrees C Note: Any changes must be made in writing once samples and COC Form have been submitted to ALS Laboratory Group. CoolerTel'!Jp. {;IC Pac~ge: (~he()k B~:x:!3~loif4. Level ll: Standard QC ITRRP-Checklist - - - - - - 1 Level Ill: Std QC + Raw Data ITRRP Level IV ......-+L""e-v-e""'!""IV,.,...:""s.,.w'"'s""4""6""C""'""L""P--L""i~k-e-+-..... 9-5035 Other: Copyright 2009 by ALS Laboratory Group Page 22 of 43 HFNA-000003071 EPA Inspection Report - Page 1522 of 1969 SHIPPER'S DECLARATION FOR DANGEROUS GOODS Shipper NAVAJO REFINING COMPANY C/0 AQUA MICROBICS 501 E MAIN ARTESIA NM88210 US Consignee Corey Grandits ALS 10450 Stancliff Suite 210 HOUSTON TX77099 US Two compfeted and signed copies of this Declaration must be handed to the operator TRANSPORT DETAILS This shipment is within the limltatlons prescribed for: {delete non applicable} Airport of Departure ARTESIA ~ y FT Airport of Destination: HOUSTON ABSGRA (Provide at least three copies to airline.) Air Waybm No. 709308590718 Page 1 of 1 Page{s) ~ : x Shipper's Reference Number (optional} 18 Compliant Express CAFE3211 WARNING Failure to comply with all respects with the applicable Dangerous Goods Regulations may be in breach of the applicable law ,subject to legal penalties. Shioment tvce: (delete non anulidb41) NATURE AND QUANTITY OF DANGEROUS GOODS UN Number or ide11tification Number, proper shipping name1 Class or DiVision (subsidiary rfskj, packing group (if required}, and all other required information. UN 1267, Petroleum crude oil,3,1/1 80 ml//361 UN 1268, Petroleum distillates, n.o.s.,3,111/1 160 mil/366 UN 3082, Environmentally hazardous substance, liquid, n.o.s.(AMMONIA, ANHYDROUS, HYDROGEN SULFIDE),9,lllil 160 mll/964 All Packed in One FIBREBOARD BOX a ~0.1 . -A-d--d-it-i-o-n-a-l-H--a-n-d-l-in--g--In-f-o-r-m--a-t-io-n---------------------------------------------------------------------------------------------------- 24 Hour Emergency Response-- CHEt\t'ITREC 1800-424-9300 CCN 201319 I hereby declare that the contents of this consignment are fully and accurately described above by the proper shipping name, and are classified, packaged, marked and labelled/placarded, and are ln all respects in proper condition for transport according to applicable International and National Governmental Regulations. I declare that all of the applicable air transport requirements have been met. 18224249300 Emergency Telephone Num~r Name/Title of Signatory Brady Hubbard/Envircnmenta! Coordinator Place and Date Artesia NM i2,'(}6/2018 Signature (sae warning above; Br~~~~ FOR RADIOACTIVE MATER!AL SHIPMENT ACCEPTABLE FOR PASSENGER AIRCRAFT, THE SHIPMENT CONTAINS RADIOACTIVE MATERIAL INTENOEO FOR. USE IN OR - INC!DENTTO Rl::SEARCH, MEDICAL DIAGNOSIS OR TREATMENT. ADR EUROPEAN TRANSPORT STATEMENT: CARRIAGE IN ACCORDANCE WITH 1.1.4.2.1 LOGOS ~1b729511/12 Page 23 of 43 HFNA-000003072 EPA Inspection Report - Page 1523 of 1969 Use of this system constitutes your agreement to the service conditions ln the current FedEx Service Guide, available on fedex.com. FedEx will not be responsible for any claim in excess of $100 per package, whether the result of loss, damage, delay, nondelivery, misdeHvery, or mis.information, unless you declare a higher value, pay an additional charge, document your actual loss and file a timely daim. limitations found in the current FedEx Service Guide apply. Your right to recover from FedEx for any loss, including intrinsic"Va!ue of the package, loss of sales, income interest, profit, attorney's fees, costs, an'd other forms of damage whether direct1 incidental, consequential, or special is limited to the greater of $100 or the authorized declared value. Recovery cannot exceed actual documented loss. Maximum for items of extraordinary value is $1,000, e.g. jewelry, prec!ous metals, negotiable instruments and other items listed in our Service Guide. Written dalms must be filed within strict time limits, see current FedEx Service Guide. After printing this !abel: CONSIGNEE COPY PLEASE PLACE IN FRONT OF POUCH 1. Fold the printed paga along the horizontal Hna. 2. Place label in shipping pouch and affix it to your shiprnenl u,)> it:":J:;"":J,:': DJ .0.... c,p w fr 0 ,t 00 ~ (J'I I; C) CD g, .0.... 2- ->, "' 00 j ~ I [ 'f!J= 0 '"O "' :;o ""' 5 "Tl "0 ' c:::> ~ "'-,) -~ 0 I"'-') ;:! 0 "0"'"' <'::: < m m = _"' ..... ;:o .0... ...... z 0 )>O ;):, i5 w 0 ::i:: 0 :c~ 0 -I )> -; -ozf-3 0 ',;~ - Ps~:C Cl) ..... )> ("") =J-l 0 ro t9fJ3 :ag :::: ~ s-I t;; en ;:o wl' '"'z -- ~Cl> m 0 m ~;:: mro "'-I (/) -< 0 ~ = z0 ~ G) "U c':)"O ~" """"""'' -I :z ~ ("") >< :z .... -.i ,,' -.i :;; Cl 0 =i U) en = .~,,CD r I - I w 00 U,Q "0- =i~ ' ~~ o -, lffil1i JH1111~UUiw 551C11FlFEl104C '*! F ")>'"0':"C' ;;o m ~~~ Q -.i-l~ ~~ri:i ~ ~6g ~ ooo ~rm mwo Ki~i ::!Z Page 24 of 43 HFNA-000003073 EPA Inspection Report - Page 1524 of 1969 14-Dec-2018 Corey Grandits ALS Environmental 10450 Stancliff Rd Suite 210 Houston, TX 77099 Re: HS18120496 Dear Corey, Work Order: 1812650 ALS Environmental received 12 samples on 11-Dec-2018 10:00 AM for the analyses presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental - Holland and for only the analyses requested. Sample results are compliant with industry accepted practices and Quality Control results achieved laboratory specifications. Any exceptions are noted in the Case Narrative, or noted with qualifiers in the report or QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained from ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. The total number of pages in this report is 19. If you have any questions regarding this report, please feel free to contact me: ADDRESS: 3352 128th Avenue, Holland, Ml, USA PHONE: +1 (616) 399-6070 FAX: +1 (616) 399-6185 Sincerely, Electronically approved by: Chad Whelton Chad Whelton Project Manager Report of Laboratory Analysis Certificate No: MN 998501 ~:>.c:Bf}H'J %Ul.t.t'J~t:3P% ::::::::. :.:: : .,.... Page 25 of 43 HFNA-00000307 4 EPA Inspection Report - Page 1525 of 1969 ALS Group, USA Client: Project: Work Order: ALS Environmental HS18120496 1812650 Lab Samp ID Client Sample ID 1812650-01 HS18120496-0l 1812650-02 1812650-03 HS18120496-02 HS18120496-03 1812650-04 1812650-05 1812650-06 HS18120496-04 HS18120496-05 HS18120496-06 1812650-07 1812650-08 1812650-09 ]8]2650-10 HS18120496-07 HS18120496-08 HS18120496-09 HS 18120496-10 1812650-11 1812650-12 HS18120496-ll HS18120496-12 Date: 14-Dec-18 Matrix Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Work Order Sample Summary Tag Number Collection Date D-210 l Desalter Water 12/6/2018 10:59 D-2101 DesalterHC 12/6/2018 10:42 D-130 Desalter Water 12/6/2018 09: 15 D-130 Desalter HC 12/6/2018 08:54 D-482 Water 12/6/2018 09:29 P-185 Strainer Water 12/6/2018 10:04 T-401 ISOM 12/5/2018 15:09 T-401 Water 12/5/2018 15:04 T-401 Sump Water 12/5/2018 ]5:]5 T-401 Sump Gasoline Blend 12/5/20]8 15:15 D-180 Naptha 12/6/2018 11 :30 70-C-350 Naptha 12/6/2018 08:50 Date Received Hold 12/11/2018 10:00 12/11/2018 10:00 C 12/11/2018 10:00 C 12/11/2018 10:00 12/11/2018 10:00 C 12/11/2018 10:00 C 12/11/2018 10:00 12/11/2018 10:00 C 12/11/2018 10:00 C ]2/11/2018 10:00 C 12/11/2018 10:00 C 12/11/2018 10:00 C Page 26 of 43 Sample Summary Pagel of l HFNA-000003075 EPA Inspection Report - Page 1526 of 1969 ALS Group, USA Client: Project: WorkOrder: ALS Environmental HS18120496 1812650 Date: 14-Dec-18 QUALIFIERS, ACRONYl\1S, UNITS Qualifier ** a B E H Hr J ND 0 p R s u X Description Value exceeds Regulatory Limit Estimated Value Analyte is non-accredited Analyle detected in the associakd Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time BOD/CBOD - Sample was reset outside Hold Time, value should be considered estimated. Anal)1e is present al an estimated concentration between the MDL and Report Limit Not Detected at the Reporting Limit Sample amount is > 4 times amount spiked Dual Column results percent difference > 40% RPD above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL Analyte was detected in the Method Blank between the MDL and Reporting Limit, sample results may exhibit background or reagent contamination at the observed level. Acronym Description DUP Method Duplicate LCS Laboratory Control Sample LCSD Laboratory Control Sample Duplicate LOD Limit of Detection (see MDL) LOQ Limit ofQuantitation (see PQL) MBLK Method Blank MDL Method Detection Limit MS Matrix Spike MSD Matrix Spike Duplicate PQL Practical Quantitation Limit RPD Relative Percent Difference TDL Target Detection Limit TNTC Too Numerous To Count A APHA Standard Methods D ASTM E EPA SW SW-846 Update III Units Reported none Description Page 27 of 43 QFPage 1 o/1 HFNA-000003076 EPA Inspection Report - Page 1527 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS18120496 HS18120496-0l 12/6/2018 10:59 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 8 Result Qual Report Limit Work Order: 1812650 Lab ID: 1812650-01 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.999 D5057-90 none Analyst: JSH 12/13/2018 03: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 28 of 43 Analytical Results Page 1 of 12 HFNA-000003077 EPA Inspection Report - Page 1528 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS18120496 HS18120496-02 12/6/2018 10:42 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 8 Result Qual Report Limit Work Order: 1812650 Lab ID: 1812650-02 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.770 D5057-90 none Analyst: JSH 12/13/2018 03: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 29 of 43 Analytical Results Page 2 of 12 HFNA-000003078 EPA Inspection Report - Page 1529 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS18120496 HS18120496-03 12/6/2018 09:15 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 8 Result Qual Report Limit Work Order: 1812650 Lab ID: 1812650-03 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.00 none Analyst: JSH 12/13/2018 03: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 30 of 43 Analytical Results Page 3 of 12 HFNA-000003079 EPA Inspection Report - Page 1530 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS18120496 HS18120496-04 12/6/2018 08:54 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 8 Result Qual Report Limit Work Order: 1812650 Lab ID: 1812650-04 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.789 D5057-90 none Analyst: JSH 12/13/2018 03: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 31 of 43 Analytical Results Page 4 of 12 HFNA-000003080 EPA Inspection Report - Page 1531 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS18120496 HS18120496-05 12/6/2018 09:29 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 8 Result Qual Report Limit Work Order: 1812650 Lab ID: 1812650-05 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.995 D5057-90 none Analyst: JSH 12/13/2018 03: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 32 of 43 Analytical Results Page 5 of 12 HFNA-000003081 EPA Inspection Report - Page 1532 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS18120496 HS18120496-06 12/6/2018 10:04 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 8 Result Qual Report Limit Work Order: 1812650 Lab ID: 1812650-06 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.00 none Analyst: JSH 12/13/2018 03: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 33 of 43 Analytical Results Page 6 of 12 HFNA-000003082 EPA Inspection Report - Page 1533 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS18120496 HS18120496-07 12/5/2018 03 :09 PM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 8 Result Qual Report Limit Work Order: 1812650 Lab ID: 1812650-07 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.658 D5057-90 none Analyst: JSH 12/13/2018 03: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 34 of 43 Analytical Results Page 7 of 12 HFNA-000003083 EPA Inspection Report - Page 1534 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS18120496 HS18120496-08 12/5/2018 03 :04 PM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 8 Result Qual Report Limit Work Order: 1812650 Lab ID: 1812650-08 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.671 D5057-90 none Analyst: JSH 12/13/2018 03: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 35 of 43 Analytical Results Page 8 of 12 HFNA-000003084 EPA Inspection Report - Page 1535 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS18120496 HS18120496-09 12/5/2018 03:15 PM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 8 Result Qual Report Limit Work Order: 1812650 Lab ID: 1812650-09 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.716 D5057-90 none Analyst: JSH 12/13/2018 03: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 36 of 43 Analytical Results Page 9 of 12 HFNA-000003085 EPA Inspection Report - Page 1536 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS18120496 HS18120496-10 12/5/2018 03:15 PM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 8 Result Qual Report Limit Work Order: 1812650 Lab ID: 1812650-10 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.726 D5057-90 none Analyst: JSH 12/13/2018 03: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 37 of 43 Analytical Results Page 10 of 12 HFNA-000003086 EPA Inspection Report - Page 1537 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS18120496 HS18120496-ll 12/6/2018 11:30 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 8 Result Qual Report Limit Work Order: 1812650 Lab ID: 1812650-11 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.700 D5057-90 none Analyst: JSH 12/13/2018 03: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 38 of 43 Analytical Results Page 11 of 12 HFNA-000003087 EPA Inspection Report - Page 1538 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Enviromnental HS18120496 HS18120496-12 12/6/2018 08:50 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Dec-l 8 Result Qual Report Limit Work Order: 1812650 Lab ID: 1812650-12 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.777 D5057-90 none Analyst: JSH 12/13/2018 03: 15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 39 of 43 Analytical Results Page 12 of 12 HFNA-000003088 EPA Inspection Report - Page 1539 of 1969 ALS Group, USA Client: ALS Environmental Work Order: 1812650 Project: HS18120496 Batch ID: R251336 Instrument ID WETCHEM Method: D5057-90 Date: 14-Dec-18 QC BATCH REPORT DUP Sample ID: 1812650-0SA DUP Client ID: HS18120496-05 Run ID: WETCHEM_181213M Units: none SeqNo: 5436592 Analysis Date: 12/13/2018 03:15 PM Prep Date: OF: 1 Analyte Result SPK Ref PQL SPK Val Value %REC Control Limit RPO Ref Value %RPO RPO Limit Qual Specific Gravity 1.005 0 0 0 0 0-0 0.9947 1.03 20 ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------1 DUP Sample ID: 1812650-09A DUP Units: none Analysis Date: 12/13/2018 03:15 PM Client ID: HS18120496-09 Run ID: WETCHEM_181213M SeqNo: 5436597 Prep Date: OF: 1 Analyte Result SPK Ref PQL SPK Val Value %REC Control Limit RPO Ref Value %RPO RPO Limit Qual Specific Gravity 0.7188 0 0 0 0 0-0 0.7157 0.431 20 The following samples were analyzed in this batch: 1812650-01A 1812650-04A 1812650-07A 1812650-1 OA 1812650-02A 1812650-05A 1812650-08A 1812650-11 A 1812650-03A 1812650-06A 1812650-09A 1812650-12A Note: See Qualifiers Page for a list of Qualifiers and their explanation. Page 40 of 43 QC Page: 1 of 1 HFNA-000003089 EPA Inspection Report - Page 1540 of 1969 ' A s 10450 Standlff Rd, Ste 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 _ www.alsglobal.com Subcontract Chain of Custody COC ID: 10407 SUBCONTRACT TO: ALS laboratory Group 3352 128th Ave. Holland, MI 494249263 CUSTOMER INFORMATION: Company: ALS Houston Contact: Address: Phone: Corey Grandits 10450 Stancliff Rd, Ste 210 +1 281 530 5656 Email: Alternate Contact: Email: Corey. Grandlts@alsglobal.com Jumoke M. Lawal jumoke.lawal@alsglobal.com Phone: +1 616 399 6070 INVOICE INFORMATION: Company: ALS Houston Contact: Address: Accounts Payable 10450 Standiff Rd, Ste 210 Phone: +1 281 530 5656 Reference: TSR: HS18120496 Houston House Acct 1. HS18120496-01 D-2101 Desalter Water Sub to ALS Holland 2. HS181l0496--02 D-2101 Desalter HC Sub to ALS Holland 3. HS18120496-03 D-130 Desalter Water Sub to ALS Holland 4. HS18120496-04 D-130 Desalter HC Sub to ALS Holland 5. HS181l0496-05 D-482 Water Sub to ALS Holland 6. HS:1.812049606 P-185 Strainer Water Sub to ALS Holland 7. HS18120496-07 T-401 ISOM Sub to ALS Holland 8. HS18120496-08 T-401 Water Sub to ALS Holland !!ill. HS181l0496--09 T-401 Sump Water Liquid Uquld Uquld Liquid Uquld Liquid Uquld Liquid Uquld 06 Dec 2018 10:59 14 Dec 2018 06 Dec 2018 10:42 14 Dec 2018 06 Dec 2018 09: 15 14 Dec 2018 06 Dec 2018 08:54 14 Dec 2018 06 Dec 2018 09:29 14 Dec 2018 06 Dec 2018 10:04 14 Dec 2018 05 Dec 2018 15:09 14 Dec 2018 OS Dec 2018 15:04 14 Dec 2018 05 Dec 2018 15:15 Page 41 of 43 HFNA-000003090 EPA Inspection Report - Page 1541 of 1969 Subcontract Chain of Custody COC ID: 10407 Sub to ALS Holland 10. HS18120496-10 T-401 Sump Gasoline Blend Sub to ALS Holland 11. HS1812049611 D-180 Naptha Sub to ALS Holland 12. HS18120496-12 70-C:350 Naptha Sub to ALS Holland Uquld Uquld Uquld 14 Dec 2018 05 Dec 2018 15:15 14 Dec 2018 06 Dec 2018 11:30 14 Dec 2018 06 Dec 2018 08:50 14 Dec 2018 Comments: Please analyze for the analysis Hsted above. Send report to the emails shown above. QC Level: STD (Laboratory Standard QC: method blank and LCS required) Rellnqulshed By: Re<:eived By: Cooler ID(s): Date/Time: Date{Time: Temperature(s) : l D ,ooo Page 42 of 43 HFNA-000003091 EPA Inspection Report - Page 1542 of 1969 ALS Group, USA Client Name: Work Order: ALS - HOUSTON 1812650 Sample Receipt Checklist Date/Time Received: Received by: 11-Dec-18 10:00 Checklist completed by _LlULK</ '-c;',e'-""" 11-Dec-18 ------------~----- e Signature Date Matrices: Carrier name: Reviewed by: eSignature Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Yes [i,] Yes [i,] Yes No Not Present D No Not Present D No Not Present [i,] Chain of custody present? Yes [i,] No Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Yes [i,] Yes [i,] Yes [i,] Yes [i,] No D No D No D No Sufficient sample volume for indicated test? Yes [i,] No All samples received within holding time? Yes [i,] No Container/Temp Blank temperature in compliance? Yes [i,] No Sample(s) received on ice? Temperature(s)/Thermometer(s): Yes [i,] No Cooler(s)/Kit(s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? r12/11 /2018 3:53:52 PM Yes No VOA vials submitted [i,] Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Yes Yes D No N/A No D N/A Login Notes: 11-Dec-18 Date Client Contacted: Contacted By: Comments: Date Contacted: Regarding: Person Contacted: CorrectiveAction: ~agcIToff!~ SRC Page 1 of 1 HFNA-000003092 EPA Inspection Report - Page 1543 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 December 20, 2018 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Annual Sampling Dear Gabriela, Work Order: HS1812051 O ALS Environmental received 18 sample(s) on Dec 07, 2018 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, ~:::~:::::::~=--z,... t-{;-;...-, Generated By: COREY.GRANDITS Corey Grandits Project Manager Right Solutions Right Partnu www.a!sg!obaLcom Pagel of 42 HFNA-000003093 EPA Inspection Report - Page 1544 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Annual Sampling HS18120510 lab Samp ID HS18120510-01 HS18120510-02 HS18120510-03 HS18120510-04 HS18120510-05 HS18120510-06 HS18120510-07 HS18120510-08 HS18120510-09 HS18120510-10 HS18120510-11 HS18120510-12 HS18120510-13 HS18120510-14 HS18120510-15 HS18120510-16 HS18120510-17 HS18120510-18 Client Sample ID D-2101 Desalter Water D-2101 Desalter HC D-130 Desalter Water D-130 Desalter HC D-482 Water P-185 Strainer Water T-401 ISOM T-401 Water T-401 Sump Water T-401 Sump Gasoline Blend D-180 Naptha 70-C-350 Naptha Field Blank Trip Blank EQ Blank Port 1 EQ Blank Port 2 EQ Blank Port 3 Duplicate Matrix Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Liquid Date: 20-Dec-18 SAMPLE SUMMARY TagNo Collection Date 06-Dec-2018 10:59 06-Dec-2018 10:42 06-Dec-2018 09: 15 06-Dec-2018 08:54 06-Dec-2018 09:29 06-Dec-2018 10:04 05-Dec-2018 15:09 05-Dec-2018 15:04 05-Dec-2018 15: 15 05-Dec-2018 15: 15 06-Dec-2018 11 :30 06-Dec-2018 08:50 06-Dec-2018 09:27 06-Dec-2018 00:00 06-Dec-2018 13:30 06-Dec-2018 13:30 06-Dec-2018 13:30 05-Dec-2018 00:00 Date Received 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 07-Dec-2018 10:00 Hold D D D D D D D D D D D D D D D D D D Page 2 of 42 HFNA-000003094 EPA Inspection Report - Page 1545 of 1969 ALS Houston, US Date: 20-Dec-18 Client: Project: Work Order: Navajo Refining Company BWON Annual Sampling HS18120510 GCMS Volatiles by Method SW8260 Batch ID: R329602 Sample ID: D-482 Water (HS18120510-05) CASE NARRATIVE Lowest practical dilution for sample hs18120510-05. Sample is oily. Batch ID: R329345 Sample ID: HS18120216-12MS MS and MSD are for an unrelated sample Batch ID: R329225,R329435,R329443 The test results meet requirements of the current NELAP standards, state requirements or programs where applicable. Page 3 of 42 HFNA-000003095 EPA Inspection Report - Page 1546 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling D-2101 Desalter Water 06-Dec-2018 10:59 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 120 98.0 99.0 99.6 98.9 Method:SW8260 0.60 REPORT LIMIT 5.0 70-126 82-124 77-123 82-127 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-01 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC %REC %REC %REC 1000 1000 1000 1000 1000 Analyst: PC 13-Dec-2018 15:34 13-Dec-2018 15:34 13-Dec-2018 15:34 13-Dec-2018 15:34 13-Dec-2018 15:34 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of 42 HFNA-000003096 EPA Inspection Report - Page 1547 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling D-2101 Desalter HC 06-Dec-2018 10:42 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 3,900 101 101 102 106 Method:SW8260 24 REPORT LIMIT 240 70-126 70-130 70-130 70-130 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-02 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg %REC %REC %REC %REC 50000 50000 50000 50000 50000 Analyst: WLR 13-Dec-2018 12:27 13-Dec-2018 12:27 13-Dec-2018 12:27 13-Dec-2018 12:27 13-Dec-2018 12:27 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of 42 HFNA-000003097 EPA Inspection Report - Page 1548 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling D-130 Desalter Water 06-Dec-2018 09:15 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 69 96.4 102 98.0 98.1 Method:SW8260 0.60 REPORT LIMIT 5.0 70-126 82-124 77-123 82-127 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-03 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC %REC %REC %REC 1000 1000 1000 1000 1000 Analyst: PC 13-Dec-2018 16:46 13-Dec-2018 16:46 13-Dec-2018 16:46 13-Dec-2018 16:46 13-Dec-2018 16:46 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of 42 HFNA-000003098 EPA Inspection Report - Page 1549 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling D-130 Desalter HC 06-Dec-2018 08:54 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 5,200 101 101 102 107 Method:SW8260 25 REPORT LIMIT 250 70-126 70-130 70-130 70-130 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-04 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg %REC %REC %REC %REC 50000 50000 50000 50000 50000 Analyst: WLR 13-Dec-2018 12:48 13-Dec-2018 12:48 13-Dec-2018 12:48 13-Dec-2018 12:48 13-Dec-2018 12:48 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of 42 HFNA-000003099 EPA Inspection Report - Page 1550 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling D-482 Water 06-Dec-2018 09:29 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 1.9 97.9 95.8 99.5 98.4 Method:SW8260 J 0.30 REPORT LIMIT 2.5 70-126 82-124 77-123 82-127 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-05 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L 500 %REC 500 %REC 500 %REC 500 %REC 500 Analyst: PC 19-Dec-2018 17:46 19-Dec-2018 17:46 19-Dec-2018 17:46 19-Dec-2018 17:46 19-Dec-2018 17:46 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 8 of 42 HFNA-000003100 EPA Inspection Report - Page 1551 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling P-185 Strainer Water 06-Dec-2018 10:04 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 48 98.9 97.3 99.9 97.0 Method:SW8260 0.60 REPORT LIMIT 5.0 70-126 82-124 77-123 82-127 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-06 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC %REC %REC %REC 1000 1000 1000 1000 1000 Analyst: PC 19-Dec-2018 21 :49 19-Dec-2018 21 :49 19-Dec-2018 21 :49 19-Dec-2018 21 :49 19-Dec-2018 21 :49 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 9 of 42 HFNA-000003101 EPA Inspection Report - Page 1552 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling T-401 ISOM 05-Dec-2018 15:09 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 2,100 99.4 104 98.9 106 Method:SW8260 24 REPORT LIMIT 240 70-126 70-130 70-130 70-130 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-07 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg %REC %REC %REC %REC 50000 50000 50000 50000 50000 Analyst: WLR 13-Dec-2018 15:22 13-Dec-2018 15:22 13-Dec-2018 15:22 13-Dec-2018 15:22 13-Dec-2018 15:22 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 10 of 42 HFNA-000003102 EPA Inspection Report - Page 1553 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling T-401 Water 05-Dec-2018 15:04 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 1,900 88.3 104 102 103 Method:SW8260 25 REPORT LIMIT 250 70-126 70-130 70-130 70-130 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-08 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg %REC %REC %REC %REC 50000 50000 50000 50000 50000 Analyst: WLR 18-Dec-2018 11 :07 18-Dec-2018 11:07 18-Dec-2018 11:07 18-Dec-2018 11:07 18-Dec-2018 11:07 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 11 of 42 HFNA-000003103 EPA Inspection Report - Page 1554 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling T-401 Sump Water 05-Dec-2018 15:15 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 2,200 100 103 101 105 Method:SW8260 24 REPORT LIMIT 240 70-126 70-130 70-130 70-130 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-09 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg %REC %REC %REC %REC 50000 50000 50000 50000 50000 Analyst: WLR 18-Dec-2018 11 :29 18-Dec-2018 11:29 18-Dec-2018 11:29 18-Dec-2018 11:29 18-Dec-2018 11:29 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 12 of 42 HFNA-000003104 EPA Inspection Report - Page 1555 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling T-401 Sump Gasoline Blend 05-Dec-2018 15:15 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 2,500 98.4 104 100 105 Method:SW8260 25 REPORT LIMIT 250 70-126 70-130 70-130 70-130 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-10 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg %REC %REC %REC %REC 50000 50000 50000 50000 50000 Analyst: WLR 13-Dec-2018 15:00 13-Dec-2018 15:00 13-Dec-2018 15:00 13-Dec-2018 15:00 13-Dec-2018 15:00 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 13 of 42 HFNA-000003105 EPA Inspection Report - Page 1556 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling D-180 Naptha 06-Dec-2018 11 :30 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 7,200 101 96.8 102 107 Method:SW8260 24 REPORT LIMIT 240 70-126 70-130 70-130 70-130 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-11 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg %REC %REC %REC %REC 50000 50000 50000 50000 50000 Analyst: WLR 13-Dec-2018 13:53 13-Dec-2018 13:53 13-Dec-2018 13:53 13-Dec-2018 13:53 13-Dec-2018 13:53 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 14 of 42 HFNA-000003106 EPA Inspection Report - Page 1557 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling 70-C-350 Naptha 06-Dec-2018 08:50 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 3,700 100 101 99.8 108 Method:SW8260 25 REPORT LIMIT 250 70-126 70-130 70-130 70-130 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-12 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg %REC %REC %REC %REC 50000 50000 50000 50000 50000 Analyst: WLR 13-Dec-2018 14: 15 13-Dec-2018 14:15 13-Dec-2018 14:15 13-Dec-2018 14:15 13-Dec-2018 14:15 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 15 of 42 HFNA-000003107 EPA Inspection Report - Page 1558 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling Field Blank 06-Dec-2018 09:27 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 96.3 98.7 98. 1 98.0 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-13 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 15-Dec-2018 06:32 15-Dec-2018 06:32 15-Dec-2018 06:32 15-Dec-2018 06:32 15-Dec-2018 06:32 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 16 of 42 HFNA-000003108 EPA Inspection Report - Page 1559 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling Trip Blank 06-Dec-2018 00:00 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 98.3 97.7 99.8 101 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-14 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 15-Dec-2018 06:56 15-Dec-2018 06:56 15-Dec-2018 06:56 15-Dec-2018 06:56 15-Dec-2018 06:56 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 17 of 42 HFNA-000003109 EPA Inspection Report - Page 1560 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling EQ Blank Port 1 06-Dec-2018 13:30 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 95.0 101 98.0 96.5 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-15 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 15-Dec-2018 07:20 15-Dec-2018 07:20 15-Dec-2018 07:20 15-Dec-2018 07:20 15-Dec-2018 07:20 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 18 of 42 HFNA-000003110 EPA Inspection Report - Page 1561 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling EQ Blank Port 2 06-Dec-2018 13:30 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 96.9 97.7 97.7 102 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-16 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 15-Dec-2018 07:44 15-Dec-2018 07:44 15-Dec-2018 07:44 15-Dec-2018 07:44 15-Dec-2018 07:44 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 19 of 42 HFNA-000003111 EPA Inspection Report - Page 1562 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling EQ Blank Port 3 06-Dec-2018 13:30 ANALYSES VOLATILES - SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 91.0 98.0 87.6 105 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-17 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC 1 %REC 1 Analyst: PC 17-Dec-2018 17:21 17-Dec-2018 17:21 17-Dec-2018 17:21 17-Dec-2018 17:21 17-Dec-2018 17:21 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 20 of 42 HFNA-000003112 EPA Inspection Report - Page 1563 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Annual Sampling Duplicate 05-Dec-2018 00:00 ANALYSES VOLATILES BY SW8260C Benzene Surr: 1, 2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 1,700 96.9 102 97.0 103 Method:SW8260 24 REPORT LIMIT 240 70-126 70-130 70-130 70-130 Date: 20-Dec-18 ANALYTICAL REPORT Work0rder:HS1812051 O Lab ID:HS18120510-18 Matrix: Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg %REC %REC %REC %REC 50000 50000 50000 50000 50000 Analyst: WLR 18-Dec-2018 11 :52 18-Dec-2018 11:52 18-Dec-2018 11:52 18-Dec-2018 11:52 18-Dec-2018 11:52 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 21 of 42 HFNA-000003113 EPA Inspection Report - Page 1564 of 1969 ALS Houston, US Client: Navajo Refining Company Project: BWON Annual Sampling WorkOrder: HS 1812051 O Batch ID: 2819 SamplD HS18120510-02 HS18120510-04 HS18120510-07 HS18120510-10 HS18120510-11 HS18120510-12 Batch ID: 2830 SamplD HS18120510-08 HS18120510-09 HS18120510-18 Method: VOLATl LES BY SW8260C Container Sample Wt/Vol 5.136 (g) 4.98 (g) 5.222 (g) 4.99 (g) 5.277 (g) 4.972 (g) Final Volume 5 (ml) 5 (ml) 5 (ml) 5 (ml) 5 (ml) 5 (ml) Weight Factor 0.97 0.96 0.95 1.01 Method: VOLATILES BY SW8260C Container Sample Wt/Vol 4.996 (g) 5.1 (g) 5.106 (g) Final Volume 5 (ml) 5 (ml) 5 (ml) Weight Factor 0.98 0.98 Container Type Bulk (5030B) Bulk (5030B) Bulk (5030B) Bulk (5030B) Bulk (5030B) Bulk (5030B) Container Type Bulk (5030B) Bulk (5030B) Bulk (5030B) Date: 20-Dec-18 WEIGHT LOG Page 22 of 42 HFNA-000003114 EPA Inspection Report - Page 1565 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120510 Sample ID Client Samp ID Collection Date TCLP Date Batch ID R3291 26 Test Name : VOLATILES BY SW8260C HS18120510-02 D-2101 Desalter HC 06 Dec 2018 10:42 HS18120510-04 D-130 Desalter HC 06 Dec 2018 08:54 HS18120510-07 T-401 ISOM 05 Dec 2018 15:09 HS18120510-10 T-401 Sump Gasoline Blend 05 Dec201815:15 HS18120510-11 D-180 Naptha 06 Dec 2018 11 :30 HS18120510-12 70-C-350 Naptha 06 Dec 2018 08:50 Batch ID R329225 Test Name : VOLATILES - SW8260C HS18120510-01 HS18120510-03 D-2101 DesalterWater D-130 Desalter Water 06 Dec 2018 10:59 06 Dec 2018 09:15 Batch ID R329345 Test Name : VOLATILES - SW8260C HS18120510-13 HS18120510-14 HS18120510-15 HS18120510-16 Field Blank Trip Blank EQ Blank Port 1 EQ Blank Port 2 06 Dec 2018 09:27 06 Dec 2018 00:00 06 Dec 2018 13:30 06 Dec 2018 13:30 Batch ID R329435 Test Name: VOLATILES BY SW8260C HS18120510-08 T-401 Water 05 Dec 2018 15:04 HS18120510-09 T-401 Sump Water 05 Dec201815:15 HS18120510-18 Duplicate 05 Dec 2018 00:00 Batch ID R329443 Test Name: VOLATILES- SW8260C HS18120510-17 EQ Blank Port 3 06 Dec 2018 13:30 Batch ID R329602 Test Name : VOLATILES - SW8260C HS18120510-05 HS18120510-06 D-482 Water P-185 Strainer Water 06 Dec 2018 09:29 06 Dec 2018 10:04 Date: 20-Dec-18 DATES REPORT Prep Date Analysis Date Matrix: Liquid 13 Dec 2018 12:27 13 Dec 2018 12:48 13 Dec 2018 15:22 13 Dec 2018 15:00 13 Dec 2018 13:53 13 Dec201814:15 Matrix: Liquid 13 Dec 2018 15:34 13 Dec 2018 16:46 Matrix: Liquid 15 Dec 2018 06:32 15 Dec 2018 06:56 15 Dec 2018 07:20 15 Dec 2018 07:44 Matrix: Liquid 18 Dec 2018 11 :07 18 Dec 2018 11 :29 18 Dec 2018 11 :52 Matrix: Liquid 17 Dec201817:21 Matrix: Liquid 19 Dec 2018 17:46 19 Dec 2018 21 :49 DF 5000 0 5000 0 5000 0 5000 0 5000 0 5000 0 1000 1000 5000 0 5000 0 5000 0 500 1000 Page 23 of 42 HFNA-000003115 EPA Inspection Report - Page 1566 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120510 Date: 20-Dec-18 QC BATCH REPORT Batch ID: R329126 Instrument: VOA8 Method; SW8260 MBLK Client ID: Analyte Sample ID: MBLKW1-121318 Units: ug/Kg Analysis Date: 13-Dec-2018 08:23 Run ID: VOA8_329126 SeqNo: 4861889 PrepDate: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 25 2456 2370 2526 2700 250 0 2500 0 2500 0 2500 0 2500 0 98.2 76 - 125 0 94.8 80 - 120 0 101 80 - 119 0 108 81 - 118 LCS Client ID: Analyte Sample ID: VLCSW1-121318 Units: ug/Kg Analysis Date: 13-Dec-2018 07:39 Run ID: VOA8_329126 SeqNo: 4861888 PrepDate: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 50.15 5.0 50 51.21 0 50 50.73 0 50 48.03 0 50 52.48 0 50 0 100 75 - 124 0 102 76 - 125 0 101 80 - 120 0 96.1 80 - 119 0 105 81 - 118 MS Client ID: Analyte Sample ID: HS18120402-01 MS Units: ug/Kg Analysis Date: 13-Dec-2018 10:34 Run ID: VOA8_329126 SeqNo: 4862550 Prep Date: OF: 500 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 31430 21900 27870 24450 25180 2500 0 0 0 0 25000 25000 25000 25000 25000 371.3 0 0 0 0 124 70 - 130 87.6 70 - 126 111 70 - 130 97.8 70 - 130 101 70 - 130 Page 24 of 42 HFNA-000003116 EPA Inspection Report - Page 1567 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120510 Date: 20-Dec-18 QC BATCH REPORT Batch ID: R329126 Instrument: VOA8 Method; SW8260 MSD Client ID: Analyte Sample ID: HS18120402-01MSD Units: ug/Kg Analysis Date: 13-Dec-2018 10:56 Run ID: VOA8_329126 SeqNo: 4862551 PrepDate: OF: 500 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 28140 21760 27700 24340 25250 2500 0 0 0 0 The following samples were analyzed in this batch: Sl8120510-02 Sl8120510-ll 25000 25000 25000 25000 25000 371.3 0 0 0 0 111 70 - 130 87.0 70 - 126 111 70 - 130 97.4 70 - 130 101 70 - 130 31430 21900 27870 24450 25180 11 30 0.654 30 0.622 30 0.463 30 0.28 30 HS 18120510-04 HS 18120510-12 HS 18120510-07 HS18120510-10 Page 25 of 42 HFNA-000003117 EPA Inspection Report - Page 1568 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120510 Date: 20-Dec-18 QC BATCH REPORT Batch ID: R329225 Instrument: VOA6 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-181213 Units: ug/L Analysis Date: 13-Dec-2018 11 :58 Run ID: VOA6_329225 SeqNo: 4864408 Prep Date: OF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 48.44 0 50 48.87 0 50 48.86 0 50 49.91 0 50 0 96.9 70 - 130 0 97.7 82 - 115 0 97.7 73 - 126 0 99.8 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-181213 Units: ug/L Analysis Date: 13-Dec-2018 11 :09 Run ID: VOA6_329225 SeqNo: 4864407 Prep Date: OF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 18.7 5.0 20 47.96 0 50 50.61 0 50 49.9 0 50 49.25 0 50 0 93.5 74 - 120 0 95.9 70 - 130 0 101 82 - 115 0 99.8 73 - 126 0 98.5 81 - 120 MS Client ID: Analyte Sample ID: HS18120196-02MS Units: ug/L Analysis Date: 13-Dec-2018 15:58 Run ID: VOA6_329225 SeqNo: 4864415 Prep Date: OF: 20 Result PQL SPKVal SPK Ref Value %REC Control Limit RPO Ref RPO Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 392 950.7 1014 987.5 995 100 400 0 1000 0 1000 0 1000 0 1000 0 98.0 70 - 127 0 95. 1 70 - 126 0 101 82 - 124 0 98.8 77 - 123 0 99.5 82 - 127 Page 26 of 42 HFNA-000003118 EPA Inspection Report - Page 1569 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120510 Date: 20-Dec-18 QC BATCH REPORT Batch ID: R329225 Instrument: VOA6 Method; SW8260 MSD Client ID: Analyte Sample ID: HS18120196-02MSD Units: ug/L Analysis Date: 13-Dec-2018 16:22 Run ID: VOA6_329225 Seq No: 4864416 PrepDate: OF: 20 Result SPK Ref Control RPO Ref RPO PQL SPK Val Value %REC Limit Value %RPO Limit Qual Benzene 407.8 100 400 0 102 70 -127 392 3.94 20 Surr: 1,2-0ichloroethane-d4 941A 0 1000 0 94.1 70-126 950. 7 0.987 20 Surr: 4-Bromofluorobenzene 1013 0 1000 0 101 82 - 124 1014 0.0954 20 Surr: Dibromofluoromethane 984.5 0 1000 0 98A 77- 123 987.5 0.308 20 Surr: Toluene-dB 979.7 0 1000 0 98.0 82 - 127 995 1.55 20 The following samples were analyzed in this batch: ~F_s_1s_1_2o_s_1_0-_0_1_ _ _H_s_1s_1_2o_s_1_0-_0_ 3 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _~ Page 27 of 42 HFNA-000003119 EPA Inspection Report - Page 1570 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120510 Date: 20-Dec-18 QC BATCH REPORT Batch ID: R329345 Instrument: VOA6 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-181214 Units: ug/L Analysis Date: 14-Dec-2018 22:55 Run ID: VOA6_329345 SeqNo: 4867570 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 47.35 0 50 49.09 0 50 48.43 0 50 49.72 0 50 0 94.7 70 - 130 0 98.2 82 - 115 0 96.9 73 - 126 0 99A 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-181214 Units: ug/L Analysis Date: 14-Dec-2018 22:07 Run ID: VOA6_329345 SeqNo: 4867569 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 19.31 5.0 20 47.8 0 50 49.31 0 50 49A 0 50 49.42 0 50 0 96.5 74 - 120 0 95.6 70 - 130 0 98.6 82 - 115 0 98.8 73 - 126 0 98.8 81 - 120 MS Client ID: Analyte Sample ID: HS18120216-12MS Units: ug/L Analysis Date: 15-Dec-2018 00:31 Run ID: VOA6_329345 SeqNo: 4867574 Prep Date: OF: 250 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene 11570 1200 5000 1951 192 70 - 127 s Surr: 1,2-0ichloroethane-d4 11830 0 12500 0 94.7 70 - 126 Surr: 4-Bromofluorobenzene 12350 0 12500 0 98.8 82 - 124 Surr: Dibromofluoromethane 12520 0 12500 0 100 77 - 123 Surr: Toluene-dB 12450 0 12500 0 99.6 82 - 127 Page 28 of 42 HFNA-000003120 EPA Inspection Report - Page 1571 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120510 Date: 20-Dec-18 QC BATCH REPORT Batch ID: R329345 Instrument: VOA6 Method; SW8260 MSD Client ID: Analyte Sample ID: HS18120216-12MSD Units: ug/L Analysis Date: 15-Dec-2018 00:55 Run ID: VOA6_329345 SeqNo: 4867575 Prep Date: OF: 250 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 11550 11930 12550 12350 12040 1200 0 0 0 0 The following samples were analyzed in this batch: fS18120510-13 5000 12500 12500 12500 12500 1951 0 0 0 0 192 70 - 127 95.4 70 - 126 100 82 - 124 98.8 77 - 123 96.3 82 - 127 11570 0.135 20 s 11830 0.807 20 12350 1.6 20 12520 1.41 20 12450 3.42 20 HS 18120510-14 HS18120510-15 HS18120510-16 Page 29 of 42 HFNA-000003121 EPA Inspection Report - Page 1572 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120510 Date: 20-Dec-18 QC BATCH REPORT Batch ID: R329435 Instrument: VOA8 Method; SW8260 MBLK Client ID: Analyte Sample ID: MBLKW1-121818 Units: ug/Kg Analysis Date: 18-Dec-2018 08:31 Run ID: VOA8_329435 SeqNo: 4869787 PrepDate: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 25 2453 2469 2361 2605 250 0 2500 0 2500 0 2500 0 2500 0 98.1 76-125 0 98.8 80 - 120 0 94.5 80-119 0 104 81 - 118 LCS Client ID: Analyte Sample ID: VLCSW1-121818 Units: ug/Kg Analysis Date: 18-Dec-2018 07:47 Run ID: VOA8_329435 SeqNo: 4869786 PrepDate: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 49.92 5.0 50 43.15 0 50 51.54 0 50 47.98 0 50 50.71 0 50 0 99.8 75 - 124 0 86.3 76 - 125 0 103 80 - 120 0 96.0 80 - 119 0 101 81 - 118 MS Client ID: Analyte Sample ID: HS18120847-01 MS Units: ug/Kg Analysis Date: 18-Dec-2018 14:03 Run ID: VOA8_329435 SeqNo: 4871975 Prep Date: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 1959 2428 2591 2395 2260 240 2400 0 2400 0 2400 0 2400 0 2400 0 81.6 70 - 130 0 101 70 - 126 0 108 70 - 130 0 99.8 70 - 130 0 94.2 70 - 130 Page 30 of 42 HFNA-000003122 EPA Inspection Report - Page 1573 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120510 Date: 20-Dec-18 QC BATCH REPORT Batch ID: R329435 Instrument: VOA8 Method; SW8260 MSD Client ID: Analyte Sample ID: HS18120847-01 MSD Units: ug/Kg Analysis Date: 18-Dec-2018 14:46 Run ID: VOA8_329435 SeqNo: 4871977 PrepDate: OF: 50 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 2078 2432 2515 2299 2459 240 2400 0 2400 0 2400 0 2400 0 2400 0 86.6 70-130 0 101 70 - 126 0 105 70 - 130 0 95.8 70 - 130 0 102 70 - 130 1959 2428 2591 2395 2260 5.9 30 0.18 30 2.97 30 4.1 30 8.46 30 The following samples were analyzed in this batch: ~F_s_1s_1_2o_s_1_0-_o_s_ _ _H_s_1s_1_2o_s_1_0-_0_9 _ _ _H_s_1s_1_2o_s_1_0-_1_s- - - - - - - - - - - - ~ Page 31 of 42 HFNA-000003123 EPA Inspection Report - Page 1574 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120510 Date: 20-Dec-18 QC BATCH REPORT Batch ID: R329443 Instrument: VOA9 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-181217 Units: ug/L Analysis Date: 17-Dec-2018 11:35 Run ID: VOA9_329443 SeqNo: 4869994 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 44.46 0 50 49.69 0 50 43.2 0 50 52.24 0 50 0 88.9 70 - 130 0 99.4 82 - 115 0 86.4 73 - 126 0 104 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-1812017 Units: ug/L Analysis Date: 17-Dec-2018 10:45 Run ID: VOA9_329443 SeqNo: 4869993 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 21.49 5.0 20 42 0 50 51.9 0 50 43.75 0 50 52.76 0 50 0 107 74 - 120 0 84.0 70 - 130 0 104 82 - 115 0 87.5 73 - 126 0 106 81 - 120 MS Client ID: Analyte Sample ID: HS18120376-01 MS Units: ug/L Analysis Date: 17-Dec-2018 15:42 Run ID: VOA9_329443 SeqNo: 4870004 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene 26.42 5.0 20 0 132 70 - 127 s Surr: 1,2-0ichloroethane-d4 44.6 0 50 0 89.2 70 - 126 Surr: 4-Bromofluorobenzene 51.11 0 50 0 102 82 - 124 Surr: Dibromofluoromethane 44.35 0 50 0 88.7 77 - 123 Surr: Toluene-dB 53. 1 0 50 0 106 82 - 127 Page 32 of 42 HFNA-000003124 EPA Inspection Report - Page 1575 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120510 Date: 20-Dec-18 QC BATCH REPORT Batch ID: R329443 Instrument: VOA9 Method; SW8260 MSD Client ID: Analyte Sample ID: HS18120376-01 MSD Units: ug/L Analysis Date: 17-Dec-2018 16:07 Run ID: VOA9_329443 SeqNo: 4870005 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 25.89 5.0 20 43.98 0 50 51.25 0 50 44.84 0 50 52.63 0 50 0 129 70 - 127 0 88.0 70 - 126 0 103 82 - 124 0 89.7 77 - 123 0 105 82 - 127 26.42 2.01 20 s 44.6 1.41 20 51.11 0.267 20 44.35 1.1 20 53. 1 0.886 20 The following samples were analyzed in this batch: ~f_s_1s_1_2o_s_1_0-_17---------------------------~ Page 33 of 42 HFNA-000003125 EPA Inspection Report - Page 1576 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120510 Date: 20-Dec-18 QC BATCH REPORT Batch ID: R329602 Instrument: VOA6 Method; SW8260 MBLK Client ID: Analyte Sample ID: VBLKW-181219 Units: ug/L Analysis Date: 19-Dec-2018 13:45 Run ID: VOA6_329602 SeqNo: 4873605 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 49.44 0 50 47.69 0 50 49.5 0 50 48.8 0 50 0 98.9 70 - 130 0 95.4 82 - 115 0 99.0 73 - 126 0 97.6 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-181219 Units: ug/L Analysis Date: 19-Dec-2018 12:57 Run ID: VOA6_329602 SeqNo: 4873604 Prep Date: OF: 1 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 18.23 5.0 20 49.72 0 50 48.25 0 50 50.35 0 50 48.5 0 50 0 91.2 74 - 120 0 99.4 70 - 130 0 96.5 82 - 115 0 101 73 - 126 0 97.0 81 - 120 MS Client ID: Analyte Sample ID: HS18120493-02MS Units: ug/L Analysis Date: 19-Dec-2018 16:10 Run ID: VOA6_329602 SeqNo: 4873750 Prep Date: OF: 2000 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 37840 99280 99520 102600 97440 10000 0 0 0 0 40000 100000 100000 100000 100000 0 94.6 70 - 127 0 99.3 70 - 126 0 99.5 82 - 124 0 103 77 - 123 0 97.4 82 - 127 Page 34 of 42 HFNA-000003126 EPA Inspection Report - Page 1577 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120510 Date: 20-Dec-18 QC BATCH REPORT Batch ID: R329602 Instrument: VOA6 Method; SW8260 MSD Client ID: Analyte Sample ID: HS18120493-02MSD Units: ug/L Analysis Date: 19-Dec-2018 16:34 Run ID: VOA6_329602 SeqNo: 4873751 Prep Date: OF: 2000 Result SPK Ref Control RPO Ref RPO PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1,2-0ichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 38390 97310 96520 101000 95850 10000 0 0 0 0 The following samples were analyzed in this batch: fS18120510-05 40000 100000 100000 100000 100000 HS 18120510-06 0 96.0 70 - 127 0 97.3 70 - 126 0 96.5 82 - 124 0 101 77 - 123 0 95.9 82 - 127 37840 99280 99520 102600 97440 1.43 20 2 20 3.06 20 1.58 20 1.65 20 Page 35 of 42 HFNA-000003127 EPA Inspection Report - Page 1578 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Annual Sampling HS18120510 Date: 20-Dec-18 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND O P R S U Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SOL TRRP Unit Reported mg/Kg mg/L Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is> 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL/SOL Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Description Milligrams per Kilogram Milligrams per Liter Page 36 of 42 HFNA-000003128 EPA Inspection Report - Page 1579 of 1969 ALS Houston, US Agency North Carolina Arkansas Texas North Dakota Illinois Louisiana Dept of Defense Kentucky Kansas Oklahoma Date: 20-Dec-18 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number 624-2018 88-0356 T10470231-18-21 R193 2018-2019 004438 03087 ANAB L2231 123043 - 2018 E-10352 2018-2019 2018-156 Expire Date 31-Dec-2018 27-Mar-2019 30-Apr-2019 30-Apr-2019 29-Jun-2019 30-Jun-2019 22-Dec-2018 30-Apr-2019 31-Jul-2019 31-Aug-2019 Page 37 of 42 HFNA-000003129 EPA Inspection Report - Page 1580 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Annual Sampling HS18120510 Lab Sarnp ID HS18120510-01 HS18120510-02 HS18120510-03 HS18120510-04 HS18120510-05 HS18120510-06 HS18120510-07 HS18120510-08 HS18120510-09 HS18120510-10 HS18120510-11 HS18120510-12 Client Sample ID D-2101 Desalter Water D-2101 Desalter HC D-130 Desalter Water D-130 Desalter HC D-482 Water P-185 Strainer Water T-401 ISOM T-401 Water T-401 Sump Water T-401 Sump Gasoline Blend D-180 Naptha 70-C-350 Naptha Date: 20-Dec-18 SAMPLE TRACKING Action Login Login Login Login Login Login Login Login Login Login Login Login Date 12/10/2018 5:58:35 PM 12/10/2018 5:58:35 PM 12/10/2018 5:58:35 PM 12/10/2018 5:58:35 PM 12/10/2018 5:58:35 PM 12/10/2018 5:58:35 PM 12/10/2018 5:58:35 PM 12/10/2018 5:58:35 PM 12/10/2018 5:58:35 PM 12/10/2018 5:58:35 PM 12/10/2018 5:58:35 PM 12/10/2018 5:58:35 PM Person JRM JRM JRM JRM JRM JRM JRM JRM JRM JRM JRM JRM New Location Sub Sub Sub Sub Sub Sub Sub Sub Sub Sub Sub Sub Page 38 of 42 HFNA-000003130 EPA Inspection Report - Page 1581 of 1969 ALS Houston, US Client Name: Work Order: Navajo Refining HS18120510 Date/Time Received: Received by: Date: 20-Dec-18 Sample Receipt Checklist 07-Dec-2018 10:00 JRM Checklist completed by: Jared R. Makan 1O-Dec-2018 -e,:-S,-ig_n_a,-tu-re-------...---,D=-a..,.t_e_ _ Reviewed by: Corey Grandits eSignature 12-Dec-2018 Date Matrices: Carrier name: ALS Courier Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Chain of custody present? Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? TX1005 solids received in hermetically sealed vials? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler( s )/Kit( s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Login Notes: f:;oc 2 of 2 not relinquished. Client Contacted: Date Contacted: Yes ~ Yes D Yes D Yes ~ Yes D Yes ~ Yes ~ Yes ~ Yes D Yes ~ Yes ~ Yes ~ 1.3c/1.6c UC/C oam cooler 12/10/2018 16:00 Yes 4 Yes D Yes D No D No D No D No D No ~ No D No D No D No D No D No D No D No No D No D Not Present D Not Present ~ Not Present ~ N/A ~ IR25 No VOA vials submitted N/A ~ N/A ~ Person Contacted: Contacted By: Comments: Regarding: Corrective Action: Page 39 of 42 HFNA-000003131 EPA Inspection Report - Page 1582 of 1969 A enuaranmental Chain of Custody Form Page _1_ of ......-2......_ ALS Project Manager: D 11 513 733 5336 Cincinnati, OH D Everett, WA + I 425 356 2600 D Fart Collins, CO +I 970490 15/1 D +16163996070 Holland, Ml D Houston, TX +1 2815305656 D Middletown, PA +17179445541 Work Order#: >): :{Ptoieii(~ajj:je BWON Annual Sampling A_ VOLATILES (8260) Benzene D +l 801 266 7100 Salt Lake City, UT D Spring Cit, PA + 1 610 948 4903 D York, PA +I 717 505 5280 >< ~ornpaiJY.N~nie Navajo Refining Company LLC : BiU)~C<im.pa:ny Holly Frontier Navajo Refining LLC >{ 1: :.:~ : :: . :ii; P.O. Box 159 , 1. 501 East Main , I>/ ~~ ~::.~> ~:. ~:, > ~ " ' - 4 - - - - - - - - - - - - - I : :: :: :F > C:ltyi~tat~lZ1p Artesia, NM 88211-0159 / ()jty/Sfat~iZip Artesia, New Mexico 88210 I : : <".'{'"'''"' (575) 148-3311 ,. <::: , :-- :...._(575J 145.3311 :H: : fait (575) 145.5451 ::> :: : F.~li (575) 145.5451 - HS18120510 - Navajo Refining Company - BWON Annual Sampling - - 1111111 IUII 1111111111ml 1111111 - : f D-2101 Desalter Water j:< D-2101 Desalter HC 3: D-130 Desalter Water 4 < D-130 Desalter HC : :S : D-482 Water 12/06118 10:59 AM Liquid 8 X 12/06/18 10:42AM Liquid 8 X 12/06/18 9:15AM Liquid 8 X 12/06118 8:54AM Liquid 8 X 12106118 9:29AM Liquid 1, 8 X 1. ~/ P-185 Strainer Water 1 f <T-401 ISOM 12106118 10:04 AM Liquid 8 X 12/05118 3:09 PM Liquid 8 X : / T-401 Water > :- T-401 Sump Water : HJ: T-401 Sump Gasoline Blend 12/05118 3:04PM Liquid 1, 8 X 12/05118 3:15 PM Liquid 1,8 X 12/05118 3:15PM Liquid 8 X . . }Shipment Method: FedEX . Required Turnaround Time: D STD 10 Wk Days 0 5 Wk Days Oother _ _ __ D 2 Wk Days D 24 Hour --- Relin9liished by: " Logged by (Laboratory): Date: Time: /? ti LJ. Date: Time: /3-/1/;f. /0 Date! ' Time: Received by: c------- Received by (Laboratory): ' Checked by (La~ratory): PreservativeKey: ,u-1c.1. 2;HN03 . J:.H2S04 . 4,.NaOH $-Na2S203 6-NaHS04 1-0ther 8-4-degreesC Note: Any changes must be made in writing once samples and COC Form have been submitted to ALS Laboratory Group. Notes: (?C F>alikag~:(Checik Elo~ Betoyq ::: : : .. Cooler.Temp. 1---'l'!"-"'!""!'-~--:-~~~---,,~~~~~~--t ,,-,,c: Level II: Standard QC ITRRP-Checklist I Level IV: SW846 CLP-Like Level Ill: Std QC+ Raw Data ITRRP level IV 9-5035 Other: Copyright 2009 by ALS Laboratory Group Page 40of 42 HFNA-000003132 EPA Inspection Report - Page 1583 of 1969 A Enuiranmental Chain of Custody Form Page _2_ of _.L__ ALS Project Manager: D +I 513 733 5336 Cincinnati, OH D Everett, WA + l 425 356 2600 D Fort Collins, CO +19704901511 D +16163996070 Holland, Ml D Houston, TX +I 2815305656 D Middletown, PA +I 717944 5541 Work Order#: <<<<: >Pr6J~i:ifName BWON Annual Sampling i{ VOLATILES (8260) Benzene ............. <:oin~an{Nanie Navajo Refining Company LLC < Bill:ti>~ri1J:1any Holly Frontier Navajo Refining LLC D +I 801 266 7700 Salt Lake City, UT D Spring City, PA +I 610 948 4903 D York, PA +I 717 505 5280 P.0.Box 159 : < : \ /iii! (575) 746-5451 e::M~H Ai:ldr~~s Gabriela Combs@hollyfrontier.com :-::..:.............ttU1:.n~r.,sr:n@gma1l.com 501 East Main [F : ):::ityJSfate/Zlp Artesia, New Mexico 88210 > <<i=:ax (575J 746-5451 [I . e~Mail Address .uzanne~e,gui!ar(dlhol!yfront,er com >) < D-180 Naptha < i : 70-C-350 Naptha f Field Blank <4: Trip Blank :~< EQ Blank Port 1 ~) EQ Blank Port 2 , 1:< EQ Blank Port 3 1 tF Duplicate [/9< Temperature Blank <10: ,. . : .. . Relinquished by: ,: .,.... ~$.fg,f { } 12/06/18 12/06/18 12/06/18 12/06118 12/06/18 12/06118 12/06118 12/05/18 12/06/18 11:30AM 8:50AM 9:27 AM XXX 1:30 PM 1:30 PM 1:30 PM JOO{f XXX <: :/. :<: > :: :: :: :\,Shipment Method: . } <> >: .. . < : FedEx Date: Time: Received by: Liquid 8 Liquid 8 1 Liquid 1, 8 1 Liquid 1, 8 2 Liquid 1, 8 Liquid 1,8 1 Liquid 1, 8 1 Liquid 8 Liquid I!Required Turnaround Time: D STD 10 Wk Days 0 5 Wk Days Notes: Relinquished by: Date: Time: Received by (Laboratory): Logged by (Laboratory): Date: Timi!: CMcked by (Labor11tory): . . .. . 2-HN03 3H2S04 4-NaOH 5-Na2S203 S::NaHS04 70ther .. . Note: Any changes must be made in writing once samples and COC Form have been submitted to ALS Laboratory Group. 9-5035 Page 41 of 42 - HS18120510 - Navajo Refining Company - BWON Annual Sampling - Ill III I II 111111111111111 - D Other _____ D 2 Wk Days D 24 Hour Level m: Std QC + Raw Data Level IV: SW846 CLP-Like ITRRP Level IV Other: Copyright 2009 by ALS Laboratory Group HFNA-000003133 EPA Inspection Report - Page 1584 of 1969 SHIPPER'S OE CLARA TION FOR DANGEROUS GOODS Shipper NAVAJO REFINING COMPANY CIO AQUA MICROBICS 501 E MAIN ARTESIA NM88210 US Consignee Corey Grandits ALS 10450 Stanciiff Suite 210 HOUSTON TX77099 US Two completed and signed copies of this f?eclaratjon must be handed to the operator (Provide at least three copies to airline.) Air Waybill No. 709308590718 Page 1 of 1 Page(s) ~ : x Shipper's Reference Number /optional) 18 Compliant Express CAFE3211 WARNING TRANSPORT OETAILS This shipment is within the limitations prescribed for: {delete non applicable) Airport of Departure ARTESIA ~ y r Airport of Destination: HOUSTON . ABSGRA Failure to comply with all respects with the applicable Dangerous Goods Regulations may be in breach of the applicable law ,subject to legal penalties. Shioment tvne: {delete non applicable) nw. NATURE AND QUANTITY OF DANGEROUS GOODS UN Number or identification Number, proper shippi r n e g qu n i a re m d e, ln C fo la n s n s a o tfo r n D . ivision (subsidiary risk), packing group (if required) and all other UN 1267, Petroleum crude oil.3,1/1 80 ml//361 UN 1268, Petroleum distillates, n.o.s.,3,ill// 160 ml/1366 UN 3082. Environmentally hazardous substance, liquid. n.o.s.{AMMONIA, 160 ml//964 All Packed In One FIBREBOARD BOX Q =0.1 ANHYDROUS, HYDROGEN SULFIOE),9,111// -A-d--d-it-i-o-n-a-laH--a-n-d-l-in-g--I-n-f-o-r-m--a-t-io-n-----------------------~-----------------------------------------------------------------..---------- 24 Hour Emergency Response- CHEM.rREC 1800-424-9300 CCN 201319 I hereby declare that the contents of this consignment are fully and accurately described above by the proper shipping name, and are classified, packaged, marked and labelled/placarded, and are in all respects in proper condition for transport according to applicable International and Nation.al Governmental Regulations. I declare that all of the applicable air transport requirements have been met. 18224249300 Em&rgem:y Telephone Number Name/Title of Signatory Brady Hubbard/Environmental Coordinator Place and Date Artesia NM 12/0612018 (See wamin9 abcv&} Signature sj;;;:o_~ ,,,,. __ / FOR RADIOACTIVE MATERIAL SHlPMENT ACCEPTABLE FOR PASSENGER AIRCRAFT, THE SHIPMENT CONTAINS RADIOACTIVE MATE:RIAL INTENDED FOR use IN OR INCIDENT TO RESEARCH, MEDICAL OIAGNOSlS OR TREATMENT. AOR EUROPEAN TRANSPORT STATEMENT: CARRIAGE JN ACCOF;:OANCE WITH 1.1.4,2.1 LOGO~;J-1572S:5 1111? Page 42 of 42 HFNA-000003134 EPA Inspection Report - Page 1585 of 1969 ATTACHMENT 7 - Provided in Enclosed CD NSPS SUBPART Ja EXCESS EMISSIONS Period: July-December 2018 (Paragraph 18 Appendix E) HFNA-000003135 EPA Inspection Report - Page 1586 of 1969 January 30. 2019 HOLL'lFRONTIER.. Enforcement Manager Ne,v Mexico Environment Departmelll 525 Camino de Los Marquez, Suite l Santa Fe, NM 87505 (\;_tificd Mail/Return -8,~;:,:tm 7015 0640 0006 6577 737 l Re: NSPS Subpart Ja CMS Excess .Emissions and Summary Reports Reporting Period 07/01/2018 to 12/31/2018 IIoHyFn:m.tier Navajo Refining LLC - Artesia, NM Refinery Agency Interest No. 198 HoLlyFrontier Navajo Refining LLC (Navajo) is submitting this semi-annual report for the Artesia, NM Refinery pursuant to the requirements of 40 CFR 60.7 (c), in NSPS Subpart /L Per Nl'vlED request on 08/05/2016, the reports for applicable NSPS Db, J, and .fa affected sources are being submitted individually. This report covers the sources subject to NSPS Subpart Ja, and includes a Data Summary Report, a Monitoring System Dmvntirne Report, and an Excess Emissions Report. The monitored source(s) are identified as: NSR Permit Source ID or Navajo Process Pollutant Equipment Unit RuJe Name Monitored Number Number TAG NSPS Ja . Boiler 9 NOx B-9 38 38AI001.PV - - - - - + - - - - - - + - - - - - - - - - -..-----+--------!------oHOOO_ _ __ _ , NSPS Ja ~~~i8ii~a~e~t I, I (H-2501) ___ .........J':'.!.(_)_x_ __,__~_l_2_5_0_1____2_5__.L:?.?.:~J0469C.DACAPV High i Pressure i 1 ,____N_S_P_S_J_a_-+-_~_\_:_~-~--~~;; .__.__I_{;_,S_ _+---_[_J._.()_7_7_0--t7............J........ Lmv 07 AlOO l.PV- -1 Pressure Refinery I NSPS Ja -f- _!:'1:!.:?.1-.D.f.1_s___H.cc_?.s_--j__o__-0_0.t?..............i........._..?.____ 07.AI002.PV SRU3 Tail I Gas 31 AJ426C .Di\CA.PV i ..........F.:!.?.!.:..~..}~-+--In_c_ir_H:_:ra_t_o_r_+-__.?.9)...............!._S_R_l_J_3_-T_{_~r_I-+--3_1_-+_3_1_Al425C.DACA.PV ~ Hydrocrack -0 2 for I ! NSPS Ja _e_r_R_e_b_o_il_e1_-+---_..li9.~......................... }~~3402 Unit 64 Hydrogen 34 .34Al0242.DACA.PV I ------------< I Plant J..... I , -0.!.~f..._:_af___R_e_"f_o_n_.n_t:1_--+---~.9.!............J__H_-<_J8_5' _1_--+-__o_4_ _i_6_.4_AYO l 06B.D ACA. PV J 1 11 .........N.~J.:.?..J~-~-N-(_;_"f_~t_a_:::_"__t~--..!.i/?.............. FL-400 55 I 55A1400AI .PV I HdlyFrnntier Navajo Refining LLC 501 F;:stMain Artesh, NM 88210 (575) 748-33 l l hr.tp:i iv,ww.hollvfrontier.com HFNA-000003136 EPA Inspection Report - Page 1587 of 1969 NSPS Subpart Ja January 30, 2019 I NSR Permit i Source ID or Navajo Process Pollutant Equipment Unit Rule N a m-e- - 1 -lV-fo-n-ito-r-ed- 4 -N- u-m- b-e-r - - -N1u-m-b-e r- - + - - - -T-A-G- - - - - - ' North Plant --N~;~~f~~-lf-Ja--n-t NSPS Ja -+--F--l_,or_\'.{_,1s1_t_~,--- ~------FF.l.L44{())(0_) ____)_-5_ __,___.._~,:?J1.9_(!B_l_.P_\_1_--i ~ ---N--S-+P-S--J-a----------F-lare----+.--.--,---+.,---I-------.................................+-5-5------;----5-5-F-Q~ I400A-.P-V- - - - ; South Plant NSPS Ja Flare - - - - - - + - - - - -....................1 South Plant \ }hS _.lil'S Ja Sm:J~~anl ,i,,,,,, TRS FL-401 55 ----, --- . F!.-40l +-~'? ,,__ _ 55Al401A1 .PV i ...................._ . ~ , 55AI401 BlYY,,, ,. ~ .-..... J'.'1:~J~?...1-.0..... Flare .._:......JJg.,.y~ate FL-401 +---2~............J.............. 55FQI401A_.PY..............J J...__ NSPS Ja FCC Flare ~....... NSP-~;~-.~-~:~: ~1_<1.i:~.... H,S I FL-402 i 55 I 55AI402ALPV ~;;;r.......... ~'L-~q.?_............1.............?..?..........r-~~~~~~021}..:LYV - i J NSPS Ja FCC Flare J Flowrnte !------ .. : -+- FLA02 I I I NSPS Ja Alkv Flare t"'. Flowrate FL-403 ---------------- --- ! 55 i 55FQI402A.PV . t . ---- 55 .. 55FQ1403A.PV NSPS Ja GOH Flare H2S FL-404 55 55Al404A1 .PV --------------+------+------------------<---~----"------< NSPS Ja GOH Flare ----------------------------- TRS FLA04 55 55AJ404Bl.PV ---------------+-------------i-------< NSPS Ja ......G.....O.....H.......-F-l~ar-e----FlowrateF..L -404 55 55FQI404A.PV Please note that 60. l 03a(h) exempts startup, shutdown, malfunction, and process upset gases, along with relief valve leakage, from the requireinent to meet the l 62 ppm (J-I:,,S) limiL In this report we have induded infonnation on these events we believe are subject to this provision and exemption, and have identified them as such. An /\ltemative Monitoring Plan (AMP) pursuant 40 CFR 60, 13(i)(6) was submitted on November 1 24 h, 2015 to the Envirnnrnental Protection Agency (EPA) requesting authorization to perform the required daily two-point CD validation and the two-point quarterly accuracy audits for the low measurement range of each SOLA II in order to validate the high measurement range perfonmrnce of the instrument as an alternative to the quality assurance procedures described in tj60. l 07a(e)(1 )(iii). An (AMP) pursuant to 40 CFR Part 60.13(i) for all New Source Performance Standards (NSPS) \Vas submitted on June 21, 2013 to the Environmental Protection A.gency (EPA) to cover the operation of Unit 34 Hydrocracker Reboiler I (H3402), which primmily uses purchased naturnl gas. Navajo repmts instances of bumiug refinery fuel gas in the attached report sheets. The FCC Flare (FL-402) and the North Plant Flare (FL-400} were previously part of an interconnected network of fiare headers, although they did not operate as interconnected flares. The Flare Management Plan (FMP) subrnitted on November 11, 2015 established the combined flow baseline for FL-400 (North Plant) and FL-402 (FCC) flares as 1,077,961. As of July 2017, the physical connection be1ween the flares headers was removed, and separate flow baseh111.~s 1vere established for each flare. The July 2017 FMP update establishes a new flow baseline of 162,000 SCF in any 24-hour period for FL-402 (FCC), and a uev1 How baseline of 624,000 SCF in any 24-hour period for FL-400 (NP). Per 40 CFR ::i60,103a(c)(l)(ii), the tlm::shold fi:)r a Root HollyFrontie, Navajo Refining LLC .501 East Main Artesia. NM 88210 (575) 748<l3 l l h@;/ /yJY;::WJrnllyJ:rn.ntigr..;-_q_:m HFNA-000003137 EPA Inspection Report - Page 1588 of 1969 NSJ'S Subpart Ja January 30, 2019 Cause Analysis and corrective action p!an is 662,000 SCF in any 24-hour period fr1r the FCC flare, and l ,124,000 SCF in a 24-hour period for the NP flare. The FJ'vlP submitted on November 1L 2015 established the baseline t1ow for the GOH Flare (FL404) to be 3,504,000 standard cubic feet per day (SCFD; where a day is any 24--hour period). Per 40 CFR 60. 103a(c )( 1){ ii), the threshold for an RCA and corrective action plan is 4,004,000 SCF in any 24-hour period. The June 2017 flare Management Plan update included an alternative f1ow baseline of 8,500,000 SCF in any 24-hour period for excess hydrogen flaring during outages of the hydrogen units (Unit 63 and 64), or hydrogen consumers. The threshold for a Root Cause Analysis and corrective action plan is 9,000,000 SCF in any 24--hour period. In accordance with 40 CFR 60.7(d), Tcertiiy based upon reasonable inquiry that the information contained in these reports is true, accurnte and as complete as practicable. Please contact Scott Denton (Fnvironn1entnl Manager) by phone at (575) 746-5487, by email at or at the address below if you have any questions about this subrnittaL Parrish Miller Vice President & Refinery Manager HollyFrnntier NavD,io Refining LLC Enclosure Ekctronic cc (wh;nci: Environmeml fik: P. Miller, B. Romine, S. Demon. G.Cc,mbs Eiiv\2.0 Air Qualiiy\2. 1 Original Agen,y Cmwqiomlence\20 i (I HoliyFrnntie, Navijo Rd'inhlg LLC 50 i East Ivta.in Artesia, NM 882 l 0 (575) 748-331 l htm://w,vw.hollyfront\er.co_m HFNA-000003138 EPA Inspection Report - Page 1589 of 1969 New Mexico Environment Department Air Quality .Bureau Compliance and Enforcement Section 525 Camino de los Marquez~ Suite I Santa Fe, NM 87505 Version 05.02.'!3 Pii<ms, (505) 476-43UO f:rn (SilS) -!7ii-4375 A::~J--------- NMED USE ONLY- -----------------i 1 - - - - NMED USE ONLY TEMPO I i REPORTING SUBMITTAL FOllM _______________________ I SECTION !-GENERAL COMPANY AND ,__---------------------- FACILITY INFORMATION A. Companv Name: --1--5:--Fac"ifitv Name: - -------------------------------------------- HoilyFrontier Navajo Refining U_.C -f:U @ Company Address: _______________________________________j__~-~1-~f-~l}~;~~:~~~e:tning I..LC -------------------------------------------------------- PO Box 159 ! 501 E_ Main St. i ------ --.--- - --------------------J,______________________________________ 1------------1 R2 City: f:U Stale: 18.4 Zip: ._ jl E.2 City: E.3 State: E.4 Zip: ____f::r.!~:.i_~-------------------- C.1 _ Company E1111iro _ 1 __ 1 _ m --~ e -r n v. t 1 a __ l __ C ___ o __ n __ tact: C.2 88211-015~~------------ Title: --------;I --l--~\_r~te-=-s F - , cciac---~- i cc----------------- Facility Contac -- t - : -------- _N_,,..,rv~1~~---~ F ! .2 Title: ~~-2.-~.?._____________, Scoti M_ Deniori Environmental Manager ii Scott M_ Denton Environmental Manager );-::fiifi"fihon-e-Niimber: ----------- ---c:-;f@ Fax Nmnber: --------------------------------tr.3 Phone Number: --------------------------- F.4 Fax Number: - ~;;(~d;~::1 ~=;~~~~__\__ 575-746-5487 575-746-545-1 ; 575-746-5487 575-746-5451 1 :i~r;~i~tier_com ----------------------------,~-=-::~-)t-~-d~-~-/-0'~-,@-:-~-~1-~:-:r-~-~,-ti:_r_com ___________ ---~---=----:=___-=_:-_=::::=-------=-------=-----=====--=-----=---=-----------------~ G_ Resoonsible Official: /Title Vo,=n-:l-~---,--:--==-r=-H-=.=-T-=it""1e=:====-=---~=====\'=1=.""'p-=11=o=ne~N-=u~rn=cb=e=r:m==--1 -I J. Fax Number: Vice President & Refinery ' I 575-746-5451 '==P=a=rr=is=l:=M,=i=ile=-r---------------- -------- _ --------- --t=~=ll=yF-=-r=o=nt=ie=r=~~=a=v=aJ=o- ==='l=57--5-748-33 -11 __________________ ---f(--ftSNumher:___ IL. Title V Perrriit"\i"umber: M. Title V PeriiiTi"Eis-ii"iibate: iN, NSR Permit Number: l 0. NSR Permit !ssue Date: 19s ______________________J__?.os-1-R2 _________________, 05/06/2015 ___________ !___.O._L?~_-l'v_13_-7_-.---.----------: ___ os11212015 ___________________ P. Reporting Period: l \ J From: 07/01/2018 To: 12/3i/2018 i SECTION!! - TYPE OF SUBMITTAL (check one ---DT_r_it-i~--V--A~-;~-~~-i--ccmpliance IPermit Co-nci"ition{s): A, Certification I RD .. Title V Semi-annual Monitoring Report IPermit Com.lition(s): ; Rei::wlation: c_ ~ NSPS Reqliirement (40CFR60) INSPS Subpart Ja that applies).............................. !Description: ' l iDescrii:ition: \ 'Section/s): 40 CFR 60_100a. '101a,102a, i03a, iO?a 1 108a D. D E. D I F.0 MACT Requirement (40CFR63) NMAC Requirement (20.2.xx) or NESHAP Requirement (40CFR61) Permit or Notice of !ntent (NO!) Requirement lReou!ation: Section isl: I I ReGu!ation: i Section(sl: i i Permit No.0: or NOi No,[]:[ Conciition{s): I I I ................ -------- . Description: NSPS Subpart ,ia Excess Emissions R.eport Descri otion: Descri otion: Description: G,0 I Requirement of an Enforcement Action NOV l'fa [J: or SFO No. [J: j Section(s): or CD No, 0: or Other [J: l Description: i SECTION IV CERT!FICAT!ON 11---------..............- ............................._ _ _ _ _ _ _ _ ----------- Parrish Milier certify that the information (nume of 1eporting olfalo!i Title: Vice President & Refinery I Manager, Hol!yFrontier Navajo Refining LLC -~ in this submittal is true, accurate and complete, ------ ------ ! Date Re~ponsible Oflidnl for Title V? I I Oi/30/2019 [ ] No Reviewed By: Date Reviewed: -----------------------------HFNA-000003139 EPA Inspection Report - Page 1590 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja Boiler B-0009 NOx Boiler B-0009 bums a mixture of purchased natural gas and refinery fuel gas. 60.lOOa Applicability, designation of affected facility, and reconstruction. (a) The provisions of this subpart apply to the following affected facilities in petroleum refineries: fluid catalytic cracking units (FCCU), fluid coking units (FCU), delayed coking units, fuel gas combustion devices (including process heaters), flares and sulfur recovery plants. The sulfur recovery plant need not be physically located within the boundaries of a petroleum refinery to be an affected facility, provided it processes gases produced within a petroleum refinery. (b) Except for flares and delayed coking units, the provisions of this subpart apply only to affected facilities under paragraph (a) of this section which commence construction, modification or reconstruction after May 14, 2007. 60.101a Definitions. Terms used in this subpart are defined in the Clean Air Act (CAA), in 60.2 and in this section. Fuel gas means any gas which is generated at a petroleum refinery and which is combusted. Fuel gas includes natural gas when the natural gas is combined and combusted in any proportion with a gas generated at a refinery. Fuel gas does not include gases generated by catalytic cracking unit catalyst regenerators, coke calciners (used to make premium grade coke) and fluid coking burners, but does include gases from flexicoking unit gasifiers and other gasifiers. Fuel gas does not include vapors that are collected and combusted in a thermal oxidizer or flare installed to control emissions from wastewater treatment units other than those processing sour water, marine tank vessel loading operations or asphalt processing units (i.e., asphalt blowing stills). Fuel gas combustion device means any equipment, such as process heaters and boilers, used to combust fuel gas. For the purposes of this subpart, fuel gas combustion device does not include flares or facilities in which gases are combusted to produce sulfur or sulfuric acid. Boiler B-0009 was constructed after May 14, 2007 and is a fuel gas combustion device. Therefore, B-0009 is subject to NSPS Subpart Ja 60.102a Emissions limitations. 60.102a(g) Each h owner or operator of an affected fuel gas combustion device shall comply with the emissions limits in paragraphs (g)(l) and (2) of this section. 60.102a(g)(2) For each process heater with a rated capacity of greater than 40 million British thermal units per hour (MMBtu/hr) on a higher heating value basis, the owner or operator shall not discharge to the atmosphere any emissions of NOx in excess of the applicable limits in paragraphs (g)(2)(i) through (iv) of this section. 60.102a(g)(2)(i) For each natural draft process heater, comply with the limit in either paragraph (g)(2)(i)(A) or (B) of this section. The owner or operator may comply with either limit at any time, provided that the appropriate parameters for each alternative are monitored as specified in 60.107a; iffuel gas composition is not monitored as specified in 60.107a(d), the owner or operator must comply with the concentration limits in paragraph (g)(2)(i)(A) of this section. 60.102a(g)(2)(i)(A) 40 ppmv (dry basis, corrected to 0-percent excess air) determined daily on a 30-day rolling average basis; or HFNA-000003140 EPA Inspection Report - Page 1591 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. 60.107a(c) Process heaters complying with the NOx concentration-based limit. The owner or operator of a process heater subject to the NOx emissions limit in 60.102a(g)(2) and electing to comply with the applicable emissions limit in 60.102a(g)(2)(i)(A), (g)(2)(ii)(A), (g)(2)(iii)(A) or (g)(2)(iv)(A) shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration (dry basis, 0-percent excess air) of NOx emissions into the atmosphere according to the requirements in paragraphs (c)(l) through (5) of this section, except as provided in paragraph (c)(6) of this section. The monitor must include an 02 monitor for correcting the data for excess air. The NOx CEMS on Boiler B-0009 records concentrations in parts per million by volume on a dry basis (ppmvd). The NOx concentrations are corrected to 0-percent excess air using the oxygen monitor concentrations. 60.108a(d) Each owner or operator subject to this subpa1i shall submit an excess emissions report for all periods of excess emissions according to the requirements of 60.7(c) except that the report shall contain the information specified in paragraphs (d)(l) through (7) of this section. (1) The date that the exceedance occurred; (2) An explanation of the exceedance; (3) Whether the exceedance was concurrent with a startup, shutdown, or malfunction of an affected facility or control system; and (4) A description of the action taken, if any. (5) The information described in paragraph (c)(6) of this section for all discharges listed in paragraph (c)(6) of this section. For a flare complying with the monitoring alternative under 60.107a(g), following the fifth discharge required to be recorded under paragraph (c)(6) of this section and reported under this paragraph, the owner or operator shall include notification that monitoring systems will be installed according to 60.107a(e) and (f) within 180 days following the fifth discharge. (6) For any periods for which monitoring data are not available, any changes made in operation of the emission control system during the period of data unavailability which could affect the ability of the system to meet the applicable emission limit. Operations of the control system and affected facility during periods of data unavailability are to be compared with operation of the control system and affected facility before and following the period of data unavailability. (7) A written statement, signed by a responsible official, certifying the accuracy and completeness of the information contained in the report. With this report, Navajo is submitting all periods of excess emissions according to the requirements of 60.7(c) and 60.108a(d)(l)-(7). HFNA-000003141 EPA Inspection Report - Page 1592 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report Boiler B-0009 B-0009 NOx CEMS Summary Affected Source Emission Limit Citation Emission Limitation (NOx ppmv) B-0009 40 CFR 60.102a(g)(2)(i) 40 Monitor Manufacturer and Model No. Monitor Serial Number Initial Compliance Test Scheduled California Analytical, 600CLO Digital A 10011 03/07/2018 Reporting Period Beginning Date Reporting Period Ending Date 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime (Fuel gas flow to B-0009 less than zero) Total Source Operating Time in Reporting Period (hours) (hours) (hours) 4416 1 4415 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Unknown Causes Number of Incidents 1 0 184 2 0 Duration (Hours) 2.00 0.00 0.00 2.00 0.00 Totals 187 Total CMS Downtime as a Percent of Total Source OperatinQ Time 4.00 0.09% Emission Data Summary (Exceeds 30-Day rolling average of 0.2 lb NOx/MMBtu) Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Unknown Causes Totals Total Duration of Deviations as a Percent of Total Source Operating Time Number of Incidents 0 0 0 0 0 0 0 Duration (Hours) 0 0 0 0 0 0 0 0.00% HFNA-000003142 EPA Inspection Report - Page 1593 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report Boiler B-0009 B-0009 NOx GEMS Downtime GEMS Downtime Affected Source Name Monitor Type B-0009 GEMS B-0009 GEMS Monitored HAP or Gas Downtime Start Dale and Time Downtime End Dale and Time Duration of Downtime (hours) Type of Downtime Type of Cause of Period Deviation Brief Description of Cause of Downtime NOx 08/14/2018 13:30 08/14/2018 15:05 1.00 Other Known Cause Other The analyzer was placed in maintenance mode to perform a CGA. NOx 08/30/2018 08:20 08/30/2018 11 :20 2.00 Monitor Equipment Malfunction The analyzer was placed in maintenance Malfunction mode due to a sample chiller malfunction. B-0009 GEMS NOx 12/05/2018 14:00 12/05/2018 15:10 Total 1.00 4.00 Other Known Cause Other The analyzer was placed in maintenance mode to perform a CGA. Corrective Action Taken The l&E technician performed a CGA and returned the analyzer to service. The l&E technician replaced the chiller and returned the analyzer to service. The l&E technician performed a CGA and returned the analyzer to service. HFNA-000003143 EPA Inspection Report - Page 1594 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery CEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions Start Date and Time Excess Emissions End Date and Time B-0009 CEMS NOx NA NA Total NSPS Subpart Ja Periodic Report Boiler B-0009 B-0009 CEMS Excess Emissions Ja Duration of Deviation (hours) Excess Duration of Emissions excess emissions Occurred in reporting period During Period of due to: Brief Description of Nature and Cause of Excess Emission Corrective Action Taken or Preventative Measure Adopted No deviations - Boiler B-0009 did not record any NA NA NA deviations above the NSPS Ja 30-Day rolling NA average of 40 ppmv at 0% 0 2 limit. 0:00 HFNA-000003144 EPA Inspection Report - Page 1595 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja HeaterH-2501 NOx Heater H-2501 burns a mixture of purchased natural gas and refinery fuel gas. 60.lOOa Applicability, designation of affected facility, and reconstruction. (a) The provisions of this subpart apply to the following affected facilities in petroleum refineries: fluid catalytic cracking units (FCCU), fluid coking units (FCU), delayed coking units, fuel gas combustion devices (including process heaters), flares and sulfur recovery plants. The sulfur recovery plant need not be physically located within the boundaries of a petroleum refinery to be an affected facility, provided it processes gases produced within a petroleum refinery. (b) Except for flares and delayed coking units, the provisions of this subpart apply only to affected facilities under paragraph (a) of this section which commence construction, modification or reconstruction after May 14, 2007. 60.101a Definitions. Terms used in this subpart are defined in the Clean Air Act (CAA), in 60.2 and in this section. Fuel gas means any gas which is generated at a petroleum refinery and which is combusted. Fuel gas includes natural gas when the natural gas is combined and combusted in any proportion with a gas generated at a refinery. Fuel gas does not include gases generated by catalytic cracking unit catalyst regenerators, coke calciners (used to make premium grade coke) and fluid coking burners, but does include gases from flexicoking unit gasifiers and other gasifiers. Fuel gas does not include vapors that are collected and combusted in a thermal oxidizer or flare installed to control emissions from wastewater treatment units other than those processing sour water, marine tank vessel loading operations or asphalt processing units (i.e., asphalt blowing stills). Fuel gas combustion device means any equipment, such as process heaters and boilers, used to combust fuel gas. For the purposes of this subpart, fuel gas combustion device does not include flares or facilities in which gases are combusted to produce sulfur or sulfuric acid. Heater H-2501 was constmcted after May 14, 2007 and is a fuel gas combustion device. Therefore, H-2501 is subject to NSPS Subpart Ja 60.102a Emissions limitations. 60.102a(g) Each h owner or operator of an affected fuel gas combustion device shall comply with the emissions limits in paragraphs (g)(l) and (2) of this section. 60.102a(g)(2) For each process heater with a rated capacity of greater than 40 million British thermal units per hour (MMBtu/hr) on a higher heating value basis, the owner or operator shall not discharge to the atmosphere any emissions of NOx in excess of the applicable limits in paragraphs (g)(2)(i) through (iv) of this section. 60.102a(g)(2)(i) For each natural draft process heater, comply with the limit in either paragraph (g)(2)(i)(A) or (B) of this section. The owner or operator may comply with either limit at any time, provided that the appropriate parameters for each alternative are monitored as specified in 60.107a; iffuel gas composition is not monitored as specified in 60.107a(d), the owner or operator must comply with the concentration limits in paragraph (g)(2)(i)(A) of this section. 60.102a(g)(2)(i)(A) 40 ppmv (dry basis, corrected to 0-percent excess air) determined daily on a 30-day rolling average basis; or HFNA-000003145 EPA Inspection Report - Page 1596 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. 60.107a(c) Process heaters complying with the NOx concentration-based limit. The owner or operator of a process heater subject to the NOx emissions limit in 60.102a(g)(2) and electing to comply with the applicable emissions limit in 60.102a(g)(2)(i)(A), (g)(2)(ii)(A), (g)(2)(iii)(A) or (g)(2)(iv)(A) shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration (dry basis, 0-percent excess air) of NOx emissions into the atmosphere according to the requirements in paragraphs (c)(l) through (5) of this section, except as provided in paragraph (c)(6) of this section. The monitor must include an 0 2 monitor for correcting the data for excess air. The NOx CEMS on Heater H-250 l records concentrations in parts per million by volume on a dry basis (ppmvd). The NOx concentrations are corrected to 0-percent excess air using the oxygen monitor concentrations. 60.108a(d) Each owner or operator subject to this subpa1i shall submit an excess emissions report for all periods of excess emissions according to the requirements of 60.7(c) except that the report shall contain the information specified in paragraphs (d)(l) through (7) of this section. (1) The date that the exceedance occurred; (2) An explanation of the exceedance; (3) Whether the exceedance was concurrent with a startup, shutdown, or malfunction of an affected facility or control system; and (4) A description of the action taken, if any. (5) The information described in paragraph (c)(6) of this section for all discharges listed in paragraph (c)(6) of this section. For a flare complying with the monitoring alternative under 60.107a(g), following the fifth discharge required to be recorded under paragraph (c)(6) of this section and reported under this paragraph, the owner or operator shall include notification that monitoring systems will be installed according to 60.107a(e) and (f) within 180 days following the fifth discharge. (6) For any periods for which monitoring data are not available, any changes made in operation of the emission control system during the period of data unavailability which could affect the ability of the system to meet the applicable emission limit. Operations of the control system and affected facility during periods of data unavailability are to be compared with operation of the control system and affected facility before and following the period of data unavailability. (7) A written statement, signed by a responsible official, certifying the accuracy and completeness of the information contained in the report. With this report, Navajo is submitting all periods of excess emissions according to the requirements of 60.7(c) and 60.108a(d)(l)-(7). HFNA-000003146 EPA Inspection Report - Page 1597 of 1969 HollyFron!ier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report Heater H-2501 H-2501 NOx CEMS Summary Affected Source Emission Limit Citation Emission Limitation (NOx ppmv) Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit Reporting Period Beginning Date Reporting Period Ending Date H-2501 40 CFR 60.102a(g)(2)(i) 40 Thermo Scientific 48iANPCB 809828981 01/10/2018 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime (Fuel gas flow to H-2501 less than zero) Total Source Operating Time in Reporting Period (hours) (hours) (hours) 4416 173 4243 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Unknown Causes Totals Total CMS Downtime as a Percent of Total Source Operating Time Number of Incidents 0 0 177 1 0 178 Duration (Hours) 0.00 0.00 0.00 2.00 0.00 2.00 0.05% Emission Data Summary (Exceeds 30-Day rolling average of 40 ppmv NOx limit.) Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Unknown Causes Totals Total Duration of Deviations as a Percent of Total Source Operating Time Number of Incidents 0 0 0 0 0 0 0 Duration (Hours) 0 0 0 0 0 0 0 0.00% HFNA-000003147 EPA Inspection Report - Page 1598 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report Heater H-2501 H-2501 NOx CEMS Downtime CEMS Downtime Affected Source Name Monitor Type Monitored HAP or Gas Downtime Start Date and Time Downtime End Date and Time Duration of Downtime (hours) Type of Downtime Period Type of Cause of Deviation Brief Description of Cause of Downtime Corrective Action Taken H-2501 CEMS NOx 08/20/2018 09:57 08/20/2018 11 :47 Total 2.00 2.00 Other Known Cause Other The analyzer was placed in maintenance The E&I technician performed the CGA and mode to perform a CGA. returned the analyzer to service. HFNA-000003148 EPA Inspection Report - Page 1599 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report Heater H-2501 H-2501 CEMS Excess Emissions CEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored Excess Emissions HAP or Gas Start Date and Time Excess Emissions End Date and Time Duration of Deviation (hours) Excess Emissions Occurred During Period of Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission Corrective Action Taken or Preventative Measure Adopted H-2501 CEMS NOx NA No deviations - Heater H-2501 did not record NA NA NA NA any deviations above the NSPS Ja 30-Day NA rolling average of 40 ppmv limit. HFNA-000003149 EPA Inspection Report - Page 1600 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery NSPS Subpart Ja High Pressure Refinery Fuel Gas Drum D-0770 According to 60.102a Emissions limitations. (g) Each owner or operator of an affected fuel gas combustion device shall comply with the emission limits in paragraphs (g)(l) through (3) of this section. (1) For each fuel gas combustion device, the owner or operator shall comply with either the emission limit in paragraph (g)(l)(i) of this section or the fuel gas concentration limit in paragraph (g)(l)(ii) of this section. (ii) The owner or operator shall not burn in any fuel gas combustion device any fuel gas that contains H2S in excess of 162 ppmv determined hourly on a 3-hour rolling average basis and H2S in excess of 60 ppmv determined daily on a 365 successive calendar day rolling average basis. And 60.107a Monitoring of emissions and operations for fuel gas combustion devices. (f) Excess emissions. For the purpose of reports required by 60.7(c), periods of excess emissions for fuel gas combustion devices subject to the emissions limitations in 60.102a(g) are defined as specified in paragraphs (f)(l) through (4) of this section. Note: Determine all averages as the arithmetic average of the applicable 1-hour averages, e.g., determine the rolling 3-hour average as the arithmetic average of three contiguous 1-hour averages. (2) All rolling 3-hour periods during which the average concentration of H2S as measured by the H2S continuous monitoring system required under paragraph (a)(2) of this section exceeds 162 ppmv, all days in which the concentration of H2S as measured by daily stain tube sampling required under paragraph (b)(3)(iii) of this section exceeds 162 ppmv, and all rolling 365-day periods during which the average concentration as measured by the H2S continuous monitoring system under paragraph (a)(2) of this section exceeds 60 ppmv. 60.108a(d) Each owner or operator subject to this subpart shall submit an excess emissions report for all periods of excess emissions according to the requirements of 60.7(c) except that the report shall contain the information specified in paragraphs (d)(l) through (7) of this section. (1) The date that the exceedance occurred; (2) An explanation of the exceedance; (3) Whether the exceedance was concurrent with a startup, shutdown, or malfunction of an affected facility or control system; and (4) A description of the action taken, if any. (5) The information described in paragraph (c)(6) of this section for all discharges listed in paragraph (c)(6) of this section. For a flare complying with the monitoring alternative under 60.107a(g), following the fifth discharge required to be recorded under paragraph (c)(6) of this section and repo1ied under this paragraph, the owner or operator shall include notification that monitoring systems will be installed according to 60.107a(e) and (f) within 180 days following the fifth discharge. (6) For any periods for which monitoring data are not available, any changes HFNA-000003150 EPA Inspection Report - Page 1601 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery made in operation of the emission control system during the period of data unavailability which could affect the ability of the system to meet the applicable emission limit. Operations of the control system and affected facility during periods of data unavailability are to be compared with operation of the control system and affected facility before and following the period of data unavailability. (7) A written statement, signed by a responsible official, certifying the accuracy and completeness of the information contained in the report. With this report, Navajo is submitting all periods of excess emissions according to the requirements of 60.7(c) and 60.108a(d)(l)-(7). HFNA-000003151 EPA Inspection Report - Page 1602 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report for D-0770 D-0770 H2S CMS Summary High Pressure Fuel Balance Affected Source Drum D-0770 Emission Limit Citation 40 CFR 60.102a(g)(1)(ii) Emission Limitation (ppmv H2S) 162 Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit SpectraSensor 882100 11002 02/15/2018 Reporting Period Beginning Date Reporting Period Ending Date 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime (hours) (hours) 4416 0 Total Source Operating Time in Reporting Period (hours) 4416 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Totals Total CMS Downtime as a Percent of Total Source Operating Time Number of Incidents 1 1 184 0 0 186 Duration (Hours) 28.00 13.00 0.00 0.00 0.00 41.00 0.93% Emission Data Summary (Exceeds 3-hour rolling average of 162 ppmv H2S) Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Totals Total Duration of Deviations as a Percent of Total Source Operating Time Number of Incidents 0 0 0 3 1 1 5 Duration (Hours) 0 0 0 15 4 3 22 0.50% HFNA-000003152 EPA Inspection Report - Page 1603 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report D-0770 GEMS Downtime Affected Source Name Monitor Type Monitored HAP or Gas Downtime Start Date and Time Downtime End Date and Time Duration of Downtime (hours) Type of Downtime Period Type of Cause of Deviation Brief Description of Cause of Downtime D-0770 GEMS Downtime Corrective Action Taken D-0770 GEMS H2S 07/09/2018 06:12 07/10/2018 09:23 28.00 Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode The l&E technician validated the calibration due to failed calibration. and returned the analyzer to service. D-0770 GEMS H2S 09/24/2018 05:00 09/24/201818:00 13.00 Total 41.00 Non-Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode The l&E technician reset controller, due to a power failure which caused the recalibrated, and returned the analyzer to calibration not to occur on time. service. HFNA-000003153 EPA Inspection Report - Page 1604 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report for D-0770 D-0770 Excess Emissions CEMS Monitored Excess Emissions Affected Source Name D-770 D-770 D-770 Monitor Type CEMS CEMS CEMS Monitore d HAP or Gas H2S H2S H2S Excess Emissions Start Date and Time 07/19/20181500 08/26/2018 14 00 09/23/2018 21 00 Excess Emissions End Date and Time 07/19/2018 17 00 08/26/2018 17 00 09/24/2018 01 00 Duration of Excess Emissions Deviation Occurred During (hours) Period of 2.00 Ma Ifunction 3.00 Ma Ifunction 4.00 Other Duration of excess emissions in Brief Description of Nature and Cause of Excess reporting period Emission due to: 1ne Amine un1i H1gn r'ressure Gomacmr oecame Process Problems saturated with H2S, causing the concentration of this gas in the Fuel Gas System (FGS) to exceed the reportable "-" High concertation of H2S in the FGS reduced the Amine Other Unknown Unit High Pressure Contactor H2S scrubbing efficiency. Cause Upon investigation, no known cause could be determined. The electrical power supply from a third party substation to the Artesia Refinery was interrupted for approximately Other Known Cause 3 hours, resulting in the shutdown of several process units, as well as several pumps, compressors and other electric pieces of equipment within the refinery, followed by the increase of the FGS H2S concentration above the reportable limit Corrective Action Taken or Preventative Measure Adopted Amine flow to the contactor was increased and the overhead temperature was reduced to increase the H2S scrubbing efficiency. No adjustments were made. The H2S concentration in the fuel gas system decreased enough to allow the 3hour rolling average to drop under 162 ppmvd. After the electrical power was restored, the amine scrubbing system returned to service and began removing H2S from the fuel gas system D-0770 CEMS H2S 10/01/2018 12 00 10/01/2018 21 00 9.00 Ma Ifunction Process Problems Due to the increase in temperatures in the Mild Hydrocracker Unit (MHC) and Fluid Catalytic Cracking (FCC, Unit 10), increased off-gas productions from these units rapidly increased the H2S concentration in the FGS above the regulatory limit. MHC and FCC process temperatures were adjusted, to help reduce the acid gas production and the H2S concentration in the off gas treated in the amine units. New amine solution was introduced in the amine unit system to help increase the removal rate of H2S in the FGS. D-0770 CEMS H2S 12/07/2018 21 00 12/08/2018 01 00 4.00 Total 22.00 Ma Ifunction The H2S concentration in the FGS increased following an Process Problems unexpected shutdown of the Sulfur Recovery Unit No.2 (SRU2) Operations added H2S scavenger to the the system to help reduce the concentration of this gas below the regulatory limit HFNA-000003154 EPA Inspection Report - Page 1605 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery According to NSPS Subpart Ja Low Pressure Refinery Fuel Gas Dmm D-0019 60.102a Emissions limitations. (g) Each owner or operator of an affected fuel gas combustion device shall comply with the emission limits in paragraphs (g)(l) through (3) of this section. (1) For each fuel gas combustion device, the owner or operator shall comply with either the emission limit in paragraph (g)(l)(i) of this section or the fuel gas concentration limit in paragraph (g)(l)(ii) of this section. (ii) The owner or operator shall not burn in any fuel gas combustion device any fuel gas that contains H2S in excess of 162 ppmv determined hourly on a 3-hour rolling average basis and H2S in excess of 60 ppmv determined daily on a 365 successive calendar day rolling average basis. 60.107a Monitoring of emissions and operations for fuel gas combustion devices. (t) Excess emissions. For the purpose of reports required by 60.7(c), periods of excess emissions for fuel gas combustion devices subject to the emissions limitations in 60.102a(g) are defined as specified in paragraphs (f)(l) through (4) of this section. Note: Determine all averages as the arithmetic average of the applicable 1-hour averages, e.g., determine the rolling 3-hour average as the arithmetic average of three contiguous 1-hour averages. (2) All rolling 3-hour periods during which the average concentration of H2S as measured by the H2S continuous monitoring system required under paragraph (a)(2) of this section exceeds 162 ppmv, all days in which the concentration of H2S as measured by daily stain tube sampling required under paragraph (b)(3)(iii) of this section exceeds 162 ppmv, and all rolling 365-day periods during which the average concentration as measured by the H2S continuous monitoring system under paragraph (a)(2) of this section exceeds 60 ppmv. 60.108a(d) Each owner or operator subject to this subpart shall submit an excess emissions report for all periods of excess emissions according to the requirements of 60.7(c) except that the report shall contain the information specified in paragraphs (d)(l) through (7) of this section. (1) The date that the exceedance occurred; (2) An explanation of the exceedance; (3) Whether the exceedance was concurrent with a startup, shutdown, or malfunction of an affected facility or control system; and (4) A description of the action taken, if any. (5) The information described in paragraph (c)(6) of this section for all discharges listed in paragraph (c)(6) of this section. For a flare complying with the monitoring alternative under 60.107a(g), following the fifth discharge required to be recorded under paragraph (c)(6) of this section and reported under this paragraph, the owner or operator shall include notification that monitoring systems will be installed according to 60.107a(e) and (f) within 180 days following the fifth discharge. Page 1 of2 HFNA-000003155 EPA Inspection Report - Page 1606 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery (6) For any periods for which monitoring data are not available, any changes made in operation of the emission control system during the period of data unavailability which could affect the ability of the system to meet the applicable emission limit. Operations of the control system and affected facility during periods of data unavailability are to be compared with operation of the control system and affected facility before and following the period of data unavailability. (7) A written statement, signed by a responsible official, certifying the accuracy and completeness of the information contained in the report. With this report, Navajo is submitting all periods of excess emissions according to the requirements of 60.7(c) and 60.108a(d)(l)-(7). Page 2 of2 HFNA-000003156 EPA Inspection Report - Page 1607 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report D-0019 D-0019 H2S CMS Summary Affected Source Emission Limit Citation Emission Limitation (ppmv H2S) Low Pressure Fuel Balance Drum D-0019 40 CFR 60.102a (g)(1)(ii) 162 Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit SpectraSensor SS2100 11003 03/06/2018 Reporting Period Beginning Date Reporting Period Ending Date 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime (hours) (hours) 4416 0 Total Source Operating Time in Reporting Period (hours) 4416 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Totals Total CMS Downtime as a Percent of Total Source Operating Time Number of Incidents 0 0 184 0 0 184 Duration (Hours) 0.00 0.00 0.00 0.00 0.00 0.00 0.00% Emission Data Summary (Exceeds 3-hour rolling average of 162 ppmv H2S) Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Totals Number of Incidents 0 0 0 3 1 0 4 Duration (Hours) 0 0 0 12 5 0 17 Total Duration of Deviations as a Percent of Total Source Operating Time 0.38% HFNA-000003157 EPA Inspection Report - Page 1608 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report D-0019 CEMS Downtime Affected Source Name Monitor Type Monitored HAP or Gas Downtime Start Date and Time D-0019 CEMS H2S NA Downtime End Date and Time NA Total Duration of Downtime (hours) Type of Downtime Period NA NA 0.00 Type of Cause of Deviation Brief Description of Cause of Downtime No Downtime - There was no downtime recorded for this CEMS during this reporting period. D-0019 GEMS Downtime Corrective Action Taken NA HFNA-000003158 EPA Inspection Report - Page 1609 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report D-0019 D-0019 Excess Emissions CEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions Start Date and Time Duration of Excess Excess Emissions Deviation Emissions End Date and Time (hours) Occurred During Period of Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission Corrective Action Taken or Preventative Measure Adopted D-0019 CEMS H2S 09/23/2018 21 00 09/24/2018 02 00 5.00 Other Other Known Cause The electrical power supply from a third party substation to the Artesia Refinery was interrupted for approximately 3 hours, resulting in the shutdown of several process units, as well as several pumps, compressors and other electric pieces of equipment within the refinery, followed by the increase of the FGS H2S concentration above the reportable limit After the electrical power was restored, the amine scrubbing system returned to service and began removing H2S form the fuel gas system. D-0019 CEMS H2S 12/07/2018 21 00 12/08/2018 01 00 4.00 Malfunction Process Problems The H2S concentration in the FGS increased following an unexpected shutdown of the Sulfur Recovery Unit No.2 (SRU2) Operations added H,S scavenger to the system to help reduce the concentration of this gas below the regulatory limit D-0019 CEMS H2S 12/15/2018 15 00 12/15/2018 20 00 5.00 Malfunction Process Problems The H2S concentration in the FGS increased following an Operations made adjustments and restarted SRU2. unexpected shutdown of SRU2. The FGS scrubbing system Operators waited for the 3 hour averages to drop below was contaminated and was not properly removing fiS. permitted limits. D-0019 CEMS H2S 12/31/2018 11 00 12/31/20181400 3.00 Total 17.00 Malfunction Process Problems The H2S concentration in the FGS increased following an Operations made adjustments and restarted SRU2, and unexpected shutdown of SRU2. The FGS scrubbing system waited for the 3 hour averages to drop below permitted was contaminated and was not properly removing fiS. limits. HFNA-000003159 EPA Inspection Report - Page 1610 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery According to: 60.102a Emissions limitations. NSPS Subpart Ja SRU3 Tail Gas Incinerator (f) Each owner or operator of an affected sulfur recovery plant shall comply with the applicable emission limits in paragraphs (f)(l) of this section. (1) For a sulfur recovery plant with a capacity greater than 20 long tons per day (LTD): (i) For a sulfur recovery plant with an oxidation control system or a reduction control system followed by incineration, the owner or operator shall not discharge or cause the discharge of any gases into the atmosphere in excess of 250 ppm by volume (dry basis) of sulfur dioxide (S02) at zero percent excess air. If the sulfur recovery plant consists of multiple process trains or release points the owner or operator shall comply with the 250 ppmv limit for each process train or release point or comply with a flow rate weighted average of 250 ppmv for all release points from the sulfur recovery plant And 60.106a Monitoring of emissions and operations for sulfur recovery plants. (b) Excess emissions. For the purpose of reports required by 60.7(c), periods of excess emissions for sulfur recovery plants subject to the emissions limitations in 60.102a(f) are defined as specified in paragraphs (b)(l) through (3) of this section. Note: Determine all averages as the arithmetic average of the applicable 1-hour averages, e.g., determine the rolling 12-hour average as the arithmetic average of 12 contiguous 1-hour averages. (1) All 12-hour periods during which the average concentration of S02 as measured by the S02continuous monitoring system required under paragraph (a)(l) of this section exceeds the applicable emission limit (dry basis, zero percent excess air); SRU3 is a 3-stage Claus Sulfur Recovery Units, followed by a reduction control system (the Tail Gas Treating Unit), and Incineration. Therefore, the SRU3 Tail Gas Incineration stack has a continuous emissions monitoring system (CEMS) for continuously monitoring and recording the concentration (dry basis, zero percent excess air) of S02 emissions into the atmosphere. The monitor shall include an oxygen monitor for correcting the data for excess air. Therefore, any deviations are based on 12-hour rolling averages where the S02 concentration exceeds 250 ppmvd corrected to 0% oxygen. 60.108a(d) Each owner or operator subject to this subpa1i shall submit an excess emissions report for all periods of excess emissions according to the requirements of 60.7(c) except that the report shall contain the information specified in paragraphs (d)(l) through (7) of this section. (1) The date that the exceedance occurred; (2) An explanation of the exceedance; (3) Whether the exceedance was concurrent with a startup, shutdown, or malfunction of an affected facility or control system; and (4) A description of the action taken, if any. HFNA-000003160 EPA Inspection Report - Page 1611 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery (5) The information described in paragraph (c)(6) of this section for all discharges listed in paragraph (c)(6) of this section. For a flare complying with the monitoring alternative under 60.107a(g), following the fifth discharge required to be recorded under paragraph (c)(6) of this section and reported under this paragraph, the owner or operator shall include notification that monitoring systems will be installed according to 60.107a(e) and (f) within 180 days following the fifth discharge. (6) For any periods for which monitoring data are not available, any changes made in operation of the emission control system during the period of data unavailability which could affect the ability of the system to meet the applicable emission limit. Operations of the control system and affected facility during periods of data unavailability are to be compared with operation of the control system and affected facility before and following the period of data unavailability. (7) A written statement, signed by a responsible official, certifying the accuracy and completeness of the information contained in the repo1i. With this report, Navajo is submitting all periods of excess emissions according to the requirements of 60.7(c) and 60.108a(d)(l)-(7). HFNA-000003161 EPA Inspection Report - Page 1612 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report SRU3TGIS02 CEMSSumma~ Affected Source Emission Limit Citation Emission Limitation (ppmv S02) SRU3 TGI 40 CFR 60.104(a)(2)(i) 250 Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit Reporting Period Beginning Date Reporting Period Ending Date Total Time in Reporting Period Total Source Downtime (Time with no tail gas feed to the Incinerator, SRU3 down) Total Source Operating Time in Reporting Period California Analytical ZRE A8K9291T 03/21/2018 07/01/2018 12/31/2018 (hours) 4416 (hours) 4 (hours) 4412 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Number of Incidents 4 0 184 2 0 Duration (Hours) 64.00 0.00 0.00 3.00 0.00 Totals 190 Total CMS Downtime as a Percent of Total Source Operating Time 67.00 1.52% Emission Data Summary (Exceeds 250 ppmvd S02 corrected to 0% 0 2 on a 12-hour rolling average) Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Totals Number of Incidents 0 0 0 0 0 0 0 Duration (Hours) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Total Duration of Deviations as a Percent of Total Source Operating Time 0.00% HFNA-000003162 EPA Inspection Report - Page 1613 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report CEMS Downtime Affected Monitor Monitore Source Type d HAP Name or Gas Downtime Start Date and Time Downtime End Date and Time Duration of Downtime (hours) Type of Downtime Period Type of Cause of Deviation Brief Description of Cause of Downtime SRU3 S02 CEMS Downtime Corrective Action Taken SRU3 CEMS S02 08/13/2018 13:30 08/13/2018 15:10 1.00 Other Known Cause Other The analyzer was placed in maintenance mode to The l&E technician performed a CGA and returned the perform a CGA. analyzer to service. Monitor Equipment The analyzer was placed in maintenance mode The l&E technician steamed out the sample line and probe SRU3 CEMS S02 08/31/2018 13:50 08/31/2018 15:10 1.00 Malfunction Malfunction due to high vacuum in sample line. assembly lo reduce the vacuum and returned the analyzer to service. SRU3 CEMS S02 12/04/2018 13:05 12/04/2018 14:45 2.00 Other Known Cause Other The analyzer was placed in maintenance mode to The l&E technician performed a CGA and returned the perform a CGA. analyzer to service. SRU3 CEMS S02 12/17/2018 05:27 12/18/2018 14:20 34.00 SRU3 CEMS S02 12/18/2018 14:20 12/19/2018 13:50 24.00 Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due lo a failed calibration. The l&E technician checked for leaks in the sample system but found none, recalibrated and returned the analyzer to service. Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due to a failed calibration. The l&E technician found a damaged sample line below the probe box under the insulation, replaced the section of line, recalibrated and returned the analyzer to service. SRU3 CEMS S02 12/24/2018 08:00 12/24/2018 13:00 5.00 Total 67.00 Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due to a sample system leak. The l&E technician found the sample leak at the probe, repaired, and returned the analyzer to service. HFNA-000003163 EPA Inspection Report - Page 1614 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report COMS or CEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions Start Date and Time Excess Emissions End Date and Time Duration of Deviation (hours) Excess Emissions Occurred During Period of Duration of excess emissions 1n reporting period due to: Brief Description of Nature and Cause of Excess Emission SRU3 CEMS S02 Deviations Corrective Action Taken or Preventative Measure Adopted No deviations -SRU3 did not record any deviations above the 12-Hour rolling SRU3 CEMS so, NA NA NA NA NA average of 250 ppmv S02 limit (corrected to 0% O,) during this reporting NA period. HFNA-000003164 EPA Inspection Report - Page 1615 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja Heater H-3402 NOx Heater H-3402 burns primarily purchased natural gas. The purchased natural gas may be supplemented with refinery fuel gas during times of purchased natural gas curtailment. 60.lOOa Applicability, designation of affected facility, and reconstruction. (a) The provisions of this subpart apply to the following affected facilities in petroleum refineries: fluid catalytic cracking units (FCCU), fluid coking units (FCU), delayed coking units, fuel gas combustion devices (including process heaters), flares and sulfur recovery plants. The sulfur recovery plant need not be physically located within the boundaries of a petroleum refinery to be an affected facility, provided it processes gases produced within a petroleum refinery. (b) Except for flares and delayed coking units, the provisions of this subpart apply only to affected facilities under paragraph (a) of this section which commence construction, modification or reconstruction after May 14, 2007. 60.101a Definitions. Terms used in this subpart are defined in the Clean Air Act (CAA), in 60.2 and in this section. Fuel gas means any gas which is generated at a petroleum refinery and which is combusted. Fuel gas includes natural gas when the natural gas is combined and combusted in any proportion with a gas generated at a refinery. Fuel gas does not include gases generated by catalytic cracking unit catalyst regenerators, coke calciners (used to make premium grade coke) and fluid coking burners, but does include gases from flexicoking unit gasifiers and other gasifiers. Fuel gas does not include vapors that are collected and combusted in a thermal oxidizer or flare installed to control emissions from wastewater treatment units other than those processing sour water, marine tank vessel loading operations or asphalt processing units (i.e., asphalt blowing stills). Fuel gas combustion device means any equipment, such as process heaters and boilers, used to combust fuel gas. For the purposes of this subpart, fuel gas combustion device does not include flares or facilities in which gases are combusted to produce sulfur or sulfuric acid. Heater H-3402 was constmcted after May 14, 2007 and is a fuel gas combustion device. Therefore, H-3402 is subject to NSPS Subpart Ja. 60.102a Emissions limitations. 60.102a(g) Each h owner or operator of an affected fuel gas combustion device shall comply with the emissions limits in paragraphs (g)(l) and (2) of this section. 60.102a(g)(2) For each process heater with a rated capacity of greater than 40 million British thermal units per hour (MMBtu/hr) on a higher heating value basis, the owner or operator shall not discharge to the atmosphere any emissions of NOx in excess of the applicable limits in paragraphs (g)(2)(i) through (iv) of this section. 60.102a(g)(2)(i) For each natural draft process heater, comply with the limit in either paragraph (g)(2)(i)(A) or (B) of this section. The owner or operator may comply with either limit at any time, provided that the appropriate parameters for each alternative are monitored as specified in 60.107a; if fuel gas composition is not monitored as specified in 60.107a(d), the owner or operator must comply with the concentration limits in paragraph (g)(2)(i)(A) of this section. 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. HFNA-000003165 EPA Inspection Report - Page 1616 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery 60.107a(c) Process heaters complying with the NOx concentration-based limit. The owner or operator of a process heater subject to the NOx emissions limit in 60.102a(g)(2) and electing to comply with the applicable emissions limit in 60.102a(g)(2)(i)(A), (g)(2)(ii)(A), (g)(2)(iii)(A) or (g)(2)(iv)(A) shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration (dry basis, 0-percent excess air) of NOx emissions into the atmosphere according to the requirements in paragraphs (c)(l) through (5) of this section, except as provided in paragraph (c)(6) of this section. The monitor must include an 0 2 monitor for correcting the data for excess air. 60.107a(c)(6) The owner or operator of a process heater that has a rated heating capacity of less than 100 MMBtu and is equipped with combustion modification-based technology to reduce NOX emissions (i.e., low-NOx burners, ultra-low-NOx burners) may elect to comply with the monitoring requirements in paragraphs (c)(l) through (5) of this section or, alternatively, the owner or operator of such a process heater shall conduct biennial pe1formance tests according to the requirements in 60.104a(i), establish a maximum excess 0 2 operating limit or operating curve according to the requirements in 60.104a(i)(6) and comply with the 0 2 monitoring requirements in paragraphs (c)(3) through (5) of this section to demonstrate compliance. If an 0 2 operating curve is used (i.e., if different 0 2 operating limits are established for different operating ranges), the owner or operator of the process heater must also monitor fuel gas flow rate, fuel oil flow rate (as applicable) and heating value content according to the methods provided in paragraphs (d)(5), (d)(6), and (d)(4) or (d)(7) of this section, respectively. Heater H-3402 has a rated heating capacity of greater than 40 MMBtu and less than l 00 MMBtu and is equipped with ultra-low-NOx burners. Therefore, Navajo operates H-3402 according to the alternative monitoring requirements of: Biennial performance testing. Establishing a maximum excess 0 2 operating li1nit. Operating an 0 2 monitor according to the requirements in paragraphs 60. l07a(c)(3) through (5). The 0 2 operating li1nit only applies during periods when Fuel Gas is burned in H-3402. 60.108a(d) Each owner or operator subject to this subpart shall submit an excess emissions repo1i for all periods of excess emissions according to the requirements of 60.7(c) except that the report shall contain the information specified in paragraphs (d)(l) through (7) of this section. (1) The date that the exceedance occurred; (2) An explanation of the exceedance; (3) Whether the exceedance was concurrent with a startup, shutdown, or malfunction of an affected facility or control system; and (4) A description of the action taken, if any. (5) The information described in paragraph (c)(6) of this section for all discharges listed in paragraph (c)(6) of this section. For a flare complying with the monitoring alternative under 60.107a(g), following the fifth discharge required to be recorded under paragraph (c)(6) of this section and repo1ied under this paragraph, the owner or operator shall include notification that monitoring systems will be installed according to 60.107a(e) and (f) within 180 days following the fifth discharge. (6) For any periods for which monitoring data are not available, any changes made in operation of the emission control system during the period of data unavailability which could affect the ability of the system to meet the applicable emission limit. Operations of the control system and affected facility during periods of data unavailability are to be compared with operation of the control system and affected facility before and following the period of data unavailability. HFNA-000003166 EPA Inspection Report - Page 1617 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery (7) A written statement, signed by a responsible official, certifying the accuracy and completeness of the information contained in the report. With this report, Navajo is submitting all periods of excess emissions according to the requirements of 60.7(c) and 60.108a(d)(l)-(7). HFNA-000003167 EPA Inspection Report - Page 1618 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report Heater H-3402 H-3402 0 2 Monitor Summary Mild Hydrocracker Reboiler 1 Affected Source Heater (H-3402) Emission Limit Citation Emission Limitation (02 AMP Emission Limit) 40 CFR 60.107a(c)(6) 4.6 Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit Servomex 2700 10276 01/31/2018 Reporting Period Beginning Date Reporting Period Ending Date CMS Performance Citation I Total Time in Reporting Period Total Source Downtime Total Source Operating Time in Reporting Period 07/01/2018 12/31/2018 60.7(d)(2) (hours) 4416 (hours) 157 (hours) 4259 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (eg., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Totals Total CMS Downtime as a Percent of Total Source Operating Time (60.7(d)(2)) Number of Incidents 0 0 178 0 0 178 Duration (Hours) 0.00 0.00 0.00 0.00 0.00 0.00 0.00% Emission Data Summary (Exceeds 30-Day rolling average of 0.2 lb NOx/MMBtu) (Exceeds 3-hour rolling average of 4.6 % 02) Duration of excess emissions in reporting period due to: Number of Incidents Startup 0 Shutdown 0 Control Equipment Problems 0 Process Problems 0 Other Known Causes 0 Other Unknown Causes 0 Totals 0 Total Duration of Deviations as a Percent of Total Source Operating Time (60.7(d)(2)) Duration (Hours) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00% HFNA-000003168 EPA Inspection Report - Page 1619 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery NSPS Subpart Ja Periodic Report Heater H-3402 GEMS Downtime Affected Source Name Monitor Type Monitored HAP or Gas Downtime Start Date and Time Downtime End Date and Time Duration of Downtime (hours) Type of Downtime Period H-3402 GEMS NOx NA NA NA NA Total 0.00 Type of Cause of Deviation Brief Description of Cause of Downtime NA No Downtime - There was no downtime recorded for this GEMS during this reporting period. H-3402 0 2 Monitor Downtime Corrective Action Taken NA HFNA-000003169 EPA Inspection Report - Page 1620 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery NSPS Subpart Ja Periodic Report Heater H-3402 H-3402 0 2 Monitor Exceedences GEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored Excess Emissions HAP or Start Date and Gas Time Excess Emissions End Date and Time Duration of Excess Deviation Emissions (hours) Occurred During Period of Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission Corrective Action Taken or Preventative Measure Adopted No deviation - There were no deviations based on the AMP H-3402 GEMS 02 NA NA NA NA NA measured 0 2/o for the calculated 30-Day rolling average of 0.2 It NA NOx/MMBtu. HFNA-000003170 EPA Inspection Report - Page 1621 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja Heater H-9851 NOx Heater H-9851 burns a mixture of purchased natural gas and refinery fuel gas. 60.lOOa Applicability, designation of affected facility, and reconstruction. (a) The provisions of this subpart apply to the following affected facilities in petroleum refineries: fluid catalytic cracking units (FCCU), fluid coking units (FCU), delayed coking units, fuel gas combustion devices (including process heaters), flares and sulfur recovery plants. The sulfur recovery plant need not be physically located within the boundaries of a petroleum refinery to be an affected facility, provided it processes gases produced within a petroleum refinery. (b) Except for flares and delayed coking units, the provisions of this subpart apply only to affected facilities under paragraph (a) of this section which commence construction, modification or reconstruction after May 14, 2007. 60.101a Definitions. Terms used in this subpart are defined in the Clean Air Act (CAA), in 60.2 and in this section. Fuel gas means any gas which is generated at a petroleum refinery and which is combusted. Fuel gas includes natural gas when the natural gas is combined and combusted in any proportion with a gas generated at a refinery. Fuel gas does not include gases generated by catalytic cracking unit catalyst regenerators, coke calciners (used to make premium grade coke) and fluid coking burners, but does include gases from flexicoking unit gasifiers and other gasifiers. Fuel gas does not include vapors that are collected and combusted in a thermal oxidizer or flare installed to control emissions from wastewater treatment units other than those processing sour water, marine tank vessel loading operations or asphalt processing units (i.e., asphalt blowing stills). Fuel gas combustion device means any equipment, such as process heaters and boilers, used to combust fuel gas. For the purposes of this subpart, fuel gas combustion device does not include flares or facilities in which gases are combusted to produce sulfur or sulfuric acid. Heater H-9851 was constmcted after May 14, 2007 and is a fuel gas combustion device. Therefore, H-9851 is subject to NSPS Subpart Ja. 60.102a Emissions limitations. 60.102a(g) Each h owner or operator of an affected fuel gas combustion device shall comply with the emissions limits in paragraphs (g)(l) and (2) of this section. 60.102a(g)(2) For each process heater with a rated capacity of greater than 40 million British thermal units per hour (MMBtu/hr) on a higher heating value basis, the owner or operator shall not discharge to the atmosphere any emissions of NOx in excess of the applicable limits in paragraphs (g)(2)(i) through (iv) of this section. 60.102a(g)(2)(i) For each natural draft process heater, comply with the limit in either paragraph (g)(2)(i)(A) or (B) of this section. The owner or operator may comply with either limit at any time, provided that the appropriate parameters for each alternative are monitored as specified in 60.107a; iffuel gas composition is not monitored as specified in 60.107a(d), the owner or operator must comply with the concentration limits in paragraph (g)(2)(i)(A) of this section. 60.102a(g)(2)(i)(A) 40 ppmv (dry basis, corrected to 0-percent excess air) determined daily on a 30-day rolling average basis; or HFNA-000003171 EPA Inspection Report - Page 1622 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. 60.107a(c) Process heaters complying with the NOx concentration-based limit. The owner or operator of a process heater subject to the NOx emissions limit in 60.102a(g)(2) and electing to comply with the applicable emissions limit in 60.102a(g)(2)(i)(A), (g)(2)(ii)(A), (g)(2)(iii)(A) or (g)(2)(iv)(A) shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration (dry basis, 0-percent excess air) of NOx emissions into the atmosphere according to the requirements in paragraphs (c)(l) through (5) of this section, except as provided in paragraph (c)(6) of this section. The monitor must include an 0 2 monitor for correcting the data for excess air. The NOx CEMS on Heater H-9851 records concentrations in parts per million by volume on a dry basis (ppmvd). The NOx concentrations are corrected to 0-percent excess air using the oxygen monitor concentrations. 60.108a(d) Each owner or operator subject to this subpa1i shall submit an excess emissions report for all periods of excess emissions according to the requirements of 60.7(c) except that the report shall contain the information specified in paragraphs (d)(l) through (7) of this section. (1) The date that the exceedance occurred; (2) An explanation of the exceedance; (3) Whether the exceedance was concurrent with a startup, shutdown, or malfunction of an affected facility or control system; and (4) A description of the action taken, if any. (5) The information described in paragraph (c)(6) of this section for all discharges listed in paragraph (c)(6) of this section. For a flare complying with the monitoring alternative under 60.107a(g), following the fifth discharge required to be recorded under paragraph (c)(6) of this section and reported under this paragraph, the owner or operator shall include notification that monitoring systems will be installed according to 60.107a(e) and (f) within 180 days following the fifth discharge. (6) For any periods for which monitoring data are not available, any changes made in operation of the emission control system during the period of data unavailability which could affect the ability of the system to meet the applicable emission limit. Operations of the control system and affected facility during periods of data unavailability are to be compared with operation of the control system and affected facility before and following the period of data unavailability. (7) A written statement, signed by a responsible official, certifying the accuracy and completeness of the information contained in the report. With this report, Navajo is submitting all periods of excess emissions according to the requirements of 60.7(c) and 60.108a(d)(l)-(7). HFNA-000003172 EPA Inspection Report - Page 1623 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report Heater H-9851 H-9851 NOx CEMS Summary Affected Source Emission Limit Citation Emission Limitation (ppmv) H-9851 40 CFR 60.102a(g)(2)(i) 40 Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit Reporting Period Beginning Date Reporting Period Ending Date California Analytical 600 CLO W01040 03/20/2018 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime (Fuel gas flow to H-9851 less than zero) Total Source Operating Time in Reporting Period (hours) (hours) (hours) 4416 0 4416 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Totals Total CMS Downtime as a Percent of Total Source Operatinq Time Number of Incidents 1 0 184 2 0 187 Duration (Hours) 19.00 0.00 0.00 4.00 0.00 23.00 0.52% Emission Data Summary (Exceeds 30-Day NOx rolling average of 40 ppmv) Duration of excess emissions in reporting period due to: Number of Incidents Duration (Hours) Startup 0 Shutdown 0 Control Equipment Problems 0 Process Problems 0 Other Known Causes 0 Other Unknown Causes 0 Totals 0 Total Duration of Deviations as a Percent of Total Source Operating Time 0 0 0 0 0 0 0 0.00% HFNA-000003173 EPA Inspection Report - Page 1624 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report Heater H-9851 H-9851 NOx CEMS Downtime CEMS Downtime Affected Source Name Monitor Monitored Downtime Downtime Type HAP or Gas Start Date and Time End Date and Time Duration of Downtime (hours) Type of Downtime Type of Cause of Period Deviation Brief Description of Cause of Downtime H-9851 CEMS NOx 08/16/20181315 08/16/2018 15 25 2.00 Other Known Cause Other The analyzer was placed in maintenance mode to perform a CGA Corrective Action Taken The E&I technician performed the CGA and returned the analyzer to service. H-9851 CEMS NOx 11/15/20181250 11/15/20181457 2.00 Other Known Cause Other The analyzer was placed in maintenance mode to perform a CGA The E&I technician performed the CGA and returned the analyzer to service. A broken connection at the pressure sensor was H-9851 CEMS NOx 12/23/2018 16 55 12/24/20181115 1900 Monitor Equipment Malfunction The analyzer was placed in maintenance mode due to identified as the cause of the air pressure issue. Malfunction loss of air pressure in the sample system The l&E technician repaired the connection, recalibrated and returned the analyzer to service. Total 23.00 HFNA-000003174 EPA Inspection Report - Page 1625 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery CEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions Start Date and Time Excess Emissions End Date and Time H-9851 CEMS NOx NA NA NSPS Subpart Ja Periodic Report Heater H-9851 H-9851 GEMS Excess Emissions Duration of Deviation (hours) 0:00 Excess Emissions Occurred During Period of Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission No deviations - Heater H-9851 did not record any NA NA deviations above the 30-Day rolling average of 40 ppmv limit. Corrective Action Taken or Preventative Measure Adopted NA HFNA-000003175 EPA Inspection Report - Page 1626 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja Artesia North Plant Flare, FL-0400 60.lOOa Applicability, designation of affected facility, and reconstruction. (b) For flares, the provisions of this subpart apply only to flares which commence construction, modification or reconstruction after June 24, 2008. 60.101a Definitions. Terms used in this subpart are defined in the Clean Air Act (CAA), in 60.2 and in this section. Emergency flare means a flare that combusts gas exclusively released as a result of malfunctions (and not startup, shutdown, routine operations or any other cause) on four or fewer occasions in a rolling 365-day period. For purposes of this rule, a flare cannot be categorized as an emergency flare unless it maintains a water seal. Non-emergency flare means any flare that is not an emergency flare as defined in this subpart. Flare FL-400 is a Non-emergency flare. Modification or reconstrnction occurred on Flare FL-400 after June 24, 2008. Therefore FL-400 is subject to NSPS Subpart Ja HFNA-000003176 EPA Inspection Report - Page 1627 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja - 500 M SCF 24-hour rolling average Artesia North Plant Flare (FL-400) 60.lOla Definitions. Flare. In the case of an interconnected flare gas header system, the flare includes each individual flare serviced by the interconnected flare gas header system and the interconnected flare gas header system. 60.103a Design, equipment, work practice or operational standards (a) Except as provided in paragraph (g) of this section, each owner or operator that operates a flare that is subject to this subpart shall develop and implement a written flare management plan no later than the date specified in paragraph (b) of this section. The flare management plan must include the information described in paragraphs (a)(l) through (7) of this section. compressor staging and a justification for why the maximum time period cannot be further reduced. (4) An evaluation of the baseline flow to the flare. The baseline flow to the flare must be determined after implementing the minimization assessment in paragraph (a)(2) of this section. Baseline flows do not include pilot gas flow or purge gas flow (i.e., gas introduced after the flare's water seal) provided these gas flows remain reasonably constant (i.e., separate flow monitors for these streams are not required). Separate baseline flow rates may be established for different operating conditions provided that the management plan includes: (c) Except as provided in paragraphs (f) and (g) of this section, each owner or operator that operates a flare subject to this subpart shall conduct a root cause analysis and a corrective action analysis for each of the conditions specified in paragraphs (c)(l) of this section. (1) For a flare: (ii) Any discharge to the flare in excess of 14,160 standard cubic meters (m3) (500,000 standard cubic feet (set)) above the baseline, determined in paragraph (a)(4) of this section, in any 24-hour period. 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. (t) Flow monitoring for flares. Except as provided in paragraphs (t)(2) and (h) of this section, the owner or operator of an affected flare subject to 60.103a(c) through (e) shall install, operate, calibrate and maintain, in accordance with the specifications in paragraph (t)(l) of this section, a CPMS to measure and record the flow rate of gas discharged to the flare. (1) The owner or operator shall install, calibrate, operate and maintain each flow monitor according to the manufacturer's procedures and specifications and the following requirements. (iv) At least quarterly, pe1form a visual inspection of all components of the monitor for physical and operational integrity and all electrical connections for oxidation and galvanic corrosion if the flow monitor is not equipped with a redundant flow sensor. (v) Recalibrate the flow monitor in accordance with the manufacturer's procedures and specifications biennially (every two years) or at the frequency specified by the manufacturer. HFNA-000003177 EPA Inspection Report - Page 1628 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery The FCC Flare (FL-402) and the North Plant Flare (FL-400) were previously part of an interconnected network of flare headers, although they did not operate as intercom1ected flares. The Flare Management Plan (FMP) submitted on November 11, 2015 established the combined flow baseline for FL-400 (North Plant) and FL-402 (FCC) flares as 1,077,961. As ofJuly 2017, the physical connection between the flares headers was removed, and separate flow baselines were established for each flare. The July 2017 FMP update establishes a new flow baseline of 162,000 SCF in any 24-hour period for FL-402 (FCC), and a new flow baseline of 624,000 SCF in any 24-hour period for FL-400 (NP). Per 40 CFR 60.103a(c)(l)(ii), the threshold for a Root Cause Analysis and corrective action plan is 662,000 SCF in any 24-hour period for the FCC Flare, and 1,124,000 SCF in a 24-hour period for the NP Flare. HFNA-000003178 EPA Inspection Report - Page 1629 of 1969 HollyFron!ier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report North Plant Flare (FL-0400) FL-400 500M SCF Summ Affected Source FL-400 North Flare Emission Limit Citation 60.107a(f) Emission Limitation (SCF over baseline in rolling 24 hours) 500,000 Monitor Manufacturer and Model No. General Electric - GF868-2-11 Monitor Serial Number Date of Latest CMS Certification or Audit 4431 10/17/2017 Reporting Period Beginning Date Reporting Period Ending Date 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime Total Source Operating Time in Reporting Period (hours) (hours) (hours) 4416 0 4416 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Totals Total CMS Downtime as a Percent of Total Source Operating Time Number of Incidents 9 0 0 0 0 9 9 Duration (Hours) 15.00 0.00 0.00 0.00 0.00 15.00 15.00 0.34% Emission Data Summary (Exceeds 500,000 SCF over baseline in rolling 24 hours) Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Totals Total Duration of Deviations as a Percent of Total Source Operating Time Number of Incidents 0 1 0 1 1 0 3 Duration (Hours) 0.00 28.00 0.00 24.00 88.00 0.00 140.00 3.17% HFNA-000003179 EPA Inspection Report - Page 1630 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report North Plant Flare (FL-0400) FL-400 Flowmeter Downtime CMS Downtime Affected Source Name Monitor Type Monitored Downtime Downtime HAP or start Date and Time End Date and Time Gas Duration of Downtime (hours) FL-400 Flowmeter SCF 08/14/2018 17:00 08/14/2018 18:00 1.00 FL-400 Flowmeter SCF 09/13/201811:45 09/13/2018 12:00 0.25 FL-400 Flowmeter SCF 09/14/2018 09:15 09/14/2018 11 :30 2.25 FL-400 Flowmeter SCF 10/02/2018 13:30 10/02/2018 16:30 3.00 FL-400 Flowmeter SCF 10/30/2018 09:00 10/30/2018 10:00 1.00 FL-400 Flowmeter SCF 11/21/201813:45 11/21/201814:15 0.50 FL-400 Flowmeter SCF 11/27/201810:30 11/27/2018 15:30 5.00 FL-400 Flowmeter SCF 11/29/2018 09:15 11/29/201810:15 1.00 FL-400 Flowmeter SCF 12/12/2018 09:00 12/12/2018 09:45 rotal 0.75 ,s no Type of Downtime Period Type of Cause of Deviation Brief Description of Cause of Downtime Corrective Action Taken Changes to Emission Control 60.108a(d)(6) Monitor Equipment Malfunction Monitor Equipment Malfunction Monitor Equipment Malfunction Monitor Equipment Malfunction Monitor Equipment Malfunction Monitor Equipment Malfunction Monitor Equipment Malfunction Monitor Equipment Malfunction Monitor Equipment Malfunction Malfunction Malfunction Malfunction Malfunction Malfunction Malfunction Malfunction Malfunction Malfunction The analyzer was placed in maintenance mode due to an analyzer malfunction. The analyzer was placed in maintenance mode due to an analyzer malfunction. The analyzer was placed in maintenance mode due to an analyzer malfunction. The analyzer was placed in maintenance mode due to an analyzer malfunction The analyzer was placed in maintenance mode due to an analyzer malfunction The analyzer was placed in maintenance mode due to an analyzer malfunction The analyzer was placed in maintenance mode due to an analyzer malfunction The analyzer was placed in maintenance mode due to an analyzer malfunction. The analyzer was placed in maintenance mode due to an analyzer malfunction The l&E Technician performed maintenance to No changes were made in operation of correct an analyzer malfunction, and the the emission control system analyzer was returned to service. The l&E Technician performed maintenance to No changes were made in operation of correct an analyzer malfunction, and the the emission control system. analyzer was returned to service. The l&E Technician performed maintenance to No changes were made in operation of correct an analyzer malfunction, and the the emission control system. analyzer was returned to service. The l&E Technician performed maintenance to No changes were made in operation of correct an analyzer malfunction, and the the emission control system. analyzer was returned to service. The l&E Technician performed maintenance to No changes were made in operation of correct an analyzer malfunction. and the the emission control system. analyzer was returned to service. The l&E Technician performed maintenance to No changes were made in operation of correct an analyzer malfunction. and the the emission control system. analyzer was returned to service. The l&E Technician performed maintenance to No changes were made in operation of correct an analyzer malfunction. and the the emission control system. analyzer was returned to service. The l&E Technician performed maintenance to No changes were made in operation of correct an analyzer malfunction. and the the emission control system. analyzer was returned to service. The l&E Technician performed maintenance to No changes were made in operation of correct an analyzer malfunction. and the the emission control system. analyzer was returned to service. HFNA-000003180 EPA Inspection Report - Page 1631 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report North Plant Flare (FL-0400) CMS Deviations Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions Start Date and lime Excess Emissions End Date and lime Duration of Deviation (hours) Excess Emissions Occurred During Period of Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission FL-400 500M SCF Deviations Corrective Action Taken or Preventative Measure Adopted Discharges Per 60.108a(d)(5) FL-400 Flowmeter SCF 07/12/201815:00 07/13/201819:00 28.00 FL-400 Flowmeter SCF 07/16/201818:00 07/17/201818:00 24.00 FL-400 Flowmeter SCF 09/24/2018 03:00 09/27/201819:00 BB.DO Total 140.00 The North Flare exceeded the flow baseline reporting threshold scfd while flaring. Sulfur Recovery Unit No. 3 was placed out of service to repair a small leak identified Operations followed procedures to minimize the impact of the y Shutdown near the acid gas inlet nozzle to the SRU3 Thermal Reactor rear chamber. The acid excess emissions on ambient air quality". Feed flow rates in See Attached Event Record: "#1-2018-08gas normally treated in SRU3 was diverted for treatment to SRU2. Feed Flow rates upstream units were reduced to reduce the production of acid 28 FL-0400 NSPS Ja Flow RCA" in upstream units were reduced to reduce the production of acid gas, and the load gas, and to minimize flaring. on the operating SRU2 while SRU3 was out of service. Process Problems The excess flaring was caused by the fuel balance drum (D-0019) receiving excess sweet gas from various units throughout the facility. Unit feed rates were reduced so that excess flaring was minimized. See Attached Event Record: "#2-2018-0828 FL-0400 NSPS Ja Flow RCA" Other Known Cause The electrical power supply from a third party" substation to the Artesia Refinery was interrupted for approximately 3 hours, resulting in the shutdown of several process units, as well as several pumps, compressors and other electric pieces of equipment within the refinery. The flaring associated with the units' shutdown contributed to discharge to the flare in excess of the flow baseline reporting threshold. The electrical supply was promptly shifted to four additional substations that provide the electrical power to other sections of the refinery, allowing the electrical power to be restored The frequency of preventative maintenance activities petionned by the third-party electrical substation was increased form semiannual to monthly basis. See Attached Event Record: "#3-2018-1005 FL-0400 NSPS Ja Flow RCA" HFNA-000003181 EPA Inspection Report - Page 1632 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja - 162 ppmvd H2S 3-hour rolling average Artesia North Plant Flare, FL-0400 60.103a Design, equipment, work practice or operational standards (h) Each owner or operator shall not burn in any affected flare any fuel gas that contains H2S in excess of 162 ppmv determined hourly on a 3-hour rolling average basis. The combustion in a flare of process upset gases or fuel gas that is released to the flare as a result of relief valve leakage or other emergency malfunctions is exempt from this limit. 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. (a) Fuel gas combustion devices subject to S02 or H2S limit and flares subject to H2S concentration requirements. (2) The owner or operator of a fuel gas combustion device that elects to comply with the H2S concentration limits in 60.102a(g)(1)(ii) or a flare that is subject to the H2S concentration requirement in 60.103a(h) shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration by volume (dry basis) of H2S in the fuel gases before being burned in any fuel gas combustion device or flare. (3) The owner or operator of a fuel gas combustion device or flare is not required to comply with paragraph (a)(l) or (2) of this section for fuel gas streams that are exempt under 60.102a(g)(1)(iii) or 60.103a(h) or, for fuel gas streams combusted in a process heater, other fuel gas combustion device or flare that are inherently low in sulfur content. (e) Su(f'ur monitoringfor assessing root cause analysis thresholdfor affectedflares. (2) H2S monitoring requirements. The owner or operator shall install, operate, calibrate, and maintain an instrument for continuously monitoring and recording the concentration of H2S in gas discharged to the flare according to the requirements in paragraphs (e)(2)(i) through (iii) of this section and shall collect and analyze samples of the gas and calculate total sulfur concentrations as specified in paragraphs (e)(2)(iv) through (ix) of this section. Flare FL-400 is subject to the 162 ppmv hydrogen sulfide (H2S) limit. Therefore, Navajo maintains an H 2S CEMS on Flare FL-400 that records concentrations in parts per million by volume on a dry basis (ppmvd). Note: 60. l03a(h) exempts startup, shutdown. malfunctioR and process upset gases, along with relief valve leakage, from the requirement to meet the 162 ppm (H2S) limit. In this report we have included information on these events subject to exemptions. and have identified them as such. HFNA-000003182 EPA Inspection Report - Page 1633 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report North Plant Flare (FL-0400) FL-400 H2S CEMS Summary Affected Source Emission Limit Citation Emission Limitation (H 2S ppmv on rolling 3-hours) Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit FL-400 North Flare 60.103a(h) 60.107a( e)(2) 162 Siemens - Maxum II 30049702230300 01/24/2018 Reporting Period Beginning Date Reporting Period Ending Date 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime Total Source Operating Time in Reporting Period CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Totals Total CMS Downtime as a Percent of Total Source Operating Time (hours) (hours) (hours) Number of Incidents 4 0 186 5 0 195 4416 0 4416 Duration (Hours) 204.00 0.00 9.00 17.00 0.00 230.00 5.21% Emission Data Summary (Exceeds 162 H2S ppmv on rolling 3-hours) Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Totals Total Duration of Deviations as a Percent of Total Source Operating Time Number of Incidents 1 2 0 75 5 0 83 Duration (Hours) 0.00 0.00 0.00 19.00 0.00 0.00 19.00 0.43% HFNA-000003183 EPA Inspection Report - Page 1634 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report North Plant Flare (FL-0400) FL-400 H2S GEMS Downtime CEMS Downtime Affected Source Name Monitor Monitore Type d HAP or Gas Downtime Start Date and Time Downtime End Date and Time Duration of Downtime (hours) Type of Downtime Type of Cause Period of Deviation Brief Description of Cause of Downtime Corrective Action Taken Changes to Emission Control 60.108a(d)(6) FL-400 CEMS FL-400 CEMS FL-400 CEMS H2S 10/04/2018 07 38 10/04/2018 10 09 H2S 10/30/2018 08 30 10/30/2018 0946 H2S 11/20/2018 06 30 11/24/2018 1748 2.00 100 108.00 Quality Assurance Calibration Other The analyzer was placed in maintenance The l&E technician recalibrated and returned the mode to recalibrate. analyzer to service. No changes were made in operation of the emission control system. Other Known Cause Other The analyzer was placed in maintenance mode for routine maintenance. The E&I technician changed out the Genie, the water carry over, and the probe filters and returned the analyzer to service. No changes were made in operation of the emission control system. Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due to failed calibrations. The l&E technician replaced several valves, detectors, and the circa valve. with no success. Then the GC TCDi right side was replaced with no success. New parts were ordered, installed and recalibrated. The analyzer was returned to service when calibration was successfully completed No changes were made in operation of the emission control system. FL-400 CEMS H2S 11/27/2018 0900 11/27/2018 1600 FL-400 CEMS H2S 11/28/2018 1300 11/28/2018 1600 FL-400 CEMS H2S 11/29/2018 0845 11/29/2018 1000 FL-400 CEMS H2S 11/29/2018 1000 11/29/2018 17 00 FL-400 CEMS H2S 12/07/2018 0910 12/07/20181400 FL-400 CEMS H2S 12/11/2018 0630 12/12/20181140 7.00 3.00 100 7.00 5.00 30.00 Other Known Cause Other The analyzer was placed in maintenance The l&E technician proceeded with the RSR proJect tie- No changes were made in operation mode due to project tie-in. ins and returned the analyzer to service. of the emission control system. Other Known Cause Other The analyzer was placed in maintenance The l&E technician performed a linearity test and mode to perform a linearity test returned the analyzer to service. No changes were made in operation of the emission control system. Other Known Cause Other The analyzer was placed in maintenance mode to replace the sample flowmeter to the GC The l&E technician replaced the flowmeter, recalibrated No changes were made in operation and returned the analyzer to service. of the emission control system. Quality Assurance Calibration Other The analyzer was placed in calibration mode to recalibrate The l&E technician recalibrated and returned the analyzer to service. No changes were rnade in operation of the emission control system. Other Known Cause Other The analyzer was placed in maintenance The l&E Technician performed a CGA and returned the No changes were rnade in operation mode to perform a CGA analyzer to service. of the emission control system. Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due to failed calibration The l&E technician replaced the H2S process stream circos valve in the SCS, recalibrated and returned the analyzer to service. No changes were rnade in operation of the emission control system. FL-400 CEMS H2S 12/15/2018 06 30 12/16/20181400 32.00 Monitor Equipment Malfunction The analyzer was placed in maintenance The l&E technician was not able to identify the cause, Malfunction mode due to a failed calibration. but recalibrated. and returned the analyzer to service No changes were rnade in operation of the emission control system. FL-400 CEMS H,S 12/18/2018 06 30 12/19/2018 1612 Total 34.00 230.00 Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due to a failed calibration. The l&E technician performed maintenance on the analyzer, recalibrated and returned the analyzer to service. No changes were made in operation of the emission control system. HFNA-000003184 EPA Inspection Report - Page 1635 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report North Plant Flare (FL-0400) FL-400 H2S Excess Emissions CEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions start Date and Time Excess Emissions End Date and Time Duration of i Deviation (hours) Excess Emissions Occurred During Period of SSM (Y/N) Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission FL-400 GEMS H2S 08/21/2018 06:00 08/21/201813:00 7.00 y Shutdown It was discovered that the flare exceeded the NSPS Ja 162 ppm H7S 3-hour rolling average limit. Equipment being purged to get them ready for maintenance. FL-400 GEMS H2S 08/27/201813:00 08/27/2018 16:00 3.00 y Shutdown While purging equipment (C-0064. P-0043 and P-0235) to flare in preparation for maintenance, the NSPS Ja 162 ppm H2S 3-hour rolling average was exceeded Corrective Action Taken or Preventative Measure Adopted standard operating procedures were followed to minimize emissions from the flare during shut down of the units. Scavenger was injected to minimize S0 2 emissions. The standard operating procedures were followed to minimize emissions from the flare during shut down of the units. H2S scavenger was injected to minimize S02 emissions. Unexpected shutdovvn of the Recycle Compressor (C-0064) trip caused the Naphtha Unit (Unit 06) flow valve controller to operate in an open position, resulting in an To minimize excess S02 emissions from the flare. H2S scavenger agent was FL-400 GEMS H2S 09/12/2018 11 :00 09/12/201814:00 3.00 N Process Problems increase in the overhead system's temperature and pressure. The recycle compressor injected upstream of the Flare Knockout (KO) drums in crder to reduce the would not restart during this time. The compressor shutdown procedure was followed to concentration of H7S in the gas vented to the flare. minimize excess S02 emissions from the flare. FL-400 GEMS H2S 09/22/2018 17:00 09/22/2018 19:00 2.00 N FL-400 GEMS H2S 09/23/2018 22:00 09/24/2018 05:00 7.00 N FL-400 GEMS H2S 09/24/2018 07:00 09/24/2018 10:00 3.00 N FL-400 GEMS H2S 09/24/2018 14:00 09/24/2018 19:00 5.00 N FL-400 GEMS H2S 09/25/2018 13:00 09/26/2018 11:00 22.00 y FL-400 GEMS H2S 09/26/2018 16:00 09/27/2018 00:00 8.00 y I Process Problems Unexpected shutdovvn of Amine Unit Lean ,Amine Pump (P-0775). The spare Lean Electricians were called as soon as the switchgear malfunctiooed, determining ,Amine Pump (P-0776) was started. While testing P-0775, the switch rack breaker that the bucket style breaker tripped. The breaker was reset, the spare pump (P- feeding the breaker rack shorted causing a loss of power to both amine pumps. The 0776) was restarted. The ,Amine contactors were retuned online, resuming normal ,Amine contactors could not operate, reducing the treating capacity of acid gas being operation. To minimize excess S02 emissions from the flare, operations promptly sent to the fuel gas system. This caused an exceedance of the NSPS Ja 162 ppm H2S 3- injected an H2S scavenger agent upstream of the Flare Knockout drum in order to hour rolling average at the flare. reduce the emissions of S02 from the flare. Other Knovvn Cause other Known Cause Other Known Cause Other Knovvn Cause Other Known Cause The electrical power supply from a third party substation to the Artesia Refinery was interrupted for approximately 3 hours, resulting in the shutdown of several process units, as well as several pumps, compressors and other electric pieces of equipment within the refinery. Off-gas was continued to be produced some time after the power outage occurred and the process units shut down. Without the electrical power to operate amine contactors and H2S strippers, the H2S concentration in the FGS and ,Amine Unit increased. Because the FG is also used as vent gas in the flare system, the H2S concentration increase in the FGS was transferred to the North Plant, FCC, and GOH flare systems, resulting in excess of the NSPS Ja 162 ppm H2S 3-hour rolling average The electrical supply was promptly shifted to four additional substations that provide the electrical power to other sections of the refinery, allowing the electrical power to be restored, and process units to be restarted. The frequency of preventative maintenance activities performed by the third-party electrical substation was increased form semiannual to monthly basis HFNA-000003185 EPA Inspection Report - Page 1636 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report North Plant Flare (FL-0400) FL-400 H2S Excess Emissions CEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions start Date and Time FL-400 GEMS H2S 10/15/2018 23:00 FL-400 GEMS H2S 10/16/2018 08:00 FL-400 GEMS H2S 10/17/2018 19:00 FL-400 GEMS H2S 10/23/2018 01 :00 FL-400 GEMS H2S 10/26/2018 07:00 FL-400 GEMS H2S 10/27/2018 01:00 FL-400 GEMS H2S 10/31/201814:00 FL-400 GEMS H2S 11/01/2018 04:00 FL-400 GEMS H2S 11/02/2018 01:00 FL-400 GEMS H2S 11/04/201811:00 FL-400 GEMS H2S 11/08/201813:00 FL-400 GEMS H2S 11/08/201817:00 FL-400 GEMS H2S 11/09/2018 04:00 FL-400 GEMS H2S 11/09/201813:00 FL-400 GEMS H2S 11/10/2018 07:00 FL-400 GEMS H2S 11/10/201813:00 FL-400 GEMS H2S 11/10/2018 22:00 FL-400 GEMS H2S 11/11/201815:00 FL-400 GEMS H2S 11/12/201814:00 FL-400 GEMS H2S 11/12/2018 21:00 FL-400 GEMS H2S 11/13/2018 06:00 FL-400 GEMS H2S 11/13/201816:00 FL-400 GEMS H2S 11/13/2018 23:00 FL-400 GEMS H2S 11/14/2018 05:00 FL-400 GEMS H2S 11/14/201812:00 FL-400 GEMS H2S 11/16/2018 09:00 FL-400 GEMS H2S 11/17/2018 09:00 FL-400 GEMS H2S 11/18/2018 02:00 FL-400 GEMS H2S 11/19/2018 01:00 FL-400 GEMS H2S 11/19/201811:00 FL-400 GEMS H2S 11/21/2018 04:00 FL-400 GEMS H2S 11/25/2018 01:00 FL-400 GEMS H2S 11/25/201816:00 FL-400 GEMS H2S 11/26/2018 01:00 FL-400 GEMS H2S 11/26/201811:00 FL-400 GEMS H2S 11/26/2018 22:00 FL-400 GEMS H2S 11/27/2018 06:00 FL-400 GEMS H2S 11/27/2018 23:00 Excess Emissions End Date and Time 10/16/2018 02:00 10/16/2018 13:00 10/17/2018 21:00 10/23/2018 05:00 10/26/2018 11 :00 10/27/2018 04:00 10/31/201817:00 11/01/2018 07:00 11/02/2018 04:00 11/04/201814:00 11/08/201816:00 11/08/2018 23:00 11/09/2018 07:00 11/09/201816:00 11/10/201810:00 11/10/201817:00 11/11/2018 01:00 11/11/201818:00 11/12/201815:00 11/13/2018 00:00 11/13/2018 09:00 11/13/201819:00 11/14/2018 02:00 11/14/2018 08:00 11/14/201815:00 11/16/201812:00 11/17/201812:00 11/18/201812:00 11/19/2018 04:00 11/19/201814:00 11/21/201811:00 11/25/2018 05:00 11/25/201819:00 11/26/2018 04:00 11/26/201814:00 11/27/2018 02:00 11/27/201812:00 11/28/2018 02:00 Duration of i Deviation (hours) Excess Emissions Occurred During Period of SSM (Y/N) 3.00 N 5.00 N 2.00 N 4.00 N 4.00 N 3.00 N 3.00 N 3.00 N 3.00 N 3.00 N 3.00 N 6.00 N 3.00 N 3.00 N 3.00 N 4.00 N 3.00 N 3.00 N 1.00 N 3.00 N 3.00 N 3.00 N 3.00 N 3.00 N 3.00 N 3.00 N 3.00 N 10.00 N 3.00 N 3.00 N 7.00 N 4.00 N 3.00 N 3.00 N 3.00 N 4.00 N 6.00 N 3.00 N Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems The pressure in the North Plant High Pressure Knock Out Drum (D-0768) increased. The excess pressure was relieved to the North Plant Flare, resulting in emissions to exceed the NSPS Ja 162 ppm H2S 3-hour rolling average. Corrective Action Taken or Preventative Measure Adopted In an effort to minimize emissions, an H2S scavenger agent was injected at maximum rate HFNA-000003186 EPA Inspection Report - Page 1637 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report North Plant Flare (FL-0400) FL-400 H2S Excess Emissions CEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions start Date and Time FL-400 CEMS H2S 11/28/201813:00 FL-400 CEMS H2S 11/28/2018 20:00 FL-400 CEMS H2S 11/29/201817:00 FL-400 CEMS H2S 11/30/201815:00 FL-400 CEMS H2S 12/01/2018 03:00 FL-400 CEMS H2S 12/02/2018 23:00 FL-400 CEMS H2S 12/03/2018 08:00 FL-400 CEMS H2S 12/03/2018 15:00 FL-400 CEMS H2S 12/04/2018 00:00 FL-400 CEMS H2S 12/04/2018 04:00 FL-400 CEMS H2S 12/04/2018 10:00 FL-400 CEMS H2S 12/04/2018 18:00 FL-400 CEMS H2S 12/05/2018 01 :00 FL-400 CEMS H2S 12/05/2018 12:00 FL-400 CEMS H2S 12/05/2018 17:00 FL-400 CEMS H2S 12/06/2018 01 :00 FL-400 CEMS H2S 12/06/2018 09:00 FL-400 CEMS H2S 12/06/2018 17:00 FL-400 CEMS H2S 12/07/2018 03:00 FL-400 CEMS H2S 12/07/2018 21 :00 FL-400 CEMS H2S 12/08/2018 05:00 FL-400 CEMS H2S 12/08/2018 07:00 FL-400 CEMS H2S 12/08/2018 10:00 FL-400 CEMS H2S 12/11/2018 06:00 FL-400 CEMS H2S 12/12/2018 06:00 FL-400 CEMS H2S 12/13/2018 08:00 Excess Emissions End Date and Time 11/28/201816:00 11/28/2018 23:00 11/29/2018 21:00 11/30/201818:00 12/01/2018 06:00 12/03/2018 02:00 12/03/2018 12:00 12/03/2018 20:00 12/04/2018 03:00 12/04/2018 09:00 12/04/2018 16:00 12/04/2018 21 :00 12/05/2018 07:00 12/05/2018 16:00 12/05/2018 20:00 12/06/2018 04:00 12/06/2018 13:00 12/06/2018 20:00 12/07/2018 05:00 12/08/2018 03:00 12/08/2018 06:00 12/08/2018 08:00 12/10/2018 22:00 12/11/2018 20:00 12/12/2018 09:00 12/13/2018 14:00 Duration of Deviation (hours) Excess Emissions Occurred During Period of SSM (Y/N) 3.00 N 3.00 N 4.00 N 3.00 N 3.00 N 3.00 N 4.00 N 5.00 N 3.00 N 5.00 N 6.00 N 3.00 N 6.00 N 4.00 N 3.00 N 3.00 N 4.00 N 3.00 N 2.00 N 6.00 N 1.00 N 1.00 N 6000 N 14.00 N 3.00 N 6.00 N Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems The pressure in the North Plant High Pressure Knock Out Drum (D-0768) increased. The excess pressure was relieved to the North Plant Flare, resulting in emissions to exceed the NSPS Ja 162 ppm H2S 3-hour rolling average. FL-400 CEMS H2S 12/15/2018 17:00 12/15/2018 23:00 6.00 Unexpected shutdown of the Amine Unit Contactor, resulting in increase of the H2S N Process Problems concentrations in the FGS and flare vent gas to exceed the NSPS Ja 162 ppm H2S 3- hour rolling average. Corrective Action Taken or Preventative Measure Adopted In an effort to minimize emissions, an H7S scavenger agent was injected at maximum rate. Process adjustments were promptly made to establish normal operating conditions in the ,Amine Contactors. The ,Amine contactors resume the H2S removal from the FGS, allowing the concentrations to decrease below the reportable limit. FL-400 CEMS H2S 12/16/2018 15:00 12/16/2018 22:00 7.00 y FL-400 CEMS H2S 12/17/2018 23:00 12/18/2018 02:00 3.00 N FL-400 CEMS H2S 12/23/2018 07:00 12/23/2018 16:00 9.00 N FL-400 CEMS H2S 12/25/2018 07:00 12/25/2018 11 :00 4.00 N FL-400 CEMS H2S 12/26/2018 13:00 12/26/2018 20:00 7.00 N FL-400 CEMS H2S 12/26/2018 23:00 12/2//2018 00:00 1.00 N FL-400 CEMS H2S 12/28/2018 02:00 12/28/2018 07:00 5.00 N FL-400 CEMS H2S 12/28/2018 23:00 12/29/2018 00:00 1.00 N FL-400 CEMS H2S 12/31/201812:00 12/31/201817:00 5.00 N 1ora1 404.00 Startup Naphtha Hydrotreater ( Unit 13) startup after repairs in the unit. During startup Splitter Distillate Drum (D-0044) is normally vented to flare until the operating conditions to complete startup area attained. Venting from D-0044 resulted in excess of the NSPS Ja 162 ppm H2S 3-hour rolling average The unit was restarted and venting to flare ended. Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems The pressure in the North Plant High Pressure Knock Out Drum (D-0768) increased The excess pressure was relieved to the North Plant Flare, resulting in emissions to exceed the NSPS Ja 162 ppm H7S 3-hour rolling average. In an effort to minimize emissions, an H2S scavenger agent was injected at maximum rate. HFNA-000003187 EPA Inspection Report - Page 1638 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja - 500 lb S02 24-hour rolling average Artesia North Plant Flare, FL-0400 60.103a Design, equipment, work practice or operational standards (c) Except as provided in paragraphs (t) and (g) of this section, each owner or operator that operates a flare subject to this subpart shall conduct a root cause analysis and a corrective action analysis for each of the conditions specified in paragraphs (c)(l) of this section. (1) For a flare: (i) Any time the S02 emissions exceed 227 kilograms (kg) (500 lb) in any 24-hour period; or 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. (a) Fuel gas combustion devices subject to S02 or II2S limit and flares subject to II2S concentration requirements. (2) The owner or operator of a fuel gas combustion device that elects to comply with the II2S concentration limits in 60.102a(g)(1)(ii) or a flare that is subject to the II2S concentration requirement in 60.103a(h) shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration by volume (dry basis) of II2S in the fuel gases before being burned in any fuel gas combustion device or flare. (3) The owner or operator of a fuel gas combustion device or flare is not required to comply with paragraph (a)(l) or (2) of this section for fuel gas streams that are exempt under 60.102a(g)(1)(iii) or 60.103a(h) or, for fuel gas streams combusted in a process heater, other fuel gas combustion device or flare that are inherently low in sulfur content. (e) Su(f'ur monitoringfor assessing root cause analysis thresholdfor affectedflares. Except as described in paragraphs (e)(4) and (h) of this section, the owner or operator of an affected flare subject to 60.103a(c) through (e) shall determine the total reduced sulfur concentration for each gas line directed to the affected flare in accordance with either paragraph (e)(l), (e)(2) or (e)(3) of this section. (1) Total reduced sulfur monitoring requirements. The owner or operator shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration of total reduced sulfur in gas discharged to the flare. Flare FL-400 is subject to the 500 lbs S02 threshold monitoring requirements. Navajo maintains a CEMS for continuously measuring the concentration of total reduced sulfur in gas discharged to the flare. HFNA-000003188 EPA Inspection Report - Page 1639 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report North Plant Flare (FL-0400) FL-400 500 lb S0 2 CEMS Summary Affected Source Emission Limit Citation FL-400 North Flare 60.107a(e)(1) Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit ThermoScientific - SOLA II SL-10040914 12/07/2018 Reporting Period Beginning Date Reporting Period Ending Date 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime Total Source Operating Time in Reporting Period (hours) (hours) (hours) 4416 0 4416 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Number of Incidents 0 0 184 8 0 Duration (Hours) 0.00 0.00 0.00 22.00 0.00 Totals Total CMS Downtime as a Percent of Total Source Operating Time Emission Data Summary Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Totals Total Duration of Deviations as a Percent of Total Source Operating Time 192 Number of Incidents 0 0 0 2 2 0 4 22.00 0.50% Duration (Hours) 0.00 0.00 0.00 60.00 69.00 0.00 129.00 2.92% HFNA-000003189 EPA Inspection Report - Page 1640 of 1969 HdlyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report North Plant Flare (FL-0400) FL-400 500 lb S02 CEMS Downtime CEMS Downtime Affected Monitor Source Name Type Monitored HAP or Gas Downtime start Date and Time Downtime End Date and Time Duration of Downtime (hours) Type of Downtime Period FL-400 CEMS so, 08/23/2018 09:44 08/23/2018 12:09 2.00 Other Known Cause Type of Cause of Deviation Brief Description of Cause of Downtime Corrective Action Taken other The analyzer was placed in maintenance mode to perform a CGA. !The l&E technician performed a CGA and returned !the analyzer to service. Changes to Emission Control 60.1D8a(d)(6) No changes were made in operation of the emission control system. FL-400 CEMS so, 08/23/201813:10 08/23/2018 15:00 2.00 Other Known Cause Other The analyzer was placed in maintenance mode to perform a CGA The l&E technician performed a CGA and returned the analyzer to service No changes were made in operation of the emission control system. FL-400 CEMS so, 09/14/2018 08:37 09/14/201811:23 2.00 Other Known Cause Other The analyzer was placed in maintenance mode to determine cause of low sample flow. The l&E technician flushed and cleared the sample line and returned the analyzer to service. No changes were made in operation of the emission control system. FL-400 CEMS FL-400 CEMS FL-400 CEMS FL-400 CEMS FL-400 CEMS so, 10/23/2018 10:55 10/23/201811:05 0.00 so, 10/30/2018 08:30 10/30/2018 09:46 1.00 so, 11/27/2018 09 00 11/27/2018 1600 7.00 so, 11/28/2018 1300 11/28/2018 1600 3.00 so, 12/07/2018 09:10 12/07/2018 14:00 5.00 Total 22.00 Other Known Cause Other Known Cause Other Known Cause Other Known Cause Other Known Cause Other other other other other The analyzer was placed in maintenance mode to perform routine maintenance. The l&E technician changed the probe filter and returned the analyzer to service No changes were made in operation of the emission control system. The analyzer was placed in maintenance mode for routine maintenance. The E&I technician changed out the Genie, the water carry over, and the probe filters and returned the analyzer back to service. No changes were made in operation of the emission control system. The analyzer was placed in maintenance mode due The l&E technician proceeded with the RSR project to project tie-in tie-ins and returned the analyzer to service. No changes were made in operation of the emission control system. The analyzer was placed in maintenance mode to perform a linearity test The l&E technician performed a linearity test and returned the analyzer to service. No changes were made in operation of the emission control system. The analyzer was placed in maintenance mode to perform a CGA. The l&E technician performed a CGA and returned the analyzer to service. No changes were made in operation of the emission control system. HFNA-000003190 EPA Inspection Report - Page 1641 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report for North Plant Flare (FL-0400) FL-400 500 lb S02 Excess Emissions GEMS Monitored Excess Emissions Affected Source Name Monitored Monitor HAP or Type Gas Excess Emissions Duration of Emissions Start Date and Excess Emissi~ns Deviation Occurred During Time End Date and Time (hours) Period of SSM Du~!~;si~fn:~~ess repo~~n:t~~riod Brief Description of Nature and Cause of Excess Emission Corrective Action Taken or Preventative Measure Adopted Discharges Per 60.108a(d)(5) FL-400 GEMS S0 2 09/24/2018 07:00 09/24/2018 23:00 16.00 N !Other Known Cause Unexpected shutdown of the Naphtha Hydrotreating Unit (Unit 13) c - - - - t - - - - - t - - - - c - - - - - - - - - t - - - - - - - - t - - - - c - - - - - t - - - - - - - - - - i d u e to a flange leak. This caused the Naphtha Separator (D-0058) The flange was repaired. The gas was safely combusted in a steam-assisted and Splitter Distillate (D-0044) to vent to the North Flare (FL-0400), flare and scavenger was injected into the system FL-400 GEMS S02 09/25/201814:00 09/27/201819:00 53.00 N !Other Known Cause resulting in emissions above the reporting threshold. See Attached Event Record: ''#4-2018-10-08 NSPS Ja RCA S02 FL-0400" The standard procedure for unit shutdown was followed. After the unit shutdown FL-400 GEMS so, 11/08/201818:00 11/09/201818:00 24.00 N Process Problems was completed. Feed Preheater (X-0342) was by-passed for inspection and Process imbalance in the NHU debutanizer system, which included cleaning, as needed. After the exchanger was isolated and by-passed, the a pressure increase in the splitter overhead system, and resulted in Naphtha Hydrotreating Unit (NHU, Unit 13) was started up and was returned to c - - - - , - - - - - t - - - - c - - - - - - - - - t - - - - - - - - t - - - - c - - - - - - , - - - - - - - - - - i v e n t i n g of overhead gases with high sulfur (S) content from the normal operation as expeditiously as possible. Additional corrective actions may Splitter Distillate Drum (D-0044). The associated flare emissions be implemented pending the outcome of the above-described further root cause FL-400 GEMS so, 12/07/2018 22:00 12/09/201810:00 36.00 exceeded 500 pounds of sulfur dioxide (S02) on a 24-hour basis. analysis for the Feed Preheater (X-0342), and an update will be submitted within N Process Problems thirty days after completion of the implementation of any such additional corrective actions See Attached Event Record: ''#5-2018-11-26 FL-0400 NSPS Ja S02 RCA"" See Attached Event Record: ''#6-2018-12-27 NSPS Ja RCA S02 FL-0400" Total 129.00 HFNA-000003191 EPA Inspection Report - Page 1642 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja Artesia South Plant Flare, FL-40 l 60.lOOa Applicability, designation of affected facility, and reconstruction. (b) For flares, the provisions of this subpart apply only to flares which commence construction, modification or reconstruction after June 24, 2008. 60.101a Definitions. Terms used in this subpart are defined in the Clean Air Act (CAA), in 60.2 and in this section. Emergency flare means a flare that combusts gas exclusively released as a result of malfunctions (and not startup, shutdown, routine operations or any other cause) on four or fewer occasions in a rolling 365-day period. For purposes of this rule, a flare cannot be categorized as an emergency flare unless it maintains a water seal. Non-emergency flare means any flare that is not an emergency flare as defined in this subpart. Flare FL-40 l is a Non-emergency flare. Modification or reconstrnction occurred on Flare FL-40 l after June 24, 2008. Therefore FL-4010 is subject to NSPS Subpart Ja. HFNA-000003192 EPA Inspection Report - Page 1643 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja - 500 M SCF 24-hour rolling average Artesia South Plant Flare, FL-40 l 60.103a Design, equipment, work practice or operational standards (a) Except as provided in paragraph (g) of this section, each owner or operator that operates a flare that is subject to this subpart shall develop and implement a written flare management plan no later than the date specified in paragraph (b) of this section. The flare management plan must include the information described in paragraphs (a)(l) through (7) of this section. compressor staging and a justification for why the maximum time period cannot be further reduced. (4) An evaluation of the baseline flow to the flare. The baseline flow to the flare must be determined after implementing the minimization assessment in paragraph (a)(2) of this section. Baseline flows do not include pilot gas flow or purge gas flow (i.e., gas introduced after the flare's water seal) provided these gas flows remain reasonably constant (i.e., separate flow monitors for these streams are not required). Separate baseline flow rates may be established for different operating conditions provided that the management plan includes: (c) Except as provided in paragraphs (t) and (g) of this section, each owner or operator that operates a flare subject to this subpart shall conduct a root cause analysis and a corrective action analysis for each of the conditions specified in paragraphs (c)(l) of this section. (1) For a flare: (ii) Any discharge to the flare in excess of 14,160 standard cubic meters (m3) (500,000 standard cubic feet (set)) above the baseline, determined in paragraph (a)(4) of this section, in any 24-hour period. 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. (t) Flow monitoring for flares. Except as provided in paragraphs (t)(2) and (h) of this section, the owner or operator of an affected flare subject to 60.103a(c) through (e) shall install, operate, calibrate and maintain, in accordance with the specifications in paragraph (t)(l) of this section, a CPMS to measure and record the flow rate of gas discharged to the flare. (1) The owner or operator shall install, calibrate, operate and maintain each flow monitor according to the manufacturer's procedures and specifications and the following requirements. (iv) At least quarterly, perform a visual inspection of all components of the monitor for physical and operational integrity and all electrical connections for oxidation and galvanic corrosion if the flow monitor is not equipped with a redundant flow sensor. (v) Recalibrate the flow monitor in accordance with the manufacturer's procedures and specifications biennially (every two years) or at the frequency specified by the manufacturer. Flare FL-40 l is subject to the reporting threshold of 500 MSCF above the flow baseline in a 24-hour period. Navajo maintains a flow monitor for continuously measuring the flow to the flare. The Flare Management Plan submitted on November 11, 2015 established the baseline flow for FL-40 l as 64,511 standard cubic feet per day (SCFD; where a day is any 24-hour period). Per 40 CFR 60.103a(c)(l)(ii), the threshold for an RCA and corrective action plan is 564,511 SCF in any 24-hour period. HFNA-000003193 EPA Inspection Report - Page 1644 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report South Plant Flare (FL-0401) FL-401 500M SCF CEMS Summary Affected Source FL-401 South Flare Emission Limit Citation Emission Limitation (SCF over baseline in rolling 24 hours) 60.103a(c)(1)(ii) 500,000 Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit General Electric - GF868-2-11 4384 10/17/2017 Reporting Period Beginning Date Reporting Period Ending Date 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime Total Source Operating Time in Reporting Period (hours) (hours) (hours) 4416 0 4416 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Total CMS Downtime as a Percent of Total Source Totals Operating Time Number of Incidents 16 0 0 0 0 16 Duration (Hours) 40.00 0.00 0.00 0.00 0.00 40.00 0.91% Emission Data Summary (Exceeds 500,000 SCF over baseline in rolling 24 hours) Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Totals Total Duration of Deviations as a Percent of Total Source Operating Time Number of Incidents 0 0 0 0 0 0 0 Duration (Hours) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00% HFNA-000003194 EPA Inspection Report - Page 1645 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report South Plant Flare (FL-0401) FL-401 Flowmeter Downtime CMS Downtime Affected Source Name Monitor Type Monitored HAP or Gas Downtime Start Date and Time Downtime End Date and Time FL-401 Flowmeter SCF 07/06/2018 09:00 07/06/2018 11 :45 FL-401 Flowmeter SCF 07/11/201811:30 07/11/201811:45 FL-401 Flowmeter SCF 07/12/2018 07:15 07/12/2018 09:15 FL-401 Flowmeter SCF 07/17/2018 14:15 07/17/2018 15:00 FL-401 Flowmeter SCF 07/29/2018 15:15 07/29/2018 15:30 FL-401 Flowmeter SCF 08/14/2018 17:00 08/14/2018 18:00 FL-401 Flowmeter SCF 08/21/201811:00 08/21/2018 12:00 FL-401 Flowmeter SCF 10/01/201813:30 10/01/2018 16:30 FL-401 Flowmeter SCF 10/10/2018 09:00 10/10/2018 10:30 Duration of Dovvntime (hours) 2.75 Type of Downtime Period Type of Cause of Deviation Brief Description of Cause of Downtime Corrective Action Taken Changes to Emission Control 60.108a(d)(6) Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to an analyzer malfunction. The l&E technician performed maintenance to correct an analyzer malfunction, and the analyzer No changes were made in operation was returned to service. of the emission control system. 0.25 Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to an analyzer malfunction. The l&E technician performed maintenance to No changes were made in operation correct an analyzer malfunction, and the analyzer of the emission control system. was returned to service. 2.00 0.75 0.25 Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to an analyzer malfunction. The l&E technician performed maintenance to correct an analyzer malfunction, and the analyzer No changes were made in operation was returned to service. of the emission control system. Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to an analyzer malfunction. The l&E technician performed maintenance to correct an analyzer malfunction, and the analyzer No changes were made in operation was returned to service. of the emission control system. Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to an analyzer malfunction The l&E technician performed maintenance to correct an analyzer malfunction, and the analyzer No changes were made in operation was returned to service. of the emission control system. 1.00 Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to an analyzer malfunction. The l&E technician performed maintenance to correct an analyzer malfunction, and the analyzer No changes were made in operation was returned to service. of the emission control system. 1.00 3.00 Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to an analyzer malfunction. The l&E technician performed maintenance to No changes were made in operation correct an analyzer malfunction, and the analyzer of the emission control system. was returned to service. Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to an analyzer malfunction The l&E technician performed maintenance to No changes were made in operation correct an analyzer malfunction, and the analyzer of the emission control system. was returned to service. 1.50 Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to an analyzer malfunction. The l&E technician performed maintenance to No changes were made in operation correct an analyzer malfunction, and the analyzer of the emission control system. was returned to service. FL-401 Flowmeter SCF 11/06/2018 09:00 11/06/201813:45 4.75 Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to an analyzer malfunction. The l&E technician performed maintenance to correct an analyzer malfunction, and the analyzer No changes were made in operation was returned to service. of the emission control system. FL-401 Flowmeter SCF 11/30/2018 14:00 11/30/201818:15 4.25 Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to an analyzer malfunction. The l&E technician performed maintenance to No changes were made in operation correct an analyzer malfunction, and the analyzer of the emission control system. was returned to service. FL-401 Flowmeter SCF 12/03/2018 09:45 12/03/2018 14:15 FL-401 Flowmeter SCF 12/05/2018 08:15 12/05/2018 15:15 FL-401 Flowmeter SCF 12/07/201811:15 12/07/2018 15:15 4.50 7.00 4.00 Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to an analyzer malfunction The l&E technician performed maintenance to No changes were made in operation correct an analyzer malfunction, and the analyzer of the emission control system. was returned to service. Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to an analyzer malfunction. The l&E technician performed maintenance to correct an analyzer malfunction, and the analyzer No changes were made in operation was returned to service. of the emission control system. Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to an analyzer malfunction The l&E technician performed maintenance to correct an analyzer malfunction, and the analyzer No changes were made in operation was returned to service. of the emission control system. HFNA-000003195 EPA Inspection Report - Page 1646 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report South Plant Flare (FL-0401) FL-401 Flowmeter Downtime Affected Source Name Monitor Type Monitored Downtime HAP or Gas Start Date and Time Downtime End Date and Time FL-401 Flowmeter SCF 12/1012018 09:45 12/10/201811:00 Duration of DoVvTitime (hours) 1.25 Type of Downtime Type of Cause Brief Description of Cause of Downtime Period of Deviation Corrective Action Taken Changes to Emission Control 60.108a(d)(6) Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance The l&E technician performed maintenance to No changes were made in operation mode due to an analyzer malfunction. correct an analyzer malfunction, and the analyzer of the emission control system. was returned to service. FL-401 Flowmeter SCF 12/28/2018 09:15 12/2812018 10:30 Total 1.25 40.00 Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance The l&E technician performed maintenance to No changes were made in operation mode due to an analyzer malfunction correct an analyzer malfunction, and the analyzer of the emission control system. was returned to service. HFNA-000003196 EPA Inspection Report - Page 1647 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report South Plant Flare (FL-0401) CMS Deviations Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions Start Date and Time Excess Emissions Duration of End Date and Time Deviation (hours) Excess Emissions Occurred During Period of Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission FL-401 500M SCF Deviations Corrective Action Taken or Preventative Measure Adopted Discharges Per 60.108a(d)(5) iNo deviations - There were no discharges to the South FL-401 Flowmeter SCF NA NA 000 NA NA 1P Flare (FL-0401) in excess of 500,000 standard NA NA jcubic feet (scf) above the baseline in any 24-hour jperiod Total 000 HFNA-000003197 EPA Inspection Report - Page 1648 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja - 162 ppmvd H2S 3-hour rolling average Artesia South Plant Flare, FL-401 60.103a Design, equipment, work practice or operational standards (h) Each owner or operator shall not burn in any affected flare any fuel gas that contains H2S in excess of 162 ppmv determined hourly on a 3-hour rolling average basis. The combustion in a flare of process upset gases or fuel gas that is released to the flare as a result of relief valve leakage or other emergency malfunctions is exempt from this limit. 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. (a) Fuel gas combustion devices subject to S02 or H2S limit and flares subject to H2S concentration requirements. (2) The owner or operator of a fuel gas combustion device that elects to comply with the H2S concentration limits in 60.102a(g)(1)(ii) or a flare that is subject to the H2S concentration requirement in 60.103a(h) shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration by volume (dry basis) of H2S in the fuel gases before being burned in any fuel gas combustion device or flare. (3) The owner or operator of a fuel gas combustion device or flare is not required to comply with paragraph (a)(l) or (2) of this section for fuel gas streams that are exempt under 60.102a(g)(1)(iii) or 60.103a(h) or, for fuel gas streams combusted in a process heater, other fuel gas combustion device or flare that are inherently low in sulfur content. (e) Su(f'ur monitoringfor assessing root cause analysis thresholdfor affectedflares. (2) H2S monitoring requirements. The owner or operator shall install, operate, calibrate, and maintain an instrument for continuously monitoring and recording the concentration of H2S in gas discharged to the flare according to the requirements in paragraphs (e)(2)(i) through (iii) of this section and shall collect and analyze samples of the gas and calculate total sulfur concentrations as specified in paragraphs (e)(2)(iv) through (ix) of this section. Flare FL-401 is subject to the 162 ppmv hydrogen sulfide (H2S) limit. Therefore, Navajo maintains an H 2S CEMS on Flare FL-401 that records concentrations in parts per million by volume on a dry basis (ppmvd). Note: 60. l03a(h) exempts process upset gases and releases resulting from relief valve leakage or other emergency malfm1ctions from the requirement to meet the 162 ppm (H2S) limit. In this report we have included infonnation on these events subject to exemptions, and have identified them as such. HFNA-000003198 EPA Inspection Report - Page 1649 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report South Plant Flare (FL-0401) FL-401 H2S CEMS Summary Affected Source Emission Limit Citation Emission Limitation (H2S ppmv on rolling 3-hours) FL-401 South Flare 60.103a(h) 60.107a( e)(2) 162 Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit Reporting Period Beginning Date Reporting Period Ending Date Total Time in Reporting Period Total Source Downtime Total Source Operating Time in Reporting Period Siemens - Maxum II 30049702230200 01/26/2018 07/01/2018 12/31/2018 (hours) (hours) (hours) 4416 0 4416 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Totals Total CMS Downtime as a Percent of Total Source Operating Time Number of Incidents 1 2 184 9 0 196 Duration (Hours) 2.00 4.00 0.00 38.00 0.00 44.00 1.00% Emission Data Summary (Exceeds 162 H2S ppmv on rolling 3-hours) Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Totals Total Duration of Deviations as a Percent of Total Source Operating Time Number of Incidents 0 0 0 1 0 6 7 Duration (Hours) 0.00 0.00 0.00 6.00 0.00 179.00 185.00 4.19% HFNA-000003199 EPA Inspection Report - Page 1650 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report South Plant Flare (FL-0401) FL-401 H2S CEMS Downtime GEMS Downtime Affected Source Name Monitor Type Monitored HAP or Gas Downtime Start Date and Time Downtime End Date and Time FL-401 GEMS H2S 07/06/2018 08:18 07/06/201811:30 FL-401 GEMS H2S 07/12/2018 06:38 07/12/2018 09:36 Duration of DoV\111time (hours) 2.00 2.00 Type of Downtime Type of Cause Period of Deviation Brief Description of Cause of Downtime Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due to sample system low flow. Other Known Cause Other The analyzer was placed in maintenance mode to perform maintenance Corrective Action Taken Changes to Emission Control 60.108a(d)(6) iThe l&E technician removed the sample valves and imanifold and took back to shop. The valves and imanifold were tested and some restrictions were iremoved. The system was reassembled and the janalyzer returned to service. No changes were made in operation of the emission control system !The l&E technician repaired the Circo Valve going No changes were made in operation of !to the Siemens GC oven, and returned the analyzer the emission control system. ito service. FL-401 GEMS H2S 07/17/2018 13:35 07/17/2018 14:51 1.00 Other Known Cause Other The analyzer was placed in maintenance mode for maintenance. !The l&E technician replaced the sample inlet vale iand returned the analyzer to service. No changes were made in operation of the emission control system. FL-401 GEMS H2S 08/21/2018 09:55 08/21/2018 15:35 5.00 Other Known Cause Other The analyzer was placed in maintenance !The l&E Technician performed a CGA and returned No changes were made in operation of mode to perform a CGA !the analyzer to service. the emission control system FL-401 GEMS H2S 10/09/2018 10:30 10/09/2018 12:30 1.00 FL-401 GEMS H2S 11/05/201813:20 11/05/201817:30 3.00 Non-Monitor Equipment Malfunction Non-Monitor Equipment Malfunction Malfunction The analyzer was placed into maintenance mode by error !The l&E technician accidentally shut down the !breaker GC oven while working on the TRS !analyzer. When the error was found the breaker !was reset, oven came back to temperature and the !analyzer returned to service No changes were made in operation of the emission control system. Malfunction The analyzer was doV\111 due a communication !The communications was reestablished and the failure with the data server janalyzer returned to service. No changes were made in operation of the emission control system FL-401 GEMS H2S 11/06/2018 08:25 11/06/201814:00 FL-401 GEMS H2S 11/30/201813:00 11/30/201818:30 5.00 5.00 Other Known Cause Other Known Cause Other Other The analyzer was placed in maintenance !The pump was changed out, the tie-ins for the RSR No changes were made in operation of mode to change out pump and make the RSR jproject completed, and the analyzer was the emission control system. project tie-ins. iretu to service The analyzer was placed in maintenance mode to perform maintenance !The l&E technician performed maintenance on !Va GEMS lines and returned the analyzer to !service. No changes were made in operation of the emission control system. FL-401 GEMS H2S 12/03/2018 09:02 12/03/2018 14:15 The analyzer was placed in maintenance !The l&E technician flushed the flare header When No changes were made in operation of 5.00 Other Known Cause Other mode to flush the flare header ,,ci,, ''"""' ,ci, '""" was completed the analyzers were the emission control system. iretu to service FL-401 GEMS H2S 12/05/2018 07:15 12/05/2018 15:08 8.00 Other Known Cause Other The analyzer was placed in maintenance mode to flush the flare header !The l&E technician flushed the flare header When , ,c.,,, '"'"'' 'C<' '"'"' was completed the analyzers were iretu to service. No changes were made in operation of the emission control system FL-401 GEMS H2S 12/07/2018 09:35 12/07/2018 15:15 FL-401 GEMS H2S 12/10/2018 09:10 12/10/201811 00 Total The analyzer was placed in maintenance !The l&E technician flushed the flare header When No changes were made in operation of 5.00 Other Known Cause Other mode to flush the flare header ,''='" "'"'' ''=''''"''"'was completed the analyzers were the emission control system iretu to service. 2.00 44.00 Other Known Cause Other The analyzer was placed in maintenance mode to perform a CGA !The l&E Technician performed a CGA and returned No changes were made in operation of ithe analyzer to service. the emission control system. HFNA-000003200 EPA Inspection Report - Page 1651 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report South Plant Flare (FL-0401) FL-401 H2S Excess Emissions CEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored Excess Emissions HAP or Gas Start Date and Time Excess Emissions End Date and Time Excess Duration of Emissions Deviation Occurred (hours) During Period of SSM (Y/N) Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission Corrective Action Taken or Preventative Measure Adopted FL-401 CEMS H2S 11/08/2018 12:00 11/08/2018 18:00 6.00 FL-401 CEMS FL-401 CEMS FL-401 CEMS FL-401 CEMS FL-401 CEMS FL-401 CEMS H2S 11/30/2018 22:00 12/03/2018 13:00 63.00 H2S 12/03/2018 19:00 12/04/2018 16:00 21.00 H2S 12/04/2018 19:00 12/05/2018 11 :00 16.00 H2S 12/05/2018 18:00 12/07/2018 14:00 44.00 H2S 12/07/2018 19:00 12/08/2018 15:00 20.00 H2S 12/08/2018 20:00 12/09/2018 11 :00 15.00 Total 185.00 Emissions from the South Plant Flare (FL-0401) N Process exceeded 162 ppm H2S, on a 3-hour rolling average The pressure in surge drum was reduced, Problems basis due lo a relief valve on a surge drum lifting during allowing the relief valve lo reseat. a unit upset. N Other Unknown Cause N Other Unknown Cause The emissions from FL-0401 began lo increase. H 2S Other Unknown scavenger was injected al maximum rate, with no Operations immediately began injecting H 2S N Cause reduction in emissions observed. Upon investigation, an Scavenger at the maximum rate. Operations obstruction as identified in the flare header. The flare then coordinated with maintenance personnel N Other Unknown header was lanced lo remove the obstruction, allowing and outside contractors to lance the flare Cause the emissions to decrease below 162 ppm H 2S, on a 3- header and remove the debris. N Other Unknown hour rolling average basis. Cause N Other Unknown Cause HFNA-000003201 EPA Inspection Report - Page 1652 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja - 500 lb S02 24-hour rolling average Artesia South Plant Flare, FL-40 l 60.103a Design, equipment, work practice or operational standards (c) Except as provided in paragraphs (t) and (g) of this section, each owner or operator that operates a flare subject to this subpart shall conduct a root cause analysis and a corrective action analysis for each of the conditions specified in paragraphs (c)(l) of this section. (1) For a flare: (i) Any time the S02 emissions exceed 227 kilograms (kg) (500 lb) in any 24-hour period; or 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. (a) Fuel gas combustion devices subject to S02 or II2S limit and flares subject to II2S concentration requirements. (2) The owner or operator of a fuel gas combustion device that elects to comply with the II2S concentration limits in 60.102a(g)(1)(ii) or a flare that is subject to the II2S concentration requirement in 60.103a(h) shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration by volume (dry basis) of II2S in the fuel gases before being burned in any fuel gas combustion device or flare. (3) The owner or operator of a fuel gas combustion device or flare is not required to comply with paragraph (a)(l) or (2) of this section for fuel gas streams that are exempt under 60.102a(g)(1)(iii) or 60.103a(h) or, for fuel gas streams combusted in a process heater, other fuel gas combustion device or flare that are inherently low in sulfur content. (e) Su(f'ur monitoringfor assessing root cause analysis thresholdfor affectedflares. Except as described in paragraphs (e)(4) and (h) of this section, the owner or operator of an affected flare subject to 60.103a(c) through (e) shall determine the total reduced sulfur concentration for each gas line directed to the affected flare in accordance with either paragraph (e)(l), (e)(2) or (e)(3) of this section. (1) Total reduced sulfur monitoring requirements. The owner or operator shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration of total reduced sulfur in gas discharged to the flare. Flare FL-40 l is subject to the 500 lbs S02 threshold monitoring requirements. Navajo maintains a CEMS for continuously measuring the concentration of total reduced sulfur in gas discharged to the flare. HFNA-000003202 EPA Inspection Report - Page 1653 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report South Plant Flare (FL-0401) FL-401 500 lb S0 2 CEMS Summary Affected Source FL-401 South Flare Emission Limit Citation 60.107a(e)(1) Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit ThermoScientific - SOLA 11 SL10071014 12/28/2018 Reporting Period Beginning Date Reporting Period Ending Date 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime Total Source Operating Time in Reporting Period (hours) (hours) (hours) 4416 0 4416 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Number of Incidents 5 1 185 11 0 Duration (Hours) 73.00 3.00 2.00 45.00 0.00 Totals 202 Total CMS Downtime as a Percent of Total Source Operating Time 123.00 2.79% Emission Data Summary Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Totals Total Duration of Deviations as a Percent of Total Source Operating Time Number of Incidents 0 0 0 0 0 0 0 Duration (Hours) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00% HFNA-000003203 EPA Inspection Report - Page 1654 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report South Plant Flare (FL-0401) FL-401 500 lb S02 CEMS Downtime CEMS Downtime Affected Source Name Monitor Type Monitored Downtime HAP or Start Date and Time Gas Downtime End Date and Time Duration of Downtime {hours) Type of Downtime Period Type of Cause of Deviation Brief Description of Cause of Downtime FL-401 CEMS so, 07/06/2018 08:18 07/06/201811:30 2.00 Monitor Equipment Malfunction The analyzer was placed in maintenance mode due to Malfunction sample system low flow. Corrective Action Taken The l&E technician removed the sample valves and manifold for inspection. The valves and manifold were tested and updated restrictions. The system was reassembled and the analyzer was returned to service. Changes to Emission Control 60.108a(d)(6) No changes were made in operation of the emission control system. FL-401 FL-401 FL-401 CEMS so, 07/17/201813:35 07/17/201814:51 CEMS so, 07/29/201814:15 07/29/201816:19 CEMS so, 08/17/2018 13:20 08/17/201815:04 1.00 Other Known Cause Other The analyzer was placed in maintenance mode for maintenance. The l&E technician replaced the sample inlet vale and returned the analyzer to service No changes were made in operation of the emission control system. 2.00 Quality Assurance Other The analyzer was placed in calibration mode for data Calibration revalidation. The IE technician observed an unexpected shift in the calibration numbers. The data was revalidated. and the analyzer was returned to service. No changes were made in operation of the emission control system. 1.00 Other Known Cause Other The analyzer was placed in maintenance mode due to a The l&E technician replaced the rotors and checked the clean air flow, No changes were made in operation suspected calibration failure. recalibrated and returned the analyzer to service. of the emission control system. FL-401 FL-401 FL-401 CEMS CEMS CEMS so, 08/21/2018 09:55 08/21/201815:35 5.00 Other Known Cause Other The analyzer was placed in maintenance mode to perform a The l&E technician performed a CGA and returned the analyzer to CGA service. No changes were made in operation of the emission control system. S02 09/25/2018 04:30 09/26/2018 09:44 30.00 Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due to new equipment communication failure. The l&E technician disconnected the new equipment and recalibrated. and returned the analyzer to service. No changes were made in operation of the emission control system. so, 10/09/2018 04:30 10/09/201815:48 11.00 Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due to suspected calibration failure. The l&E technician replaced the 1Oport rotor and valve, shutting down the GC oven by accident. The GC was restarted, recalibrated, and returned to service. No changes were made in operation of the emission control system. FL-401 FL-401 FL-401 FL-401 FL-401 FL-401 CEMS CEMS CEMS CEMS CEMS CEMS so, 10/10/2018 08:15 10/10/201810:15 so, 10/10/2018 04:30 10/11/2018 08:10 S02 10/19/2018 08:40 10/19/201811:55 so, 11/05/201813:20 11/05/201817:30 so, 11/06/2018 08:25 11/06/201814:00 so, 11/30/201813:00 11/30/201818:30 2.00 Monitor Equipment Malfunction The analyzer was placed in maintenance mode due to a leak The l&E technician located and repaired the leak on the 1Oport valve, No changes were made in operation Malfunction in the sample system. and returned the analyze to service. of the emission control system. 28.00 Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due to a failed calibration The l&E technician recalibrated and returned the analyzer to service. No changes were made in operation of the emission control system. 3.00 Other Known Cause Other The analyzer was placed in maintenance mode due to potential contamination of the pyrolizer tube. The l&E technician replaced the pyrolizer tube. recalibrated and returned the analyzer to service. No changes were made in operation of the emission control system. Non-Monitor The analyzer shut down due to loss of communication with The communication was reestablished and the analyzer was returned to No changes were made in operation 3.00 Equipment Malfunction the data server during installation of equipment for RSR service of the emission control system Malfunction project. 5.00 Other Known Cause Other The analyzer is placed in maintenance mode to replace the The pump was replaced, the tie-ins for the RSR project were completed, No changes were made in operation sample pump and complete the RSR project tie-ins. and the analyzer was returned to service. of the emission control system. 5.00 Other Known Cause Other The analyzer was placed in maintenance mode to perform The l&E technician cleared various system lines, and returned the routine maintenance analyzer to service. No changes were made in operation of the emission control system FL-401 CEMS S02 12/03/2018 09:02 12/03/201814:15 5.00 Other Known Cause Other The analyzer was placed in maintenance mode to flush the The l&E technician flushed the flare header. When maintenance was No changes were made in operation flare header completed the analyzer was returned to service of the emission control system. FL-401 CEMS so, 12/05/2018 07:15 12/05/201815:08 8.00 Other Known Cause Other The analyzer was placed in maintenance mode to flush the The l&E technician flushed the flare header. When maintenance was No changes were made in operation flare header. completed the analyzer was returned to service. of the emission control system. FL-401 CEMS so, 12/07/2018 09:35 12/07/201815:15 5.00 Other Known Cause Other The analyzer was placed in maintenance mode to flush the The l&E technician flushed the flare header. When maintenance was No changes were made in operation flare header completed the analyzer was returned to service of the emission control system. HFNA-000003204 EPA Inspection Report - Page 1655 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report South Plant Flare (FL-0401) FL-401 500 lb S02 CEMS Downtime Affected Source Name Monitor Type Monitored HAP or Downtime Gas Start Date and Time Downtime End Date and Time Duration of Downtime (hours) Type of Downtime Period Type of Cause of Deviation Brief Description of Cause of Downtime Corrective Action Taken FL-401 CEMS so, 12/10/2018 09:10 12/10/201811:00 2.00 Other Known Cause Other The analyzer was placed in maintenance mode to perform a The l&E Technician performed a CGA and returned the analyzer to CGA service. Changes to Emission Control 60.108a(d)(6) No changes were made in operation of the emission control system. FL-401 CEMS S02 12/28/2018 08:45 12/28/201813:48 5.00 Other Known Cause Other The analyzer was placed into maintenance mode to perform The l&E Technician performed a CGA and returned the analyzer to a CGA service. No changes were made in operation of the emission control system. Total 123.00 HFNA-000003205 EPA Inspection Report - Page 1656 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery CEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions Start Date and Time Excess Emissions End Date and Time Duration of Deviation (hours) Excess Emissions Occurred During Period of NSPS Subpart Ja Periodic Report South Plant Flare (FL-0401) Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission FL-401 CEMS so, NA NA Total NA NA 0.00 NA No deviations - Flare FL-0401 did not exceed 500 lbs of S0 2 in any 24-hour period during this reporting period. FL-401 500 lb so, Excess Emissions Corrective Action Taken or Preventative Measure Adopted NA Discharges Per 6D.108a(d)(5) NA HFNA-000003206 EPA Inspection Report - Page 1657 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja Artesia FCC Flare, FL-402 60.lOOa Applicability, designation of affected facility, and reconstruction. (b) For flares, the provisions of this subpart apply only to flares which commence construction, modification or reconstruction after June 24, 2008. 60.101a Definitions. Terms used in this subpart are defined in the Clean Air Act (CAA), in 60.2 and in this section. Emergency flare means a flare that combusts gas exclusively released as a result of malfunctions (and not startup, shutdown, routine operations or any other cause) on four or fewer occasions in a rolling 365-day period. For purposes of this rule, a flare cannot be categorized as an emergency flare unless it maintains a water seal. Non-emergency flare means any flare that is not an emergency flare as defined in this subpart. Flare FL-402 is a Non-emergency flare. Modification or reconstrnction occurred on Flare FL-402 after June 24, 2008. Therefore FL-4020 is subject to NSPS Subpart Ja. HFNA-000003207 EPA Inspection Report - Page 1658 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja - 500 M SCF 24-hour rolling average Artesia FCC Flare (FL-402) 60.lOla Definitions. Flare. In the case of an interconnected flare gas header system, the flare includes each individual flare serviced by the interconnected flare gas header system and the interconnected flare gas header system. 60.103a Design, equipment, work practice or operational standards (a) Except as provided in paragraph (g) of this section, each owner or operator that operates a flare that is subject to this subpart shall develop and implement a written flare management plan no later than the date specified in paragraph (b) of this section. The flare management plan must include the information described in paragraphs (a)(l) through (7) of this section. compressor staging and a justification for why the maximum time period cannot be further reduced. (4) An evaluation of the baseline flow to the flare. The baseline flow to the flare must be determined after implementing the minimization assessment in paragraph (a)(2) of this section. Baseline flows do not include pilot gas flow or purge gas flow (i.e., gas introduced after the flare's water seal) provided these gas flows remain reasonably constant (i.e., separate flow monitors for these streams are not required). Separate baseline flow rates may be established for different operating conditions provided that the management plan includes: (c) Except as provided in paragraphs (f) and (g) of this section, each owner or operator that operates a flare subject to this subpart shall conduct a root cause analysis and a corrective action analysis for each of the conditions specified in paragraphs (c)(l) of this section. (1) For a flare: (ii) Any discharge to the flare in excess of 14,160 standard cubic meters (m3) (500,000 standard cubic feet (set)) above the baseline, determined in paragraph (a)(4) of this section, in any 24-hour period. 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. (t) Flow monitoring for flares. Except as provided in paragraphs (t)(2) and (h) of this section, the owner or operator of an affected flare subject to 60.103a(c) through (e) shall install, operate, calibrate and maintain, in accordance with the specifications in paragraph (t)(l) of this section, a CPMS to measure and record the flow rate of gas discharged to the flare. (1) The owner or operator shall install, calibrate, operate and maintain each flow monitor according to the manufacturer's procedures and specifications and the following requirements. (iv) At least quarterly, perform a visual inspection of all components of the monitor for physical and operational integrity and all electrical connections for oxidation and galvanic corrosion if the flow monitor is not equipped with a redundant flow sensor. (v) Recalibrate the flow monitor in accordance with the manufacturer's procedures and specifications biennially (every two years) or at the frequency specified by the manufacturer. HFNA-000003208 EPA Inspection Report - Page 1659 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery The FCC Flare (FL-402) and the North Plant Flare (FL-400) were previously part of an interconnected network of flare headers, although they did not operate as intercom1ected flares. The Flare Management Plan (FMP) submitted on November 11, 2015 established the combined flow baseline for FL-400 (North Plant) and FL-402 (FCC) flares as 1,077,961. As ofJuly 2017, the physical connection between the flares headers was removed, and separate flow baselines were established for each flare. The July 2017 FMP update establishes a new flow baseline of 162,000 SCF in any 24-hour period for FL-402 (FCC), and a new flow baseline of 624,000 SCF in any 24-hour period for FL-400 (NP). Per 40 CFR 60.103a(c)(l)(ii), the threshold for a Root Cause Analysis and corrective action plan is 662,000 SCF in any 24-hour period for the FCC Flare, and 1,124,000 SCF in a 24-hour period for the NP Flare. HFNA-000003209 EPA Inspection Report - Page 1660 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report FCC Flare (FL-0402) FL-402 500M SCF GEMS Summary Affected Source Emission Limit Citation Emission Limitation (SCF over baseline in rolling 24 hours) FL-402 FCC Flare 60.107a(f) 500,000 Monitor Manufacturer and Model No. General Electric - GF868-2-11 Monitor Serial Number 4430 Date of Latest CMS Certification or Audit 10/17/2017 Reporting Period Beginning Date Reporting Period Ending Date 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime Total Source Operating Time in Reporting Period (hours) (hours) (hours) 4416 0 4416 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Totals Total CMS Downtime as a Percent of Total Source l'IU111u,:;1 UI Inl"irlo-~ 5 0 0 0 0 5 5 UUICILIVI I /LJ- ~~ \ 9.00 0.00 0.00 0.00 0.00 0.00 9.00 0.20% Emission Data Summary (Exceeds 500,000 SCF over baseline in rolling 24 hours) Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Number of Incidents 0 1 0 2 1 0 Duration (Hours) 0.00 166.00 0.00 49.00 23.00 0.00 Totals 4 238.00 Total Duration of Deviations as a Percent of Total Source Operating Time 5.39% HFNA-000003210 EPA Inspection Report - Page 1661 of 1969 HdlyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report FCC Flare (FL-0402) FL-402 Flowmeter Downtime CMS Downtime Affected Source Name Monitor Type Monitored HAP or Gas Downtime Stlrt Date and Time Downtime End Date and Time Duration of Downtime (hours) FL-402 Flowmeter SCF 08/14/2018 17:00 08/14/2018 18:00 1.00 FL-402 Flowmeter SCF 08/28/2018 02:15 08/28/2018 02:45 0.50 FL-402 Flowmeter SCF 09/02/2018 15:00 09/02/2018 18:00 3.00 FL-402 Flowmeter SCF 10/04/2018 10:30 10/04/2018 14:30 4.00 FL-402 Flowmeter SCF 10/06/2018 09:15 I 10/06/2018 09:30 Total 0.25 9.00 Type of Downtime Period Type of Cause of Brief Description of Cause of Downtime Deviation Corrective Action Taken Changes to Emission Control 6D.108a(d)(6) Monitor Equipment Malfunction Monitor Equipment Malfunction Monitor Equipment Malfunction Monitor Equipment Malfunction Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance The l&E technician performed maintenance to correct mode due to an analyzer malfunction. the analyzer malfunction, and the analyzer was returned to service. iNo changes were made in ioperation of the emission control isystem Malfunction The analyzer was placed in maintenance The l&E technician performed maintenance to correct mode due to an analyzer malfunction. the analyzer malfunction, and the analyzer was returned to service. iNo changes were made in !operation of the emission control I system. Malfunction The analyzer was placed in maintenance The l&E technician performed maintenance to correct mode due to an analyzer malfunction. the analyzer malfunction, and the analyzer was returned to service. iNo changes were made in !operation of the emission control isystem Malfunction Malfunction The analyzer was placed in maintenance The l&E technician performed maintenance to correct mode due to an analyzer malfunction. the analyzer malfunction, and the analyzer was returned to service. INo changes were made in ioperation of the emission control isystem The analyzer was placed in maintenance The l&E technician performed maintenance to correct mode due to an analyzer malfunction. the analyzer malfunction, and the analyzer was returned to service. !No changes were made in !operation of the emission control I system. HFNA-000003211 EPA Inspection Report - Page 1662 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report FCC Flare (FL-0402) FL-402 500M SCF Deviations CMS Deviations Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions Start Date and Time Excess Emissions End Date and Time Duration of Excess Emissi_ons Du~a!~snsi:n:xi~ess Deviation (hours) Occpurr~ddDu nng eno o1 reporting period due to: Brief Description of Nature and Cause of Excess Emission Corrective Action Taken or Preventative Measure Adopted Discharges Per 60.108a(d){5) FL-402 Flowmeter SCF 0712212018 18:00 07/23/201818:00 24.00 Other An unexpected shutdown of the Fluid Catalytic Cracking Unit (FCC, Unit 10) Process Problems ~:u~~!~o;e;h:o;J~e~~~~ d~:et~~~e!:e~~!~r:~i~~t;~gegx:::d::t~~t~:;tic baseline reporting threshold. The flow charges and production rates in upstream units were reduced to minimize venting to the flare. The compressor's See Attached Event Record: ''#7-2018-08 relay was reset and the FCC unit was restarted, allowing the 28 FL-0402 NSPS Ja Flow RCA" discharge to the flare to end. FL-402 Flowmeter SCF 08/2712018 03:00 09/03/2018 01 :DO 166.00 Shutdown Shutdown ;~~i~~~f ~~~y~;;o~nf::~e:::~h:x~~~~~::~:i~4bO;~e~i::u~;:;~~rTn:~eshold. Unit ~harge and pr~duction ~ates were reduced a~c~r~ingly, planned shutdown of the Alkylation Unit (Unit 09) to complete repairs to the td~ adhJust fotrtthhe pflenod of urnt shutdown, and to minimize the Alky Flare (FL-0403) tip. isc arge o e are. See Attached Event Record: ''#8-2018-0S 05 FL-0402 NSPS Ja Flow RCA" FL-402 Flowmeter SCF 09/05/2018 04:00 09/06/2018 05:00 25.00 Other An unexpected shutdown of the FCC unit 10 Lift Air Blower compressor due to Process Problems a relay malfunction triggered the automatic shutdown of the FCC Unit. The FCC flare intermittently exceeded the flow baseline reporting threshold The flow charges and production rates in upstream units were reduced to minimize venting to the flare. The compressor's See Attached Event Record: ''#9-2018-1[ relay was reset and the FCC unit was restarted, allowing the 08 FL-0402 NSPS Ja Flow RCA" discharge to the flare to end. FL-402 Flowmeter SCF 09/2512018 14:00 09/26/2018 13:00 23.00 Other Other Known Cause The ~lectrical power suppl~ from a third party su~st~tion to the Artesia Refinery The electrical supply was promptly shifted to four additional was 1nterru~ted for approximately 3 hours, resulting 1n the shutdown of_ se\eral substations that provide the electrical power to other sections proce~s units, ~s ~ell as several pumps, _compres~ors an~ other el~c'.nc pieces of the refinery. allowing the electrical power to be restored. of equipment within the re~nery. The flaring a~sociated with the units . ~=u!~~;nt~~;~~~~~d to discharge to the flare in excess of the flow baseline The frequency of preventative maintenance activities ~erformed by the thi_rd-party electrical sub~tation was p g increased from semiannual to monthly basis. See Attached Event Record: ''#10-201810-25 NSPS Ja RCA S02 FL-0402" Total 238.00 HFNA-000003212 EPA Inspection Report - Page 1663 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja - 162 ppmvd H2S 3-hour rolling average Artesia FCC Flare, FL-402 60.103a Design, equipment, work practice or operational standards (h) Each owner or operator shall not bum in any affected flare any fuel gas that contains H2S in excess of 162 ppmv determined hourly on a 3-hour rolling average basis. The combustion in a flare of process upset gases or fuel gas that is released to the flare as a result of relief valve leakage or other emergency malfunctions is exempt from this limit. 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. (a) Fuel gas combustion devices subject to S02 or H2S limit and flares subject to H2S concentration requirements. (2) The owner or operator of a fuel gas combustion device that elects to comply with the H2S concentration limits in 60.102a(g)(1)(ii) or a flare that is subject to the H2S concentration requirement in 60.103a(h) shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration by volume (dry basis) of H2S in the fuel gases before being burned in any fuel gas combustion device or flare. (3) The owner or operator of a fuel gas combustion device or flare is not required to comply with paragraph (a)(l) or (2) of this section for fuel gas streams that are exempt under 60.102a(g)(1)(iii) or 60.103a(h) or, for fuel gas streams combusted in a process heater, other fuel gas combustion device or flare that are inherently low in sulfur content. (e) Su(f'ur monitoringfor assessing root cause analysis thresholdfor affectedflares. (2) H2S monitoring requirements. The owner or operator shall install, operate, calibrate, and maintain an instrument for continuously monitoring and recording the concentration of H2S in gas discharged to the flare according to the requirements in paragraphs (e)(2)(i) through (iii) of this section and shall collect and analyze samples of the gas and calculate total sulfur concentrations as specified in paragraphs (e)(2)(iv) through (ix) of this section. Flare FL-402 is subject to the 162 ppmv hydrogen sulfide (H2S) limit. Therefore, Navajo maintains an H 2S CEMS on Flare FL-402 that records concentrations in parts per million by volume on a dry basis (ppmvd). Note: 60. l03a(h) exempts startup, shutdown. malfunctioR and process upset gases, along with relief valve leakage, from the requirement to meet the 162 ppm (H2S) limit. In this report we have included information on these events we believe are exempt, and have identified them as such. HFNA-000003213 EPA Inspection Report - Page 1664 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report FCC Flare (FL-0402) FL-402 H2S CEMS Summary Affected Source Emission Limit Citation Emission Limitation (H 2S ppmv on rolling 3-hours) FL-402 FCC Flare 60.103a(h) 60.107a(e)(2) 162 Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit Reporting Period Beginning Date Reporting Period Ending Date Siemens - Maxum II Extrel Max300-IG 30049702230400 01/23/2018 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime Total Source Operating Time in Reporting Period (hours) (hours) (hours) 4416 0 4416 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Number of Incidents 2 1 185 6 0 Duration (Hours) 12.00 48.00 7.00 97.00 0.00 Totals 194 Total CMS Downtime as a Percent of Total Source Operating Time 164.00 3.71% Emission Data Summary (Exceeds 162 H2S ppmv on rolling 3-hours) Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Totals Number of Incidents 0 4 0 11 1 0 16 Duration (Hours) 0.00 110.00 0.00 92.00 46.00 0.00 248.00 Total Duration of Deviations as a Percent of Total Source Operating Time 5.62% HFNA-000003214 EPA Inspection Report - Page 1665 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report FCC Flare (FL-0402) FL-402 H2S GEMS Downtime CEMS Downtime Affected Source Name Monitor Type Monitored HAP or Gas Downtime Start Date and Time Downtime End Date and Time Duration of Downtime (hours) Type of Downtime Period Type of Cause of Deviation Brief Description of Cause of Downtime Corrective Action Taken FL-402 CEMS H2S 08/23/2018 09:40 08/23/2018 11 30 1.00 Other Known Cause other The analyzer was placed in maintenance mode The l&E technician performed a CGA and to perform a CGA. returned the analyzer to service Changes to Emission Control 60.108a(d)(6) No changes were made in operation of the emission control system FL-402 CEMS FL-402 FL-402 FL-402 FL-402 CEMS CEMS CEMS CEMS FL-402 CEMS FL-402 CEMS FL-402 CEMS FL-402 CEMS H0S 08/23/2018 13:15 08/23/2018 15:35 H2S 10/30/2018 08:00 10/31/2018 00:00 H2S 10/31/2018 00:00 11/01/20180000 H2S 11/01/2018 00:00 11/02/2018 00 00 H2S 11/02/2018 00 00 11/03/2018 06:30 H2S 11/03/2018 06:45 11/03/2018 1413 H0S 11/04/2018 06:45 11/04/2018 12:07 H0S 11/14/2018 09:15 11/16/2018 09:15 H2S 12/13/2018 06:30 12/13/2018 14:04 Total 2.00 Other Known Cause other The analyzer was placed in maintenance mode The l&E technician performed a CGA and to perform a CGA. returned the analyzer to service. No changes were made in operation of the emission control system. 16.00 24.00 24.00 30.00 7.00 5.00 48.00 Other Known Cause Other Known Cause Other Known Cause Other Known Cause Monitor Equipment Malfunction other other other other Malfunction The GC analyzer was taken out of service to be replaced with a mass spectrometer (MS). The mass spectrometer analyzer failed to calibrate due to computer sequence errors. The project team removed the GC from service and placed the MS on line. The system was adjusted and a manual calibration was run. The MS was returned to service No changes were made in operation of the emission control system. No changes were made in operation of the emission control system Monitor Equipment Malfunction Malfunction The MS analyzer failed to calibrate due to computer sequence errors. Non-Monitor Equipment Malfunction Malfunction The MS was taken out of service due to transfer line steam damage The system was adjusted and a manual calibration was run. The MS was returned to service. No changes were made in operation of the emission control system. The transfer line was replaced, the analyzer was recalibrated, and returned to service. No changes were made in operation of the emission control system. 7.00 164.00 Quality Assurance Calibration other The MS was placed into calibration mode due The l&E technician completed an auto validation to suspect validation numbers. and returned the analyzer to service. No changes were made in operation of the emission control system. HFNA-000003215 EPA Inspection Report - Page 1666 of 1969 HdlyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report FCC Flare (FL-0402) CEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions Start Date and Time Excess Emissions End Date and Time Duration of Deviation (hours) Excess Emissions Occurred During Period of SSM (Y/N) Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission FL-402 CEMS H2S 07/01/2018 16 00 07/01/2018 19:00 3.00 y Shutdown Pump (P-0955) was purged and vented to the flare in preparation for maintenance. FL-402 H2S Excess Emissions Corrective Action Taken or Preventative Measure Adopted H::,S scavenger was injected at maximum rate to reduce the concentration of this gas in the flare header and to aid in minimizing emissions. FL-402 CEMS H2S 07/21/2018 22:00 07/23/2018 03:00 29.00 N Process Problems An unexpected shutdown of the Fluid Catalytic Cracking Unit (FCC, Unit 10) Lift Air Blower compressor due to a relay malfunction triggered the automatic shutdown of the FCC unit. The flaring following the sudden unit shutdown resulted in emissions above 162 ppm H2S, on a 3-hour rolling average basis. H2S scavenger was injected at maximum rate to reduce the concentration of this gas in the flare header and to aid in minimizing emissions. The flow charges and production rates in upstream units were reduced to minimize venting to the flare. The compressor's relay was reset and the FCC unit was restarted, allowing the discharge to the flare to end. FL-402 CEMS H2S 07/25/2018 23:00 07/26/2018 06:00 7.00 N FL-402 CEMS H2S 08/23/2018 08:00 08/23/2018 11 :00 3.00 N Process Problems The FCC unit shut down unexpectedly following malfunction of the fractionator pumparound. During this time, overhead gases were vented from the FCC unit to the FCC Flare (FL-0402). The pumparound was restarted and the unit retuned online, ending the venting to flare. Process Problems Operations vented non-condensable gases from the FCC overhead system to address an unexpected pressure increase in the system. When the pressure in the unit was within normal operating range, the venting to the stopped. FL-402 CEMS H2S 08/27/2018 01 :00 08/31/2018 04:00 99.00 y FL-402 CEMS H2S 08/31/2018 15:00 08/31/2018 20:00 5.00 y Shutdown Shutdown A controlled shutdown of the Alkylation Unit was implemented in order to repair damage discovered in the Alky Flare tip. The unit was placed in recirculation mode, maintaining enough flare vent gas flow to allow the flare pilot to remain lit. The procedure for placing the Alky Unit in recirculation mode requires that the alkylation feed stream, which is produced by the FCC unit, to be vented to the FCC Flare (FL-0402) during this period. As a result, the H2S concentration at the flare header increased above 162 ppm, on a 3-hour rolling average basis. The standard procedure for unit shutdown steps to minimize the impact of emissions was followed, thereby on ambient air quality. taking FL-402 CEMS H2S 09/02/2018 07:00 09/02/2018 10: 00 3.00 N FL-402 CEMS H2S 09/04/2018 12:00 09/05/2018 16:00 28.00 N FL-402 CEMS H2S 09/11/2018 10:00 09/11/2018 13:00 3.00 y Process Problems The flare emissions exceeded 162 H2S ppmvd, on a 3-hour rolling average basis, as the FCC production rate was being increased, after repair work in the Alkylation Unit was completed and the Alkylation Unit was placed on line The H2S scavenger injection rate in the FCC Flare vent gas was maximized to reduce the concentration of this gas in the flare header, and thereby, minimize excess emissions. Process Problems An unexpected shutdown of the FCC unit 1O Lift Air Blower compressor due to a The flow charges and production rates in upstream units were reduced to relay malfunction triggered the automatic shutdown of the FCC Unit. The flare minimize venting to the flare. The compressor's relay was reset and the exceeded 162 ppm H2S, on a 3-hour rolling average basis FCC unit was restarted, allowing emissions to decrease below the reportable limit. Shutdown FCC absorber Bottoms Pump (P-0954) was purged to the FCC Flare (FL-0402) in preparation for planned maintenance work. During this process, the flare exceeded 162 ppm H2S, on a 3-hour rolling average basis The pump purge was conducted in accordance to maintenance work preparation procedures. The H::,S scavenger injection rate in the flare header was maximized to reduce the of this gas in the flare header, and thereby. minimize excess emissions. HFNA-000003216 EPA Inspection Report - Page 1667 of 1969 HdlyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report FCC Flare (FL-0402) FL-402 H2S Excess Emissions CEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions Start Date and Time Excess Emissions End Date and Time Duration of Deviation (hours) Excess Emissions Occurred During Period of SSM (Y/N) Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission Corrective Action Taken or Preventative Measure Adopted FL-402 CEMS H2S 09/22/2018 05:00 09/22/2018 08:00 3.00 N FL-402 CEMS H2S 09/22/2018 16:00 09/22/2018 20:00 4.00 N Process Problems Process Problems Unexpected shutdown of Amine Unit Lean Amine Pump (P-0775). The spare Lean Amine Pump (P-0776) was started. While testing P-0775, the switch rack breaker feeding the breaker rack shorted causing a loss of power to both amine pumps. The Amine contactors could not operate, reducing the treating capacity of acid gas being sent to the fuel gas system. This caused an exceedance of the NSPS Ja 162 ppm H2S 3-hour rolling average at the flare. Electricians were called as soon as the switchgear malfunctioned. determining that the bucket style breaker tripped. The breaker was reset, the spare pump (P-0776) was restarted. The Amine contactors were retuned online, resuming normal operation. To minimize excess SOi emissions from the flare, operations promptly injected an f-1::S scavenger agent upstream of the Flare Knockout drum in order to reduce the emissions of 802 from the flare. FL-402 CEMS H2S 09/23/2018 21 :00 09/25/2018 19: 00 46.00 FL-402 CEMS H2S 10/16/2018 08:00 10/16/201811:00 3.00 The electrical power supply from a third party substation to the Artesia Refinery was interrupted for approximately 3 hours, resulting in the shutdown of several process units, as well as several pumps, compressors and other electric pieces The electrical supply was promptly shifted to four additional substations of equipment within the refinery. Off-gas was continued to be produced some that provide the electrical power to other sections of the refinery, allowing Other Known time after the power outage occurred and the process units shut down. Without the electrical power to be restored, and process units to be restarted. The N Cause the electrical power to operate amine contactors and H2S strippers, the H2S frequency of preventative maintenance activities performed by the third- concentration in the FGS and Amine Unit increased. Because the FG is also party electrical substation was increased form semiannual to monthly used as vent gas in the flare system, the H2S concentration increase in the FGS basis. was transferred to the North Plant, FCC, and GOH flare systems, resulting in excess of the NSPS Ja 162 ppm H2S 3-hour rolling average. Due to a process upset in the Amine Unit, the H2S the FGS was not efficiently Process adjustments were promptly made to establish normal operating Process removed, resulting in the concentration of this gas in the FGS to increase. FSG conditions in the amine contactors. The amine contactors resume the H2S N Problems is also used as FCC sweep gas, therefore, the H2S concentration also removal from the FGS, allowing the concentrations to decrease below the increased in the FCC flare header, exceeding he NSPS Ja 162 ppm H2S 3-hour reportable limit. rolling average FL-402 CEMS H2S 10/19/20182300 10/20/2018 03:00 4.00 N Process Problems Water present in the FCC cold feed from the feed tank T-0400 caused high pressure in the unit's heated surge drum. The excess pressure was relieved to the flare The flow charges and production rates in upstream units were reduced to minimize venting to the flare. The H2S scavenger injection rate was maximized to reduce the concentration of this gas in the flare header FL-402 CEMS H2S 11/28/2018 22:00 11/29/2018 01 :OD 3.00 N Unknown Cause Unknown Cause Unknown Cause FL-402 CEMS H2S 12/07/20182300 12/08/2018 03:00 4.00 N Process Problems Process upset in Unit 13 contributed to the increase of H2S the FGS. FSG is also used as FCC sweep gas, therefore, the H2S concentration also increased in the FCC flare header, exceeding the NSPS Ja 162 ppm H2S 3-hour rolling average. Normal operation was re-established in Unit 13, allowing the concentration of H2S in the FGS and flare header to decrease below the reportable limit. FL-402 CEMS H2S 12/10/201810:00 12/10/2018 13:00 3.00 N FL-402 CEMS H2S 12/31/20181100 12/31/2018 16:00 5.00 N Total 255.00 Process Problems Process Problems SRU2 compressor trip resulted in increase of the H::,S concentration in the FGS H2S scavenger was added in the flare header at maximum rate and SRU2 and FCC sweep gas, above the NSPS Ja 162 ppm H2S 3-hour rolling average. was restarted. Water present in the FCC cold feed from the feed tank T-0400 caused high pressure in the unit's heated surge drum. The excess pressure was relieved to the flare, resulting in emissions above the NSPS Ja 162 ppm H2S 3-hour rolling average. The flow charges and production rates in upstream units were reduced to minimize venting to the flare. The H2S scavenger injection rate was maximized to reduce the concentration of this gas in the flare header HFNA-000003217 EPA Inspection Report - Page 1668 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja - 500 lb S02 24-hour rolling average Artesia FCC Flare, FL-402 60.103a Design, equipment, work practice or operational standards (c) Except as provided in paragraphs (t) and (g) of this section, each owner or operator that operates a flare subject to this subpart shall conduct a root cause analysis and a corrective action analysis for each of the conditions specified in paragraphs (c)(l) of this section. (1) For a flare: (i) Any time the S02 emissions exceed 227 kilograms (kg) (500 lb) in any 24-hour period; or 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. (a) Fuel gas combustion devices subject to S02 or II2S limit and flares subject to II2S concentration requirements. (2) The owner or operator of a fuel gas combustion device that elects to comply with the II2S concentration limits in 60.102a(g)(1)(ii) or a flare that is subject to the II2S concentration requirement in 60.103a(h) shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration by volume (dry basis) of II2S in the fuel gases before being burned in any fuel gas combustion device or flare. (3) The owner or operator of a fuel gas combustion device or flare is not required to comply with paragraph (a)(l) or (2) of this section for fuel gas streams that are exempt under 60.102a(g)(1)(iii) or 60.103a(h) or, for fuel gas streams combusted in a process heater, other fuel gas combustion device or flare that are inherently low in sulfur content. (e) Su(f'ur monitoringfor assessing root cause analysis thresholdfor affectedflares. Except as described in paragraphs (e)(4) and (h) of this section, the owner or operator of an affected flare subject to 60.103a(c) through (e) shall determine the total reduced sulfur concentration for each gas line directed to the affected flare in accordance with either paragraph (e)(l), (e)(2) or (e)(3) of this section. (1) Total reduced sulfur monitoring requirements. The owner or operator shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration of total reduced sulfur in gas discharged to the flare. Flare FL-402 is subject to the 500 lbs S02 threshold monitoring requirements. Navajo maintains a CEMS for continuously measuring the concentration of total reduced sulfur in gas discharged to the flare. HFNA-000003218 EPA Inspection Report - Page 1669 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report FCC Flare (FL-0402) FL-402 500 lb S0 2 CEMS Summary Affected Source Emission Limit Citation FL-402 FCC Flare 60.107a(e)(1) Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit ThermoScientific - SOLA 11 Extrel Max300-IG SL-1 0061014 05/31/2018 Reporting Period Beginning Date Reporting Period Ending Date 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime Total Source Operating Time in Reporting Period (hours) (hours) (hours) 4416 0 4416 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Number of Incidents 3 0 185 7 0 Duration (Hours) 44.00 0.00 1.00 145.00 0.00 Totals 195 Total CMS Downtime as a Percent of Total Source Operating Time 190.00 4.30% Emission Data Summary Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Totals Total Duration of Deviations as a Percent of Total Source Operating Time Number of Incidents 0 1 0 2 1 0 4 Duration (Hours) 0.00 97.00 0.00 78.00 25.00 0.00 200.00 4.53% HFNA-000003219 EPA Inspection Report - Page 1670 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report FCC Flare (FL-0402) FL-402 500 lb S02 CEMS Downtime GEMS Downtime Affected Monitor Source Name Type Monitored HAP or Gas Downtime S1art Date and Time Downtime End Date and Time Duration of Downtime (hours) FL-402 GEMS so, 08/23/2018 09:40 08/23/201811:30 1.00 FL-402 GEMS so, 08/23/2018 13: 15 08/23/2018 15:35 2.00 FL-402 GEMS so, 10/25/2018 09:45 10/25/201811:10 1.00 FL-402 GEMS so, 10/30/2018 08:00 10/31/2018 00:00 16.00 FL-402 GEMS so, 10/31 /2018 00: 00 11/01/2018 00:00 24.00 FL-402 GEMS so, 11/01/2018 00:00 11/02/2018 00:00 24.00 FL-402 GEMS so, 11/02/2018 00: 00 11/03/2018 06:30 30.00 Type of Downtime Period Other Known Cause Type of Cause of Brief Description of Cause of Downtime Deviation Corrective Action Ta ken Changes to Emission Control 60.108a(d)(6) Other The analyzer was placed into maintenance mode to perform a CGA. The l&E technician performed a CGA and returned the analyzer to service. No changes were made in operation of the emission control system Other Known Cause Other The analyzer was placed into maintenance mode to perform a CGA The l&E technician performed a CGA and returned the analyzer to service No changes were made in operation of the emission control system Quality Assurance Calibration Other The analyzer was placed into calibration The l&E technician recalibrated and returned the mode to recalibrate analyzer to service No changes were made in operation of the emission control system Other Known Cause Other The Sola analyzer vvas taken out of service to be replaced with a mass spectrometer (MS). The project team replaced the SOLA analyzer with the MS. No changes were made in operation of the emission control system Other Known Cause Other The Sola analyzer vvas taken out of service to be replaced with a mass spectrometer (MS). The project team replaced the SOLA analyzer with the MS. No changes were made in operation of the emission control system. Other Known Cause Other The Sola analyzer vvas taken out of service to be replaced with a mass spectrometer (MS). The project team replaced the SOLA analyzer with the MS. No changes were made in operation of the emission control system. Other Known Cause Other The Sola analyzer vvas taken out of service to be replaced with a mass spectrometer (MS) The project team replaced the SOLA analyzer with the MS. No changes were made in operation of the emission control system. FL-402 GEMS so, 11/03/2018 06:45 11/03/20181413 7.00 Monitor Equipment Malfunction Malfunction The MS failed to calibrate due to computer sequence failures. The calibration failed to successfully calibrate due to No changes were made in a sequencing issue. The system vvas adjusted and operation of the emission control a manual calibration vvas run. The MS analyzer vvas system. returned to service. FL-402 GEMS so, 11/04/2018 06:45 11/04/201812:07 FL-402 GEMS so, 11/14/201809:15 11/16/2018 09:15 FL-402 GEMS so, 12/12/2018 06:45 12/13/2018 14:04 Total 5.00 48.00 32.00 190.00 Monitor Equipment Malfunction Other Known Cause Monitor Equipment Malfunction Malfunction The MS failed to calibrate due to computer sequence failures. The calibration failed to successfully calibrate due to No changes were made in a sequencing issue. The system vvas adjusted and operation of the emission control a manual calibration vvas run. The MS analyzer vvas system returned to service Other Malfunction The MS was taken out of service due to The transfer line was replaced, recalibrated, and the No changes were made in transfer line steam damage. analyzer vvas returned to service. operation of the emission control system The MS was placed into maintenance mode due to a failed calibration The l&E technician reran the validation, and returned the analyzer to service No changes were made in operation of the emission control system. HFNA-000003220 EPA Inspection Report - Page 1671 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report FCC Flare (Fl-0402) Fl-402 500 lb SO 2 Excess Emissions CEMS Monitored Excess Emissions iso~~:c~eadme Monitor Type ' Monitored HAP or Gas Excess Emissions Start Date and Time . E~~c~:~;;~~s~~;se Duration ofl E~~~=i~~s Dehvoiuartio)n i Occurred 1 5 i During Period i of SSM (YIN) Duration of excess emissions in reporting period due to: :-----------------------------------------------------------------------------------------------------------------------------------------+ --------------------------------------------------------+ Brief Description of Nature and Cause of Excess Emission FL-402 CEMS so, 07/22/2018 03:00 7/23/1819:00 40.00 Process Problems iAn unexpected shutdov\111 of the Fluid Catalytic Cracking Unit (FCC, Unit 10) Lift !Air Blower compressor due to a relay malfunction triggered the automatic !shutdown of the FCC unit. The flaring follovving the sudden unit shutdov\111 Iresulted in sulfur dioxide (S02) emissions above 500 pounds in a 24 hour period. Corrective Action Taken or Preventative Measure Adopted Discharges Per 60.108a(d)(5) H2S scavenger was injected at maximum rate to reduce the i ~:i~:i~t~::i~:~:: ;ha:r~ne:h:n~a~~ohdeuac~i:nar:~etii~i~~~t~~:~z~~~ were reduced to minimize venting to the flare. The compressor's relay was reset and the FCC unit was restarted, allowing the discharge to the flare to end Isee Attached Event Record: "#11-2018-08!28 FL-402 NSPS Ja RCA S02" FL-402 CEMS so, 08/27/2018 09:00 8/31/1810:00 97.00 y Shutdown iA controlled shutdov\111 of the Alkylation Unit was implemented in order to repair !damage discovered in the Alky Flare tip. The unit was placed in recirculation imode, maintaining enough flare vent gas flow to allow the flare pilot to remain lit. iThe procedure for placing the Alky Unit in recirculation mode requires that the ialkylation feed stream. \r\lhich is produced by the FCC unit, to be vented to the iFCC Flare (FL-0402) during this period. As a result, the S02 emissions increased iabove 500 pounds in a 24-hour period The standard procedure for unit shutdo1,rvn was followed, thereby taking steps to minimize the impact of emissions on ambient air quality. -----------------------------------------------------------------------------------------------------------------------------------------+ --------------------------------------------------------+ FL-402 CEMS so, 09/04/2018 16:00 916/18 6:00 38.00 Process Problems IAn unexpected shutdovvn of the FCC unit 10 Lift Air Blower compressor due to a The flow charges and production rates in upstream units were irelay malfunction triggered the automatic shutdown of the FCC Unit. The flaring reduced to minimize venting to the flare. The compressor's relay !following the unit shutdov\111 caused S02 emissions to exceed 500 pounds in a 24-was reset and the FCC unit was restarted, allowing emissions to Ihour period decrease below the reportable limit ISee Attached Event Record: "#12-2018-09!04 NSPS Ja RCA S02 FL-0402" Isee Attached Event Record: "#13-2018-10iOB NSPS Ja RCA S02 FL-0402" FL-402 CEMS so, 09/25/2018 14:00 9/26/18 15:00 25.00 Total 200.00 Other Knovvn Cause !The electrical power supply from a third party substation to the Artesia Refinery !was interrupted for approximately 3 hours, resulting in the shutdov\111 of several !process units, as well as several pumps, compressors and other electric pieces iof equipment within the refinery. Off-gas was continued to be produced some itime after the power outage occurred and the process units shut down. Without ithe electrical power to operate amine contactors and H2S strippers, the H2S !concentration in the FGS and Amine Unit increased. The flaring associated 1,rvith ithe units' shutdovvn and subsequent startup resulted in emissions from the FCC IFlare to exceed 500 lbs S02 in a 24-hour period. ~~:n~~~:l~o~~:~~:i~~~~~c~ti~:~ ~~:i~r~~~:~:~ The electrical supply was promptly shifted to four additional 0 fo ::~!~t~~:~ of preventative maintenance activities performed by the third-party I Isee Attached Event Record: "#14-2018-10i25 NSPS Ja RCA S02 FL-0402" electrical substation was increased from semiannual to monthly basis. HFNA-000003221 EPA Inspection Report - Page 1672 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja Artesia Alky Flare, FL-403 60.lOOa Applicability, designation of affected facility, and reconstruction. (b) For flares, the provisions of this subpart apply only to flares which commence construction, modification or reconstruction after June 24, 2008. 60.101a Definitions. Terms used in this subpart are defined in the Clean Air Act (CAA), in 60.2 and in this section. Emergency flare means a flare that combusts gas exclusively released as a result of malfunctions (and not startup, shutdown, routine operations or any other cause) on four or fewer occasions in a rolling 365-day period. For purposes of this rule, a flare cannot be categorized as an emergency flare unless it maintains a water seal. Non-emergency flare means any flare that is not an emergency flare as defined in this subpart. Flare FL-403 is a non-emergency flare. Modification or reconstruction occurred on Flare FL-403 after June 24, 2008. Therefore, FL-403 is subject to NSPS Subpart Ja. 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. (b) Exemption.from H2S monitoring requirements for low-sulfur fuel gas streams. The owner or operator of a fuel gas combustion device or flare may apply for an exemption from the H2S monitoring requirements in paragraph (a)(2) of this section for a fuel gas stream that is inherently low in sulfur content. A fuel gas stream that is demonstrated to be low-sulfur is exempt from the monitoring requirements of paragraphs (a)(l) and (2) of this section until there are changes in operating conditions or stream composition. (e) Sulfur monitoring for assessing root cause ana(vsis thresholdfor affectedflares. Except as described in paragraphs (e)(4) and (h) of this section, the owner or operator of an affected flare subject to 60.103a(c) through (e) shall determine the total reduced sulfur concentration for each gas line directed to the affected flare in accordance with either paragraph (e)(l), (e)(2) or (e)(3) of this section. Different options may be elected for different gas lines. If a monitoring system is in place that is capable of complying with the requirements related to either paragraph (e)(l), (e)(2) or (e)(3) of this section, the owner or operator of a modified flare must comply with the requirements related to either paragraph (e)(l), (e)(2) or (e)(3) of this section upon startup of the modified flare. If a monitoring system is not in place that is capable of complying with the requirements related to either paragraph (e)(l), (e)(2) or (e)(3) of this section, the owner or operator of a modified flare must comply with the requirements related to either paragraph (e)(l), (e)(2) or (e)(3) ofthis section no later than November 11, 2015 or upon startup of the modified flare, whichever is later. (4) Exemptions from sulfur monitoring requirements. Flares identified in paragraphs (e)(4)(i) through (iv) of this section are exempt from the requirements in paragraphs (e)(l) through (3) of this section. For each such flare, except as provided in paragraph (e)(4)(iv), engineering calculations shall be used to calculate the S02 emissions in the event of a discharge that may trigger a root cause analysis under 60.103a(c)(l). (i) Flares that can only receive: HFNA-000003222 EPA Inspection Report - Page 1673 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery (A) Fuel gas streams that are inherently low in sulfur content as described in paragraph (a)(3)(i) through (iv) of this section; and/or (B) Fuel gas streams that are inherently low in sulfur content for which the owner or operator has applied for an exemption from the H2S monitoring requirements as described in paragraph (b) of this section. (ii) Emergency flares, provided that for each such flare, the owner or operator complies with the monitoring alternative in paragraph (g) of this section. (iii) Flares equipped with flare gas recovery systems designed, sized and operated to capture all flows except those resulting from startup, shutdown or malfunction, provided that for each such flare, the owner or operator complies with the monitoring alternative in paragraph (g) of this section. (iv) Secondary flares that receive gas diverted from the primary flare. In the event of a discharge from the secondary flare, the sulfur content measured by the sulfur monitor on the primary flare should be used to calculate S02 emissions, regardless of whether or not the monitoring alternative in paragraph (g) of this section is selected for the secondary flare. Flare FL-403 is a non-emergency flare. Modification or reconstmction occurred on Flare FL-403 after June 24, 2008. Flare FL-403 receives flow from the Alkylation Unit (Unit 09) only, and does not operate as part of an interconnected or cascaded flare system. Because the Alkylation Unit is, by design, inherently low in sulfur, the Flare FL-403 system meets the exemption in 60.107a(b) and 60.107a(e)(4). Therefore, FL-403 is not subject to the NSPS Subpart Ja sulfur monitoring requirements. HFNA-000003223 EPA Inspection Report - Page 1674 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja - 500 M SCF 24-hour rolling average Artesia Alky Flare, FL-403 60.103a Design, equipment, work practice or operational standards (a) Except as provided in paragraph (g) of this section, each owner or operator that operates a flare that is subject to this subpart shall develop and implement a written flare management plan no later than the date specified in paragraph (b) of this section. The flare management plan must include the information described in paragraphs (a)(l) through (7) of this section. compressor staging and a justification for why the maximum time period cannot be further reduced. (4) An evaluation of the baseline flow to the flare. The baseline flow to the flare must be determined after implementing the minimization assessment in paragraph (a)(2) of this section. Baseline flows do not include pilot gas flow or purge gas flow (i.e., gas introduced after the flare's water seal) provided these gas flows remain reasonably constant (i.e., separate flow monitors for these streams are not required). Separate baseline flow rates may be established for different operating conditions provided that the management plan includes: (c) Except as provided in paragraphs (t) and (g) of this section, each owner or operator that operates a flare subject to this subpart shall conduct a root cause analysis and a corrective action analysis for each of the conditions specified in paragraphs (c)(l) of this section. (1) For a flare: (ii) Any discharge to the flare in excess of 14,160 standard cubic meters (m3) (500,000 standard cubic feet (set)) above the baseline, determined in paragraph (a)(4) of this section, in any 24-hour period. 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. (t) Flow monitoring for flares. Except as provided in paragraphs (t)(2) and (h) of this section, the owner or operator of an affected flare subject to 60.103a(c) through (e) shall install, operate, calibrate and maintain, in accordance with the specifications in paragraph (t)(l) of this section, a CPMS to measure and record the flow rate of gas discharged to the flare. (1) The owner or operator shall install, calibrate, operate and maintain each flow monitor according to the manufacturer's procedures and specifications and the following requirements. (iv) At least quarterly, perform a visual inspection of all components of the monitor for physical and operational integrity and all electrical connections for oxidation and galvanic corrosion if the flow monitor is not equipped with a redundant flow sensor. (v) Recalibrate the flow monitor in accordance with the manufacturer's procedures and specifications biennially (every two years) or at the frequency specified by the manufacturer. Flare FL-403 is subject to the reporting threshold of 500 MSCF above the flow baseline in a 24-hour period. Navajo maintains a flow monitor for continuously measuring the flow to the flare. The Flare Management Plan submitted on November 11, 2015 established the baseline flow for FL-403 as 85,403 standard cubic feet per day (SCFD; where a day is any 24-hour period). Per 40 CFR 60.103a(c)(1 )(ii), the threshold for an RCA and corrective action plan is 585,403 SCF in any 24-hour period. HFNA-000003224 EPA Inspection Report - Page 1675 of 1969 HollyFron!ier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report Alky Flare (FL-0403) FL-403 500M SCF CEMS Summary Affected Source Emission Limit Citation Emission Limitation (SCF over baseline in rolling 24 hours) FL-403 Alky Flare 60.103a(c)(1)(ii) 500,000 Monitor Manufacturer and Model No. I J~ f-i n r I ...-t r....1.,.; Monitor Serial Number I .1\/1:""'\ I .PrTITI -:-Ill 11 11 AllnlT General Electric - GF868-2-11 4383 11 J/ I i"'>I / I / 07/01/2018 Total Time in Reporting Period Total Source Downtime Total Source Operating Time in Reporting Period (hours) (hours) (hours) CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes ' ULCII \J .. ..., UUvvl ILII' Iv c,.;::, Cl r "''""''IL UI '"' Totals - - --= I ULCII ...., ''-'' I.,<, Number of Incidents 7 0 0 0 0 7 4416 0 4416 Duration (Hours) 7.00 0.00 0.00 0.00 0.00 7.00 0.16% Emission Data Summary (Exceeds 500,000 SCF over baseline in rolling 24 hours) Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Totals Number of Incidents 0 1 0 1 0 0 2 Duration (Hours) 0.00 12.00 0.00 55.00 0.00 0.00 67.00 Total Duration of Deviations as a Percent of Total Source Operating Time 1.52% HFNA-000003225 EPA Inspection Report - Page 1676 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report Alky Flare (FL-0403) FL-403 Flowmeter Downtime CMS Downtime Affected Source Name Monitored Monitor Type HAP or Gas Downtime Start Date and Time FL-403 Flowmeter SCF 07/23/2017 05:00 Downtime End Date and Time Duration of Downtime (hours) Type of Downtime Period Type of Cause of Deviation Brief Description of Cause of Downtime 07/23/2017 05:15 0.25 Monitor Equipment Malfunction The analyzer was placed in maintenance Malfunction mode due to an analyzer malfunction. Corrective Action Taken Changes to Emission Control 60.108a(d)(6) The l&E technician corrected the analyzer No changes were made in operation malfunction, and the analyzer was returned to service. of the emission control system. FL-403 Flowmeter SCF FL-403 Flowmeter SCF FL-403 Flowmeter SCF FL-403 Flowmeter SCF 08/07/2017 06:30 08/07/2017 09:30 08/14/2017 07:00 08/14/2017 07:15 09/21/2017 17:00 09/21/2017 17:15 08/14/2018 17:00 08/14/2018 18:00 3.00 0.25 0.25 1.00 Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due to an analyzer malfunction. Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due to an analyzer malfunction. Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due to an analyzer malfunction. Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due to an analyzer malfunction. The l&E technician corrected the analyzer No changes were made in operation malfunction, and the analyzer was returned to service. of the emission control system. The l&E technician corrected the analyzer No changes were made in operation malfunction, and the analyzer was returned to service. of the emission control system. The l&E technician corrected the analyzer No changes were made in operation malfunction, and the analyzer was returned to service. of the emission control system. The l&E technician corrected the analyzer No changes were made in operation malfunction, and the analyzer was returned to service. of the emission control system. FL-403 Flowmeter SCF 08/27/2018 13:45 08/27/2018 14:00 0.25 Monitor Equipment Malfunction The analyzer was placed in maintenance The l&E technician corrected the analyzer No changes were made in operation Malfunction mode due to an analyzer malfunction. malfunction, and the analyzer was returned to service. of the emission control system. FL-403 Flowmeter SCF 10/04/2018 09:00 10/04/2018 11 00 Total 2.00 7.00 Monitor Equipment Malfunction Malfunction The analyzer was placed in maintenance mode due to an analyzer malfunction. The l&E technician corrected the analyzer No changes were made in operation malfunction, and the analyzer was returned to service of the emission control system. HFNA-000003226 EPA Inspection Report - Page 1677 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report Alky Flare (FL-0403) FL-403 500M SCF Deviations CMS Deviations Affected Source Name Monitor Type iMonitored Excess Emissions HAP or Sta rt Date and Ti me Gas Excess Emissions End Date and Time Duration of Deviation (hours) Excess Emissions Occurred During Period of Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission Corrective Action Taken or Preventative Measure Adopted Discharges Per 60.108a(d)(5) FL-403 Flowmeter SCF 08/11/2018 11 :00 08111/2018 23:00 1200 y Shutdown Depressured the Propane Treater (D-0629) for maintenance to replace media All standard operating procedures were followed See Attached Event Record: ''#15- to minimize emissions from the flare during 2018-08-28 FL-0403 NSPS Ja Flow shutdown. RCA" FL-403 Flowmeter SCF 09/18/201818:00 09121/2018 01 :00 55.00 N Total 67.00 Process Problems W-79 began venting non-condensables to FL0403. W- completed venting non-condensables and flaring was minimized. See Attached Event Record: "/1162018-10-05 FL-0403 NSPS Ja Flow RCA" HFNA-000003227 EPA Inspection Report - Page 1678 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja Artesia GOH Flare, FL-404 60.lOOa Applicability, designation of affected facility, and reconstruction. (b) For flares, the provisions of this subpart apply only to flares which commence construction, modification or reconstruction after June 24, 2008. 60.101a Definitions. Terms used in this subpart are defined in the Clean Air Act (CAA), in 60.2 and in this section. Emergency flare means a flare that combusts gas exclusively released as a result of malfunctions (and not startup, shutdown, routine operations or any other cause) on four or fewer occasions in a rolling 365-day period. For purposes of this rule, a flare cannot be categorized as an emergency flare unless it maintains a water seal. Non-emergency flare means any flare that is not an emergency flare as defined in this subpart. Flare FL-404 is a Non-emergency flare. Modification or reconstrnction occurred on Flare FL-404 after June 24, 2008. Therefore FL-4040 is subject to NSPS Subpart Ja. HFNA-000003228 EPA Inspection Report - Page 1679 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja - 500 M SCF 24-hour rolling average Artesia GOH Flare, FL-404 60.103a Design, equipment, work practice or operational standards (a) Except as provided in paragraph (g) of this section, each owner or operator that operates a flare that is subject to this subpart shall develop and implement a written flare management plan no later than the date specified in paragraph (b) of this section. The flare management plan must include the information described in paragraphs (a)(l) through (7) of this section. compressor staging and a justification for why the maximum time period cannot be further reduced. (4) An evaluation of the baseline flow to the flare. The baseline flow to the flare must be determined after implementing the minimization assessment in paragraph (a)(2) of this section. Baseline flows do not include pilot gas flow or purge gas flow (i.e., gas introduced after the flare's water seal) provided these gas flows remain reasonably constant (i.e., separate flow monitors for these streams are not required). Separate baseline flow rates may be established for different operating conditions provided that the management plan includes: (c) Except as provided in paragraphs (t) and (g) of this section, each owner or operator that operates a flare subject to this subpart shall conduct a root cause analysis and a corrective action analysis for each of the conditions specified in paragraphs (c)(l) of this section. (1) For a flare: (ii) Any discharge to the flare in excess of 14,160 standard cubic meters (m3) (500,000 standard cubic feet (set)) above the baseline, determined in paragraph (a)(4) of this section, in any 24-hour period. 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. (t) Flow monitoring for flares. Except as provided in paragraphs (t)(2) and (h) of this section, the owner or operator of an affected flare subject to 60.103a(c) through (e) shall install, operate, calibrate and maintain, in accordance with the specifications in paragraph (t)(l) of this section, a CPMS to measure and record the flow rate of gas discharged to the flare. (1) The owner or operator shall install, calibrate, operate and maintain each flow monitor according to the manufacturer's procedures and specifications and the following requirements. (iv) At least quarterly, perform a visual inspection of all components of the monitor for physical and operational integrity and all electrical connections for oxidation and galvanic corrosion if the flow monitor is not equipped with a redundant flow sensor. (v) Recalibrate the flow monitor in accordance with the manufacturer's procedures and specifications biennially (every two years) or at the frequency specified by the manufacturer. Flare FL-404 is subject to the reporting threshold of 500 MSCF above the flow baseline in a 24-hour period. Navajo maintains a flow monitor for continuously measuring the flow to the flare. The Flare Management Plan submitted on November 1L 2015 established the baseline flow for FL-404 to be 3,504,000 standard cubic feet per day (SCFD; where a day is any 24-hour period). Per 40 CFR 60. l03a(c)(l)(ii), the threshold for an RCA and corrective action plan is 4,004,000 SCF in any 24-hour period. The June 2017 Flare Management Plan update included an alternative flow baseline of 8,500,000 SCF in any 24-hour period for excess hydrogen flaring during outages of the hydrogen units (Unit 63 and 64), or hydrogen consumers. The threshold for a Root Cause Analysis and corrective action plan is 9,000,000 SCF in any 24-hour period. HFNA-000003229 EPA Inspection Report - Page 1680 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report GOHT Flare (FL-0404) FL-404 500M SCF CEMS Summary Affected Source Emission Limit Citation Emission Limitation (SCF over baseline in rolling 24 hours) FL-404 GOH Flare 60.103a(c)(1)(ii) 500,000 Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit General Electric - GF868-2-11 4382 10/18/2017 Reporting Period Beginning Date Reporting Period Ending Date 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime Total Source Operating Time in Reporting Period (hours) (hours) (hours) 4416 0 4416 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Totals Total CMS Downtime as a Percent of Total Source Operating Time Number of Incidents 13 0 0 0 0 13 Duration (Hours) 19.00 0.00 0.00 0.00 0.00 19.00 0.43% Emission Data Summary (Exceeds 500,000 SCF over baseline in rolling 24 hours) Duration of excess emissions in reporting period due to: Startup Number of Incidents 3 Duration (Hours) 60.00 Shutdown 1 59.00 Control Equipment Problems 0 0.00 Process Problems 1 19.00 Other Known Causes 5 232.00 Other Unknown Causes 0 0.00 Totals 10 370.00 Total Duration of Deviations as a Percent of Total Source Operating Time 8.38% HFNA-000003230 EPA Inspection Report - Page 1681 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report GOHT Flare (FL-0404) FL-404 Flowmeter Downtime CMS Downtime Affected Source Name Monitor Type Monitored Downtime Downtime HAP or ! Start Date and Time End Date and Time Gas Duration of Downtime (hours) Type of Downtime Period Type of Cause Brief Description of Cause of Downtime of Deviation Corrective Action Taken Changes to Emission Control 60.108a(d)(6) FL-404 Flowmeter SCF 07/30/2018 0930 07/30/20181200 Monitor Equipment The analyzer was placed in The l&E technician performed maintenance to No changes were made in operation of 2.50 Malfunction Malfunction maintenance mode due to an analyzer correct an analyzer malfunction, and the the emission control system. malfunction. analyzer was returned to service FL-404 Flowmeter SCF 08/14/2018 17 00 08/14/20181800 Monitor Equipment The analyzer was placed in The l&E technician performed maintenance to No changes were made in operation of 100 Malfunction Malfunction maintenance mode due to an analyzer correct an analyzer malfunction, and the the emission control system. malfunction. analyzer was returned to service FL-404 Flowmeter SCF 09/05/2018 09 15 09/05/2018 10 15 Monitor Equipment The analyzer was placed in The l&E technician performed maintenance to No changes were made in operation of 100 Malfunction Malfunction maintenance mode due to an analyzer correct an analyzer malfunction, and the the emission control system. malfunction analyzer was returned to service. FL-404 Flowmeter SCF 09/11/2018 1415 09/11/2018 15 30 Monitor Equipment The analyzer was placed in The l&E technician performed maintenance to No changes were made in operation of 1.25 Malfunction Malfunction maintenance mode due to an analyzer correct an analyzer malfunction, and the the emission control system. malfunction. analyzer was returned to service FL-404 Flowmeter SCF 09/14/2018 0145 09/14/2018 0215 Monitor Equipment The analyzer was placed in The l&E technician performed maintenance to No changes were made in operation of 0.50 Malfunction Malfunction maintenance mode due to an analyzer correct an analyzer malfunction, and the the emission control system. malfunction analyzer was returned to service. FL-404 Flowmeter SCF 09/17/20181230 09/17/2018 1315 Monitor Equipment The analyzer was placed in The l&E technician performed maintenance to No changes were made in operation of 0.75 Malfunction Malfunction maintenance mode due to an analyzer correct an analyzer malfunction, and the the emission control system. malfunction analyzer was returned to service. FL-404 Flowmeter SCF 10/02/2018 08 00 10/02/2018 11 30 Monitor Equipment The analyzer was placed in The l&E technician performed maintenance to No changes were made in operation of 3.50 Malfunction Malfunction maintenance mode due to an analyzer correct an analyzer malfunction, and the the emission control system. malfunction. analyzer was returned to service FL-404 Flowmeter SCF 11/05/20181015 11/05/20181130 Monitor Equipment The analyzer was placed in The l&E technician performed maintenance to No changes were made in operation of 1.25 Malfunction Malfunction maintenance mode due to an analyzer correct an analyzer malfunction, and the the emission control system. malfunction. analyzer was returned to service FL-404 Flowmeter SCF 11/26/2018 0915 11/26/2018 1145 Monitor Equipment The analyzer was placed in The l&E technician performed maintenance to No changes were made in operation of 2.50 Malfunction Malfunction maintenance mode due to an analyzer correct an analyzer malfunction, and the the emission control system. malfunction. analyzer was returned to service FL-404 Flowmeter SCF 11/27/2018 1515 11/27/2018 15 30 Monitor Equipment The analyzer was placed in The l&E technician performed maintenance to No changes were made in operation of 0.25 Malfunction Malfunction maintenance mode due to an analyzer correct an analyzer malfunction, and the the emission control system. malfunction. analyzer was returned to service FL-404 Flowmeter SCF 11/28/2018 0900 11/28/2018 0915 Monitor Equipment The analyzer was placed in The l&E technician performed maintenance to No changes were made in operation of 0.25 Malfunction Malfunction maintenance mode due to an analyzer correct an analyzer malfunction, and the the emission control system. malfunction analyzer was returned to service. HFNA-000003231 EPA Inspection Report - Page 1682 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report GOHT Flare (FL-0404) FL-404 Flowmeter Downtime Affected Source Name Monitor Type Monitored Downtime Downtime HAP or i Start Date and Time End Date and Time Gas Duration of Downtime (hours) Type of Downtime Period Type of Cause Brief Description of Cause of Downtime of Deviation Corrective Action Taken Changes to Emission Control 60.108a(d)(6) FL-404 Flowmeter SCF 12/11/2018 0845 12/11/2018 0945 Monitor Equipment The analyzer was placed in The l&E technician performed maintenance to No changes were made in operation of 100 Malfunction Malfunction maintenance mode due to an analyzer correct an analyzer malfunction, and the the emission control system. malfunction. analyzer was returned to service. FL-404 Flowmeter SCF 12/27/2018 1000 12/27/2018 1315 Total Monitor Equipment The analyzer was placed in The l&E technician performed maintenance to No changes were made in operation of 3.25 Malfunction Malfunction maintenance mode due to an analyzer correct an analyzer malfunction, and the the emission control system. malfunction. analyzer was returned to service. 1900 HFNA-000003232 EPA Inspection Report - Page 1683 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report GOHT Flare (FL-0404) FL-404 500M SCF Deviations CMS Monitored Excess Emissions Affected Source Name Monitor Type Monitore d HAP or Gas Excess Emissions Start Date and Time Excess Emissions End Date and Time Duration of Deviation (hours) excess Emissions OccurredfDSu;~g (Y/N) uura11on of excess emissions in nerinrl due to: Brief Description of Nature and Cause of Excess Emission FL-404 FL-404 iFlowmete, SCF 07/19/2018 16:00 07/20/2018 02:00 1000 y Startup Hydrogen venting to the GOH Flare (FL-0404) during startup of the -----+--------------1------------------------------+----------------------------+----------------1------------------------1---------------------IH,,dro_,aen Plant No.1 and increased rate in the CCR contribute to !Flowmete, SCF 07/22/2018 05:00 07/23/2018 17:00 36.00 y Startup the Corrective Action Taken or Preventative Measure Adopted The startup of Unit 63 wa_s complete? and the produ_c~ion rate in the . hydrogen Plant No.2 (Unit 64) was dialed back to minimum rate, reducing the hydrogen flow vented to the flare. Discharges Per 60.108a(d)(5) ~i1~ ~~ot;; :g:;/ttache~aE;~n~aRs:~i~~d;\;: :L- 1201 ! RCAH FL- NSPS Ja Alt Baseline Flow 0404 FL-404 iFlowmete1 SCF 08/27/2018 16:00 08/30/2018 03:00 59.00 During the shutdown period of the Al~fation Unit for flare tip repairs, the The repairs to the Alkylation Flare tip were completed and the Alkylation production rates in the hydrotreater units was reduced, minimizing their unit was restarted. The hydrotreaters' production and hydrogen !see Attached Event Record: "#19-2018-10-25 FL- y Shutdown hydrogen consumption. The hydrogen that was not consumed by these units during this period had to be vented to the GOH flare, contributing to consumption were increased to normal rates, reducing the hydrogen !0404 Ja Alt Baseline Flow RCA" the flare flow to increase above the reporting threshold. discharge to the flare. FL-404 iFlowmete, SCF 09/23/2018 18:00 09/25/2018 00:00 30.00 The electrical power supply from a third party substation to the Artesia The electrical supply was promptly shifted to four additional substations Refinery was interrupted for approximately 3 hours, resulting in the that provide the electrical power to other sections of the refinery, allowing N Other Known shutdown of several process units, as well as several pumps, compressors the electrical power to be restored. The frequency of preventative !see Attached Event Record: "#20-2018-10-16 FL- Cause and other electric pieces of equipment within the refinery. The flaring maintenance activities petionned by the third-party electrical substation !0404 Ja Alt Baseline Flow RCA" associated with the units' shutdown contributed to discharge to the flare in was increased fonn semiannual to monthly basis. excess of the flow baseline reporting threshold. FL-404 iflowmete, SCF 09/25/2018 18:00 09/25/2018 23:00 5.00 FL-404 jFlowmete, SCF 09/28/2018 13:00 09/29/2018 03:00 14.00 FL-404 iFlowmete, SCF 10/2912018 05:00 10/3012018 00:00 19.00 FL-404 iFlowmete, SCF FL-404 !Flowmete, SCF 11/19/201816:00 11/25/2018 01:00 11/25/201815:00 11/27/2018 20:00 129.00 53.00 FL-404 iflowmete, SCF 11/29/2018 04:00 11/29/2018 19:00 Total 15.00 370.00 N y N Other Other Other Other Known Cause The electrical power supply from a third party substation to the Artesia Refinery was interrupted for approximately 3 hours, resulting in the shutdown of several process units, as well as several pumps, compressors and other electric pieces of equipment within the refinery. The flaring associated with the units' shutdown contributed to discharge to the flare in excess of the flow baseline reporting threshold The electrical supply was promptly shifted to four additional substations that provide the electrical power to other sections of the refinery, allowing the electrical power to be restored. The frequency of preventative maintenance activities performed by the third-party electrical substation was increased fonn semiannual to monthly basis. !See Attached Event Record: "#20-2018-10-16 FL- !0404 Ja Alt Baseline Flow RCA" Startup Startup of the Mild Hydrocracker Unit (MHC) following a planned shutdown The planned shutdown and startup procedures were followed. for MHC Guard Bed Reactor catalyst replacement. Process Problems Other Known Cause Other Known Cause Other Known Cause Unexpected shutdown of Diesel Hydrotreater (DHT, Unit 33) Recycle Compressor (C-0693) due to a seal malfunction in the oil level indicator. The hydrogen feed not consumed by the DHT during the shutdown period was vented to the flare, causing the flare flow to exceed the alternative baseline flow reporting threshold of 9 MMSCF in a 24-hour period. Presence of water in the conduit to the level indicator was identified as the cause of the seal malfunction that resulted in the unit shutdown. Between 11/19/18 and 11/26/2018, the GOH Flare (FL-0404) flow baseline reporting threshold was exceeded. During this period, discharges to the flare associated to the startup of the ROSE (Unit 25), the venting of hydrogen associated with an unexpected shutdown of the Diesel Hydrotreater (DHT, Unit 33) Recycle Hydrogen Compressor (C-0693), the planned shutdown of the Mild Hydrotreater (MHC) unit, and the unit startup of several process units after an unexpected interruption of electrical power to the refinery, contributed to increasing the flare flow above the reporting threshold. 1&3 technicians removed the water, restarted the compressor and the DHT, stopping the venting of excess hydrogen to the flare. Units were restarted; C-693 was repaired returned online. iSee Attached Event Record: "#21-2018-10-17 FL- i0404 Ja Alt Baseline Flow RCA" and "#22- i201 Ja RCA S02 FL-0404" isee Attached Event Record: "#23-2018-11-06 FL- i0404 Ja Alt Baseline Flow RCA" !See Attached Event Record: "#24-2018-12-06 FL- !0404 Ja Baseline Flow RCA" HFNA-000003233 EPA Inspection Report - Page 1684 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja - 162 ppmvd H2S 3-hour rolling average Artesia GOH Flare, FL-404 60.103a Design, equipment, work practice or operational standards (h) Each owner or operator shall not bum in any affected flare any fuel gas that contains H2S in excess of 162 ppmv determined hourly on a 3-hour rolling average basis. The combustion in a flare of process upset gases or fuel gas that is released to the flare as a result of relief valve leakage or other emergency malfunctions is exempt from this limit. 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. (a) Fuel gas combustion devices subject to S02 or H2S limit and flares subject to H2S concentration requirements. (2) The owner or operator of a fuel gas combustion device that elects to comply with the H2S concentration limits in 60.102a(g)(1)(ii) or a flare that is subject to the H2S concentration requirement in 60.103a(h) shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration by volume (dry basis) of H2S in the fuel gases before being burned in any fuel gas combustion device or flare. (3) The owner or operator of a fuel gas combustion device or flare is not required to comply with paragraph (a)(l) or (2) of this section for fuel gas streams that are exempt under 60.102a(g)(1)(iii) or 60.103a(h) or, for fuel gas streams combusted in a process heater, other fuel gas combustion device or flare that are inherently low in sulfur content. (e) Su(f'ur monitoringfor assessing root cause analysis thresholdfor affectedflares. (2) H2S monitoring requirements. The owner or operator shall install, operate, calibrate, and maintain an instrument for continuously monitoring and recording the concentration of H2S in gas discharged to the flare according to the requirements in paragraphs (e)(2)(i) through (iii) of this section and shall collect and analyze samples of the gas and calculate total sulfur concentrations as specified in paragraphs (e)(2)(iv) through (ix) of this section. Flare FL-404 is subject to the 162 ppmv hydrogen sulfide (H2S) limit. Therefore, Navajo maintains an H 2S CEMS on Flare FL-404 that records concentrations in parts per million by volume on a dry basis (ppmvd). Note: 60. l03a(h) exempts process upset gases and releases resulting from relief valve leakage or other emergency malfm1ctions from the requirement to meet the 162 ppm (H2S) limit. In this report we have included infonnation on these events subject to exemptions, and have identified them as such. HFNA-000003234 EPA Inspection Report - Page 1685 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report for GOHT Flare (FL-0404) FL-404 H2S CEMS Summary Affected Source Emission Limit Citation Emission Limitation (H 2S ppmv on rolling 3-hours) Monitor Manufacturer and Model No. Monitor Serial Number Date of Latest CMS Certification or Audit Reporting Period Beginning Date Reporting Period Ending Date FL-404 GOH Flare 60.103a(h) 60.107a(e)(2) 162 Siemens - Maxum II 30049702230100 02/14/2018 07/01/2018 12/31/2018 Total Time in Reporting Period Total Source Downtime Total Source Operating Time in Reporting Period (hours) (hours) (hours) 4416 0 4416 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Number of Incidents 4 0 184 10 0 Duration (Hours) 745.00 0.00 0.00 78.00 0.00 Totals 198 Total CMS Downtime as a Percent of Total Source Operating Time 823.00 18.64% Emission Data Summary (Exceeds 162 H2S ppmv on rolling 3-hours) Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Totals Total Duration of Deviations as a Percent of Total Source Operating Time Number of Incidents 3 2 0 7 5 2 19 Duration (Hours) 30.00 9.00 0.00 78.00 25.00 3.00 145.00 3.28% HFNA-000003235 EPA Inspection Report - Page 1686 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report for GOHT Flare (FL-0404) FL-404 H2S CEMS Downtime GEMS Downtime Affected Source Name Monitor Type Monitored Downtime HAP or Start Date and Time Gas DoV\111time End Date and Time Duration of DoV\111time (hours) Type of Downtime Period Type of Cause of Deviation Brief Description of Cause of Downtime Corrective Action Taken Changes to Emission Control 60.108a(d)(6) FL-404 GEMS H2S 07/30/2018 08:55 07/30/2018 11 :50 3.00 Other Known Cause Other The analyzer vvas placed in maintenance mode to perform maintenance. The l&E technician changed the probe filter and returned the analyzer to service. No changes were made in operation of the emission control system. FL-404 GEMS H2S 08/22/2018 09:41 08/22/2018 11 :36 1.00 Other Known Cause Other The analyzer vvas placed in maintenance mode to perform a CGA The E&I technician performed the CGA and returned the analyzer to service. No changes were made in operation of the emission control system FL-404 FL-404 FL-404 FL-404 FL-404 FL-404 FL-404 GEMS GEMS GEMS GEMS GEMS GEMS GEMS H2S 09/05/2018 05:00 09/05/2018 10: 15 5.00 H2S 09/11/20181330 09/11/2018 15:20 1.00 Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to low sample pressure. The l&E technician identified contamination in the sample pump as the cause of malfunction. The sample pump was cleaned and rebuilt, and the analyzer vvas returned to service. No changes were made in operation of the emission control system. Other Known Cause Other The analyzer vvas placed in maintenance mode to perform maintenance. The l&E technician replaced the sample pump assembly in the SGS cabinet, and returned the analyzer to service. No changes were made in operation of the emission control system H2S 09/13/2018 23:00 09/14/2018 02:00 3.00 Monitor Equipment Malfunction Malfunction The analyzer vvas placed in maintenance mode due to a sample pump failure. The l&E technician repaired the pump, replacing the diaphragm and valves, and returned the analyzer to service. No changes were made in operation of the emission control system. H2S 09/17/2018 11 :45 09/17/201813:15 1.00 Other Known Cause Other The analyzer vvas placed in maintenance mode to perform routine maintenance. The l&E technician changed the probe filter, the water carry over filter, rebuilt sample pump, and returned the analyzer to service. No changes were made in operation of the emission control system. H2S 10/24/2018 08:57 10/26/2018 14:39 53.00 Other Known Cause Other The analyzer vvas placed in maintenance mode to complete the installation of new equipment for the RSR upgrade Maintenance/project \/\/Ork was being performed for No changes were made in operation of the RSR upgrade, and the analyzer was returned to the emission control system. service when completed. H2S 10/26/2018 14:39 11/01/2018 00:00 129.00 Monitor Equipment Malfunction Malfunction The monitor was placed in maintenance mode The technician repaired the analyzer and returned it No changes were made in operation of due to analyzer failures. to service the emission control system. H2S 11/01/2018 0000 11/26/2018 08:00 608.00 Monitor Equipment Malfunction Malfunction The monitor was placed in maintenance mode The technician repaired the analyzer and returned it No changes were made in operation of due to analyzer failures to service. the emission control system FL-404 GEMS H2S 11/26/2018 08:37 11/26/2018 11 :42 2.00 Other Known Cause FL-404 FL-404 FL-404 GEMS GEMS GEMS H2S 11/27/2018 09:00 11/27/2018 16:00 700 H2S 11/28/2018 07:40 11/28/2018 12:00 4.00 H2S 12/06/2018 10:36 12/06/2018 12: 22 1.00 Other Known Cause Other Known Cause Other Known Cause Other The analyzer vvas placed in maintenance mode to complete project tie-in. The l&E technician proceeded with the RSR project No changes were made in operation of tie-ins and returned the analyzer to service. the emission control system Other Other Other The analyzer vvas placed in maintenance mode to complete project tie-in. The analyzer vvas placed in maintenance mode to complete a linearity test. The analyzer vvas placed in maintenance mode to perform a CGA The l&E technician proceeded with the RSR project No changes were made in operation of tie-ins and returned the analyzer to service. the emission control system. The l&E technician performed a linearity test and returned the analyzer to service. No changes were made in operation of the emission control system The E&I technician performed the CGA and returned the analyzer to service. No changes were made in operation of the emission control system. HFNA-000003236 EPA Inspection Report - Page 1687 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report for GOHT Flare (FL-0404) FL-404 H2S CEMS Downtime Affected Source Name FL-404 Monitor Type CEMS Monitored Downtime HAP or Start Date and Time Gas Dovvntime End Date and Time Duration of Dovvntime (hours) H2S 12/27/2018 08:05 12/27/201813:15 5.00 Total 823.00 Type of Downtime Period Other Known Cause Type of Cause of Deviation Brief Description of Cause of Downtime Other The analyzer vvas placed in maintenance mode due to plugged probe and pump. Corrective Action Taken Changes to Emission Control 60.108a(d)(6) The l&E technician replaced the filter and rebuilt pump. The sample system would not heat up. Freed up pressure switch and the system heated, and the analyzer was returned to service No changes were made in operation of the emission control system. HFNA-000003237 EPA Inspection Report - Page 1688 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report for GOHT Flare (FL-0404) FL-404 H2S Excess Emissions CEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions Sta rt Date and Ti me Excess Emissions End Date and Time Excess Duration of Emissions Deviation Occurred (hours) i During Period of SSM (YIN) Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission Corrective Action Taken or Preventative Measure Adopted FL-404 CEMS H2S 08/06/2018 15:00 08/06/2018 16: 00 1.00 FL-404 CEMS H2S 08/26/2018 16:00 08/26/2018 18:00 2.00 The GOH (FL-0404) flare header exceeded the NSPS Ja limit of 162 Operations immediately increased f-bS scavenger injection rate. The event N Other Unknown ppm H2S, on a 3-hour rolling average basis. Operations conducted a ended before the actual cause of the event could be determined or Cause unit wide walk-through looking for potential equipment and relief valve corrective actions were implemented. leaks with no issues found. The GOH flare header exceeded the NSPS Ja limit of 162 ppm H2S, Operations immediately increased f-bS scavenger injection rate. The event N Other Unknown on a 3-hour rolling average basis. Operations conducted a unit wide ended before the actual cause of the event could be determined or Cause walk-through looking for potential equipment and relief valve leaks wiU corrective actions were implemented. no issues found. FL-404 CEMS H2S 08/29/2018 06:00 08/29/2018 09: 00 3.00 y Shutdown The GOH flare header exceeded the NSPS Ja limit of 162 ppm H2S, on a 3-hour rolling average basis while depressuring the Asphaltene Separator (D-2502) for planned maintenance on Unit 25 A controlled venting to the flare was monitored to relieve the pressure in the drum. As soon as the pressure in the drum was reduced within normal operating values, the venting to flare was stopped. The gas was safely combusted and dispersed from a steam-assisted flare, which aides in dispersion FL-404 CEMS H2S 09/06/2018 18:00 09/07/2018 05:00 11.00 y Startup During start up of Unit 25, drum D-2506 was vented to flare to maintain pressure and levels. The standard operating procedures were followed to minimize emissions from the flare during startup of the units Scavenger was injected to minimize S02 emissions. FL-404 CEMS H2S 09/22/2018 05 00 09/22/2018 08:00 3.00 N Process Problems Unexpected shutdown of Amine Unit Lean Amine Pump (P-0775). The Electricians were called as soon as the switchgear malfunctioned, spare Lean Amine Pump (P-0776) was started. While testing P-0775, determining that the bucket style breaker tripped. The breaker was reset. the the switch rack breaker feeding the breaker rack shorted causing a spare pump (P-0776) was restarted. The Amine contactors were returned loss of power to both amine pumps. The amine contactors could not on line, resuming normal operation. To minimize excess SQ emissions from operate, reducing the treating capacity of acid gas being sent to the the flare, operations promptly injected an H:,S scavenger agent upstream of fuel gas system This caused an exceedance of the NSPS Ja 162 ppm H2S 3-hour rolling average at the flare. the Flare Knockout drum in order to reduce the emissions of S02 from the flare. FL-404 CEMS H2S 09/22/2018 21 :00 09/23/2018 03:00 6.00 y Shutdown Planned shutdown of the Mild Hydrocracker (MHC) unit for catalyst replacement in the Guard Bed Reactor. The unit shutdown procedure was followed. During the shutdovvn and decontamination of the MHC, pressure normally builds up in the reactors and the fractionator, which has to be relieved to the flare. The unit shutdown procedure was followed. Additionally, f-bS scavenger was injected at maximum rate to reduce the concentration of this gas in the flare header. The minimum volume necessary to safely de-pressure the system was vented to the flare. FL-404 CEMS FL-404 CEMS H2S 09/23/2018 07 00 09/23/2018 15:00 8.00 H2S 09/23/2018 22:00 09/2412018 07:00 9.00 FL-404 CEMS H2S 09/24/2018 10:00 09/24/2018 13:00 3.00 FL-404 CEMS FL-404 CEMS H2S 09/24/2018 19:00 09/24/2018 22:00 3.00 H2S 09/25/2018 08:00 09/25/2018 10: 00 2.00 Other Known N Cause The electrical power supply from a third party substation to the Artesia Refinery was interrupted for approximately 3 hours, resulting in the Other Known shutdown of several process units, as well as several pumps, N Cause compressors and other electric pieces of equipment within the refinery. Off-gas was continued to be produced some time after the The electrical supply was promptly shifted to four additional substations that Other Known power outage occurred and the process units shut dovvn. Without the provide the electrical power to other sections of the refinery, allovving the electrical power to be restored, and process units to be restarted. The N Cause electrical power to operate amine contactors and H:,S strippers, the frequency of preventative maintenance activities performed by the third- H:::,S concentration in the FGS and Amine Unit increased. Because the party electrical substation was increased form semiannual to monthly basis Other Known FG is also used as vent gas in the flare system, the H2S concentration N Cause increase in the FGS was transferred to the North Plant, FCC, and GOH flare systems, resulting in excess of the NSPS Ja 162 ppm H2S N Other Known 3-hour rolling average. Cause FL-404 CEMS H2S 09/28/2018 17 00 09/29/2018 11 :00 18.00 y FL-404 CEMS H2S 09/29/2018 15:00 09/29/2018 16: 00 1.00 y Startup Startup S1artup of the MHC after catalyst replacement in the Guard Bed Reactor. The unit startup procedure was followed HFNA-000003238 EPA Inspection Report - Page 1689 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report for GOHT Flare (FL-0404) FL-404 H2S Excess Emissions CEMS Monitored Excess Emissions Affected Source Name Monitor Type Monitored HAP or Gas Excess Emissions Sta rt Date and Ti me Excess Em1ss1ons End Date and Trme Excess Duratron of Emissions Dev1at1on Occurred (hours) i During Period of SSM (YIN) Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission Corrective Action Ta ken or Preventative Measure Adopted FL-404 GEMS H2S 10101/201811:00 10/0312018 03:00 40.00 N FL-404 GEMS H2S 10103/2018 05:00 10/0312018 22: 00 17.00 N FL-404 GEMS H2S 10/0412018 11 00 10104/2018 15:00 4.00 N FL-404 GEMS H2S 10104/201817:00 10104/2018 23:00 6.00 N FL-404 GEMS H2S 10105/201810:00 10/0512018 12: 00 2.00 N FL-404 GEMS H2S 10105/20181600 10/0512018 22: 00 6.00 N Total 145.00 Process Problems Process Problems Process Problems Process Problems Process Problems Process Problems !An increase of the FGS H2S concentration was transferred to the flare There are three scavenger injection points to the flare system. Adjusting iheader. causing the NSPS Ja 162 ppm H2S 3-hour rolling average to these injection points did not alleviate the issue. Investigation continued and ibe exceeded intermittently operations found a plugged quill at one of the injection points. HFNA-000003239 EPA Inspection Report - Page 1690 of 1969 HollyFrontier Navajo Refining LLC Artesia, Nl'v1 Refinery NSPS Subpart Ja - 500 lb S02 24-hour rolling average Artesia GOH Flare, FL-404 60.103a Design, equipment, work practice or operational standards (c) Except as provided in paragraphs (t) and (g) of this section, each owner or operator that operates a flare subject to this subpart shall conduct a root cause analysis and a corrective action analysis for each of the conditions specified in paragraphs (c)(l) of this section. (1) For a flare: (i) Any time the S02 emissions exceed 227 kilograms (kg) (500 lb) in any 24-hour period; or 60.107a Monitoring of emissions and operations for fuel gas combustion devices and flares. (a) Fuel gas combustion devices subject to S02 or II2S limit and flares subject to II2S concentration requirements. (2) The owner or operator of a fuel gas combustion device that elects to comply with the II2S concentration limits in 60.102a(g)(1)(ii) or a flare that is subject to the II2S concentration requirement in 60.103a(h) shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration by volume (dry basis) of II2S in the fuel gases before being burned in any fuel gas combustion device or flare. (3) The owner or operator of a fuel gas combustion device or flare is not required to comply with paragraph (a)(l) or (2) of this section for fuel gas streams that are exempt under 60.102a(g)(1)(iii) or 60.103a(h) or, for fuel gas streams combusted in a process heater, other fuel gas combustion device or flare that are inherently low in sulfur content. (e) Su(f'ur monitoringfor assessing root cause analysis thresholdfor affectedflares. Except as described in paragraphs (e)(4) and (h) of this section, the owner or operator of an affected flare subject to 60.103a(c) through (e) shall determine the total reduced sulfur concentration for each gas line directed to the affected flare in accordance with either paragraph (e)(l), (e)(2) or (e)(3) of this section. (1) Total reduced sulfur monitoring requirements. The owner or operator shall install, operate, calibrate and maintain an instrument for continuously monitoring and recording the concentration of total reduced sulfur in gas discharged to the flare. Flare FL-404 is subject to the 500 lbs S02 threshold monitoring requirements. Navajo maintains a CEMS for continuously measuring the concentration of total reduced sulfur in gas discharged to the flare. HFNA-000003240 EPA Inspection Report - Page 1691 of 1969 HollyFrontier Navajo Refining LLC Artesia Refinery NSPS Subpart Ja Periodic Report GOHT Flare (FL-0404) FL-404 500 lb S0 2 CEMS Summary Affected Source Emission Limit Citation Emission Limitation (lbs S02 in rolling 24 hours) FL-404 GOH Flare 60.107a(e)(1) 500 Monitor Manufacturer and Model No. ThermoScientific - SOLA 11 Monitor Serial Number SL-10030914 Date of Latest CMS Certification or Audit 12/06/2018 Reporting Period Beginning Date Reporting Period Ending Date Total Time in Reporting Period Total Source Downtime Total Source Operating Time in Reporting Period 07/01/2018 12/31/2018 (hours) 4416 (hours) 0 (hours) 4416 CMS Performance Summary CMS downtime in reporting period due to: Monitoring Equipment Malfunctions Non-Monitoring Equipment Malfunctions (e.g., Computer, Data Recorder, Etc.) Quality Assurance/Quality Control Calibrations Other Known Causes Other Unknown Causes Number of Incidents 4 0 185 9 0 Duration (Hours) 39.00 0.00 1.00 25.00 0.00 Totals 198 Total CMS Downtime as a Percent of Total Source Operating Time 65.00 1.47% Emission Data Summary Duration of excess emissions in reporting period due to: Startup Shutdown Control Equipment Problems Process Problems Other Known Causes Other Unknown Causes Totals Total Duration of Deviations as a Percent of Total Source Operating Time Number of Incidents 1 0 0 0 1 0 2 Duration (Hours) 24.00 0.00 0.00 0.00 10.00 0.00 34.00 0.77% HFNA-000003241 EPA Inspection Report - Page 1692 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery NSPS Subpart JA Periodic Report GOHT Flare (FL-0404) FL-404 500 lb S02 GEMS Downtime CEMS Downtime Affected Monitor Monitored Downtime Downtime Source Name Type HAP or Gas Start Date and Time End Date and Time Duration of Downtime (hours) FL-404 CEMS so, 07/21/2018 08:42 07/21/2018 09:50 1.00 Type of Downtime Period Quality Assurance Calibration Type of Cause of Deviation Brief Description of Cause of Downtime Corrective Action Taken Changes to Emission Control 60.108a(d)(6) other The analyzer was placed in calibration mode to The E&I technician ran calibration gases to the probe to check verify calibration values the analyzer and returned the analyzer to service. No changes were made in operation of the emission control system. FL-404 CEMS so, 07/30/2018 08:55 07/30/201811:50 3.00 Other Known Cause Other The analyzer was placed in maintenance mode The l&E technician changed the probe filter and returned the to perform maintenance analyzer to service. No changes were made in operation of the emission control system. FL-404 CEMS so, FL-404 CEMS so, FL-404 CEMS so, FL-404 CEMS SO- FL-404 CEMS so, FL-404 CEMS so, FL-404 CEMS SO- FL-404 CEMS so, FL-404 CEMS so, FL-404 CEMS so, FL-404 CEMS so, FL-404 CEMS so, 08/22/2018 13:20 08/22/2018 15:15 1.00 09/05/2018 05:00 09/05/2018 10:15 5.00 09/11/2018 13:30 09/11/201815:20 1.00 09/13/2018 23:00 09/14/2018 02:00 3.00 10/19/2018 04:30 10/20/2018 1000 30.00 11/05/2018 09:36 11/05/201811:34 1.00 11/16/2018 09:20 11/16/201811:30 1.00 11/26/2018 08:37 11/26/2018 11 :42 2.00 11/27/2018 09:00 11/27/201816:00 7.00 11/28/2018 07:40 11/28/201812:00 4.00 12/06/2018 10:36 12/06/2018 1222 1.00 12127/2018 08:05 12/27/2018 13:15 5.00 Total 65.00 Other Known Cause Monitor Equipment Malfunction Other Known Cause Monitor Equipment Malfunction Monitor Equipment Malfunction Monitor Equipment Malfunction Other Known Cause Other Known Cause Other Known Cause Other Known Cause Other Known Cause Other Known Cause Other The analyzer was placed in maintenance mode The l&E Technician performed a CGA and returned the analyzer No changes were made in operation of the to perfonn a CGA. to service. emission control system. Malfunction The analyzer was placed in maintenance mode due to low sample pressure. The l&E technician determined that the low pressure was caused by sample pump contamination. The sample pump head was cleaned, the pump rebuilt. and the analyzer was returned to service. No changes were made in operation of the emission control system. Other The analyzer was placed in maintenance mode The l&E technician replaced the sample pump assembly on the No changes were made in operation of the to perform maintenance SCS cabinet, and returned the analyzer to service. emission control system. Malfunction The analyzer was placed in maintenance mode The l&E technician repaired the pump, replacing the diaphragm No changes were made in operation of the due to a sample pump failure. and valves, and returned the analyzer to service emission control system. Malfunction The analyzer was placed in maintenance mode The l&E Technician recalibrated and returned the analyzer to due to a failed calibration. service. No changes were made in operation of the emission control system. Malfunction The analyzer was placed in maintenance mode The l&E technician rebuilt the sample pump, and returned the due to a sample pump failure analyzer to service. No changes were made in operation of the emission control system. Other Other Other Other Other other The analyzer was placed in maintenance mode The l&E technician performed a CGA and returned the analyzer No changes were made in operation of the to perfonm a CGA. to service emission control system. The analyzer was placed in maintenance mode The l&E technician proceeded with the RSR project tie-ins and to complete project tie-ins. returned the analyzer to service. No changes were made in operation of the emission control system. The analyzer was placed in maintenance mode The l&E technician proceeded with the RSR project tie-ins and to complete project tie-ins. returned the analyzer to service No changes were made in operation of the emission control system. The analyzer was placed in maintenance mode The l&E technician performed a linearity test and returned the to perform a linearity test. analyzer to service. No changes were made in operation of the emission control system. The analyzer was placed in maintenance mode The l&E technician performed a CGA and returned the analyzer No changes were made in operation of the to perfonm a CGA. to service. emission control system. The analyzer was placed in maintenance mode due to plugged probe and pump The l&E technician replaced the filter and rebuilt the pump The sample system would not heat up. The pressure switch was reset and the system began to heat up, and the analyzer was returned to service. No changes were made in operation of the emission control system. HFNA-000003242 EPA Inspection Report - Page 1693 of 1969 HollyFrontier Navajo Refining LLC Artesia, NM Refinery NSPS Subpart Ja Periodic Report GOHT Flare (FL-0404) FL-404 500 lb S02 Excess Ernissi GEMS Monitored Excess Emissions Affected Source Name Monitor M~;i~o~~d Excess Emissions Type Gas Start Date and Time Excess Emissions End Date and Time Duration of Deviation (hours) Excess Emissions Occurred During Period ofSSM(Y/N) Duration of excess emissions in reporting period due to: Brief Description of Nature and Cause of Excess Emission Corrective Action Taken or Preventative Measure Adopted Discharges Per 60.108a(d)(5) The electrical power supply from a third party substation to the Artesia Refinery ,,vas interrupted for approximately 3 hours, resulting in the shutdown of several process units, as well as several pumps, compressors and other electric pieces of The electrical supply was promptly shifted to four additional substations Other Known equipment v.ithin the refinery. Off-gas was continued to be produced some time that provi~e the electrical power to other sections of the refiner~, allowing See Attached Event Record: "#25-201 8- FL-404 CEMS so, 09/24/2018 01 :DO 09/24/201811:00 1000 N after the power outage occurred and the process units shut down. Without the the_electncal PO\~~~ to be restored. The fre_quency of pre\entat1ve . _ NSPS Ja RCA FL- ., Cause 10 08 802 0404 electrical power to operate amine contactors and H 2S strippers, the H2S maintenance act1V1t1es performed by the third-party electrical substation concentration in the FGS and Amine Unit increased. The flaring associated with the was increased from semiannual to monthly basis. units' shutdown and subsequent startup resulted in emissions from the GOH Flare to exceed 500 lbs. S0 2 in a 24-hour period. FL-404 CEMS 09/28/2018 23:00 09/29/2018 23:00 24.00 y Total 34.00 Startup Planned shutdown of the Mild Hydrocracker (MHC) unit for catalyst replacement in the Guard Bed Reactor. The unit shutdown procedure was followed. During the shutdown and decontamination of the MHC. pressure normally builds up in the reactors and the fractionator, v,thich has to be relieved to the flare. The unit shutdown procedure was followed See Attached Event Record: "#26-201810-25 NSPS Ja RCA S02 FL-0404" HFNA-000003243 EPA Inspection Report - Page 1694 of 1969 NSPS SUBPART Ja ROOT CAUSE ANALYSYS Reporting Period:July-December 2018 HFNA-000003244 EPA Inspection Report - Page 1695 of 1969 H.OLLYF.RONTIER #1-2018-08-28 FL-0400 NSPS JaFlow RCA Pagel of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: August 28, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from the North Flare (FL-0400) per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 06/16/2018, the North Flare (FL-0400) began exceeding its baseline threshold by >500,000 scfd while flaring. The excess flaring was caused by the SRU (Unit 31) thermal reactor (D-3100) being taken out of service to repair a crack near the acid gas inlet nozzle to the rear chamber. Rates were decreased through the area to move the acid and sour water gas to the other SRU (Unit 30). At approximately 15:00 on 07/12/2018 FL-0400 began exceeding its baseline threshold until approximately 18:00 on 07/13/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 07/12/2018 15 :00 Event Duration: 07/12/2018 15:00 -07/13/2018 18:00; 28 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) North Flare (FL-0400) Measured Quantity of Gas Discharged over Event Duration (dscf) 1,575,530 24-Hour Period 07/12/2018 15:00 - 07/12/2018 23:59 07/13/2018 00:00 - 07/13/2018 18:59 Quantity of Gas Discharged in 24-Hour Period (dsc:I) 735,530 840,000 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(]) from a fuel gas combustion device, either the measured concentration of H2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. HFNA-000003245 EPA Inspection Report - Page 1696 of 1969 #1-2018-08-28 FL-0400 NSPS JaFlow RCA Page 2 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess e1nissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Unit feed rates were reduced to mini1nize excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d). including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): North Flare (FL-0400) Date of Discharge: 07/12/2018 DurationofDischarge: 28 hours ROOT CAUSE ANALYSIS Unexpected shutdown of the SRU 2 (Unit 31) caused excess flaring to the North Plant Flare (FL-0400). CORRECTIVE ACTION ANALYSIS Unit feed rates were reduced so that excess flaring was minimized. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e). a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action Unit feed rates reduced Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003246 EPA Inspection Report - Page 1697 of 1969 H.OLLYF.RONTIER #2-2018-08-28 FL-0400 NSPS JaFlow RCA Pagel of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: August 28, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from the North Flare (FL-0400) per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 07/16/2018, the North Flare (FL-0400) began exceeding its baseline threshold by >500,000 scfd while flaring. The excess flaring was caused by the fuel balance drum (D-19) receiving excess sweet gas from various units throughout the facility. At approximately 18:00 on 07/16/2018 FL-0400 began exceeding its baseline threshold until approximately 17:00 on 07/17/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 07/16/2018 18:00 Event Duration: 07/16/2018 18:00 -07/17/2018 17:00; 24 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) North Flare (FL-0400) Measured Quantity of Gas Discharged over Event Duration (dscf) 1,133,110 24-Hour Period 07/16/2018 18:00 - 07/16/2018 23:59 07/17/2018 00:00-17/17/2018 17:59 Quantity of Gas Discharged in 24-Hour Period (dscf) 342,780 790,330 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(]) from a fuel gas combustion device, either the measured concentration of H2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4 ). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. HFNA-00000324 7 EPA Inspection Report - Page 1698 of 1969 #2-2018-08-28 FL-0400 NSPS JaFlow RCA Page 2 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess e1nissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Unit feed rates were reduced to mini1nize excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d). including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): North Flare (FL-0400) Date of Discharge: 07/16/2018 DurationofDischarge: 24 hours ROOT CAUSE ANALYSIS The fuel balance drum (D-19) reduced venting from the vessel to the flare. CORRECTIVE ACTION ANALYSIS Unit feed rates were reduced so that excess flaring was minimized. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e). a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action D-19 reduced venting Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003248 EPA Inspection Report - Page 1699 of 1969 H.OLLYF.RONTIER #3-2018-10-05 FL-0400 NSPS JaFlow RCA Pagel of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: October 8, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from the North Flare (FL-0400) per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 09/24/2018, the North Flare (FL-0400) began exceeding its baseline threshold by >500,000 scfd while flaring. The Naphtha Hydrodesulfurization Unit (Unit 13) experienced a flange leak causing the Splitter Distillate Drum (D-44) and the Product Separator Drum (D-58) to empty to the flare so that repairs could be made. The unit was brought back online with additional malfunctions (EIV 13HIS181) and was shut-down again to repair EIV. The unit was brought back into service on 09/26/2018 with no additional issues. Steps were taken to prevent excess emissions during startup/shutdown/startup. Scavenger was injected to reduce H2S in the flare. At approximately 03:00 on 09/24/2018 FL-0400 began exceeding its baseline threshold until approximately 18:00 on 09/27/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 09/24/2018 03 :00 Event Duration: 09/24/2018 03 :00 - 09/27/2018 18:00; 88 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) North Flare (FL-0400) Measured Quantity of Gas Discharged over Event Duration (dscf) 5,210,970 24-Hour Period 09/24/2018 03:00 - 09/24/2018 23:59 09/25/2018 00:00 - 09/25/2018 23:59 09/26/2018 00:00 - 09/26/2018 23:59 09/27/2018 00:00 - 09/27/2018 18:00 Quantity of Gas Discharged in 24-Hour Period (dsc:I) 1,712,370 1,321,350 1,326,530 850,720 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60 I02a(g)(I) from a fuel gas combustion device, either the measured concentration of H 2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4). Not applicable to this event. HFNA-000003249 EPA Inspection Report - Page 1700 of 1969 #3-2018-10-05 FL-0400 NSPS JaFlow RCA Page 2 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 60.108a(c)(6) (vi) For each discharge greater than 5001bs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. 60.108a(c)(6) (vii) For each discharge greater than 5001bs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess emissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Unit feed rates were reduced to minimize excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d), including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): North Flare (FL-0400) Date of Discharge: 09/24/2018 Duration of Discharge: 88 hours ROOT CAUSE ANALYSIS The Naphtha Hydrodesulfurization Unit (Unit 13) e;,.,.1)erienced a flange leak causing the Splitter Distillate Drum (D-44) and the Product Separator Drum (D-58) to empty to the flare so that repairs could be made. The unit was brought back online with additional malfm1ctions (EIV 13HIS181) and was shutdown again to repair EIV. The unit was brought back into service on 09/26/2018 with no additional issues. CORRECTIVE ACTION ANALYSIS Steps were taken to repair the flange and then the EIV. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60. l03a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action Repairs made Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planued startup or shutdown of a refinery process unit or ancillary equipment conuected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003250 EPA Inspection Report - Page 1701 of 1969 4 F: HOLLYFRONTIER #4-2018-10-08 NSPS JaRCA S02 FL-0400 Page 1 of2 ................................................................................................................HollyFrontier Navajo Refining LLC 501 E. Main Artesia, NM 88201 (575) 748-3311 DATE: October 8, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for S02 from Flares per 60. l03a(c)(l) I 60.l08a(c)(6)(i) A description of the discharge. Unexpected shutdown of the Naphtha Hydrotreating Unit (Unit 13) due to a flange leak. This caused the Naphtha Separator (D-0058) and Splitter Distillate (D-0044) to vent to the North Flare (FL-0400), resulting in emissions above the reporting threshold. I 60.l08a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 09/24/2018 07:00 Event Duration: 09/24/2018 07:00 - 09/27/2018 18:00; 69 hours 60. l08a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.l07a(g). Affected Facility(s) North Flare FL-0400 24-hour Period 09/24/2018 07:00 - 09/24/2018 22:59 09/25/2018 14:00 - 09/25/2018 23:59 09/26/2018 00:00 - 09/26/2018 23:59 09/27/2018 00:00 - 09/27/2018 18:59 Quantity of Gas Discharged over Event Duration (dscf) L026,840 633,000 L326,530 850,720 60.l08a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Date 09/24/2018 07:00 - 09/24/2018 22:59 09/25/2018 14:00 - 09/25/2018 23:59 09/26/2018 00:00 - 09/26/2018 23:59 09/27/2018 00:00 - 09/27/2018 18:59 Number of hours 16 10 24 19 Hourly Average Measured Total Sulfur Concentration During Event (ppm) {60.l08a(c)(6)(iv)} 1,193 23,781 6,175 248 60.l08a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(l) from a fuel gas combustion device, either the measured concentration ofH2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60. l07a(e)(4). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. HFNA-000003251 EPA Inspection Report - Page 1702 of 1969 #4-2018-10-08 NSPS JaRCA S02 FL-0400 Page 2 of2 .....................................................................................................................................................................................HollyFrontier ..Navajo...R e f i n i n g L L C Not applicable to this event. 501 E. Main Artesia, NM 88201 (575) 748-3311 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Affected Facility North Flare (FL-0400) Cumulative Quantity ofH2S Released (pounds) 27 Cumulative Quantity of S02 Released (pounds) 5,055 I 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. The flange was repaired. The gas was safely combusted in a steam-assisted flare and scavenger was i1tjected into the system. Maintenance worked quickly to detennine what steps needed to be taken to reduce excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d), including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): North Flare (FL-0400) Date of Discharge: 09/24/2018 Duration of Discharge: 69 hours ROOT CAUSE ANALYSIS Unexpected shutdown of the Naphtha Hydrotreating Unit (Unit 13) due to a flange leak. This caused the Naphtha Separator (D-0058) and Splitter Distillate (D-0044) to vent to the North Flare (FL-0400). resulting in emissions above the reporting threshold. CORRECTIVE ACTION ANALYSIS The leak was repaired. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action The leak was repaired Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003252 EPA Inspection Report - Page 1703 of 1969 4 F: HOLLYFRONTIER #5-2018-11-26 FL-0400 NSPS Ja S02 RCA Page 1 of2 Hollyfrnnti~r N~v~jq R~fining lJ,C 501 E. Main Artesia, NM 88201 (5 75) 748-3311 DATE: November 26, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for S02 from Flares per 60.103a(c)(]) I 60 .108a(c)(6)(i) Adescription ofthe discharge. Process imbalance in the NHU debutanizer system, which included a pressure increase in the splitter overhead system, and resulted in venting ofoverhead gases with high sulfur (S) content from the Splitter Distillate Drum (D-0044). The associated flare emissions exceeded 500pounds of sulfur dioxide (S02) on a 24-hour basis. I 60 .108a(c)(6)(ii) The date and time the discharge was first identified and the duration ofthe discharge. Event Start Date & Time: 11/08/2018 18:00 Event Duration: l l/08/201818:00-1l/09/201817:00: 24 hours 60 .108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) North Flare FL-0400 24-hour Period 11/08/201818:00- l l/09/2018 17:00 Quantity of Gas Discharged over Event Duration(dscf) 1,036,940 60.] 08a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Date 11/08/2018 18:00- 11/09/2018 17:00 Number of hours 24 Hourly Average Measured Total Sulfur Concentration During Event (ppm) {60.108a(c)(6)(iv)} 3,439.8 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60 l 02a(g)(l) from a fuel gas combustion de"ice, either the measured concentration ofH2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion de-vices, but cannot be used to make these estimates for flares, except as provided in I 60.107a(e)(4). Not applicable to this event. 60 .108a(c)(6) (-vi) For each discharge greater than 5OOlbs S02 in excess of the allowable limits from a sulfur recovery pl ant, either the measured concentration ofreduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. 60 .108a(c)(6) (-vii) For each discharge greater than 5OOlbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess ofthe allowable limits from a fuel gas combustion device or sulfur recovery plant, the HFNA-000003253 EPA Inspection Report - Page 1704 of 1969 #4-2018-10-08 NSPS Ja RCA S02 FL-0400 Page 2 of2 H<::>IIYfr9nJiE:lL Nc:1vc:1j9 RE:ifining J,,1.,,G 501 E. Main Artesia, NM 88201 (5 75) 748-3311 cumulative quantity ofH2S and S02 released into the atmosphere. For releases controlled by flares. asslUne 99-percent conversion ofreduced sulfur or total sulfur to S02 For fuel gas combustion devices, assllllle 99-percent conversion ofH2S to S02. Affected Facility North Flare (FL-0400) ClUllulative Quantity ofH2S Released (pounds) 27 ClUllulative Quantity of S02 Released (pounds) 5,055 I 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact ofthe excess emissions on ambient air quality. The gas was safely combusted in a steam-assisted flare and scavenger was injected into the system. Maintenance worked quickly to determine what steps needed to be taken to reduce excess flaring. 60 .108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60. l 03a(d), including an identification ofthe affected facility, the date and duration ofthe discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60. l 03a(e). AffectedFacility(s): North Flare (FL-0400) Date ofDischarge: 11/08/2018 Duration ofDischarge: 24 hours ROOT CAUSE ANALYSIS Process imbalance in the NHU debutanizer system, which included a pressure increase in the splitter overhead system, and resulted in venting of overhead gases with high sulfur (S) content from the Splitter Distillate Drlllll (D-0044). TI1e associated flare emissions exceeded 500 pounds of sulfur dioxide (S02) on a 24-hour basis. CORRECTIVE ACTION ANALYSIS After the unit shutdown, the flat cap in X-0341 was tightened, thereby eliminating the leak. The Naphtha Hydrotreating Unit (NHU, Unit 13) started up and was returned to normal operation as expeditiously as possible. Additional corrective actions may be implemented pending the outcome ofthe above-described further root cause analysis for the Feed Preheater (X-0342), and an update will be submitted within thirty days after completion ofthe implementation of any such additional corrective actions. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description ofthe corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action The flat cap in X-03 41 . Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a plmmed startup or shutdo"11 of a refinery process unit or m1cillary equipment connected to the affected flare. a statement that a root cause analysis m1d corrective action analysis are not necessary because the oy,,ner or operator followed the flare management plan. Not applicable to this event. HFNA-000003254 EPA Inspection Report - Page 1705 of 1969 4 F: HOLLYFRONTIER #6-2018-12-27 NSPS JaRCA S02 FL-0400 Page 1 of2 ...............................................................................................................HollyFrontier Navajo RefiningLLC 501 E. Main Artesia, NM 88201 (575) 748-3311 DATE: December 27, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for S02 from Flares per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. Process imbalance in the NHU debutanizer system, which included a pressure increase in the splitter overhead system, and resulted in venting of overhead gases with high sulfur (S) content from the Splitter Distillate Drum (D-0044). The associated flare emissions exceeded 500 pounds of sulfur dioxide (S02) on a 24-hour basis. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 12/07/2018 22:00 Event Duration: 12/07/2018 22 :00 - 12/09/2018 09:00; 36 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) North Flare (FL-0400) 24-hour Period 12/07/2018 22:00 -12/07/2018 23:59 12/08/2018 00:00 - 12/08/2018 23 :59 12/09/2018 00:00 - 12/09/2018 09:59 Quantity of Gas Discharged over Event Duration (dscf) 83,470 884,020 352,770 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Date 12/07/2018 22:00 - 12/07/2018 23:59 12/08/2018 00:00 - 12/08/2018 23 :59 12/09/2018 00:00 - 12/09/2018 09:59 Number of hours 2 24 10 Hourly Average Measured Total Sulfur Concentration During Event (ppm) {60.108a(c)(6)(iv)} 36289 3,114 790 60.108a(c)(6)(v) For each discharge ,greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(l) from a fuel gas combustion device, either the measured concentration ofH2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4 ). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. HFNA-000003255 EPA Inspection Report - Page 1706 of 1969 #6-2018-12-27 NSPS JaRCA S02 FL-0400 Page 2 of2 .....................................................................................................................................................................................HollyFrontier ..Navajo...R e f i n i n g L L C 501 E. Main Artesia, NM 88201 (575) 748-3311 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Affected Facility North Flare (FL-0400) Cumulative Quantity ofH2S Released (pounds) 6.06 Cumulative Quantity of S02 Released (pounds) 1,130 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess e1nissions on ambient air quality. The gas was safely combusted in a steam-assisted flare and scavenger was injected into the system. Maintenance worked quickly to detennine what steps needed to be taken to reduce excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d), including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): North Flare (FL-0400) Date of Discharge: 12107/2018 Duration of Discharge: 36 hours ROOT CAUSE ANALYSIS Process imbalance in the NHU debutanizer system, which included a pressure increase in the splitter overhead system, and resulted in venting of overhead gases with high sulfur (S) content from the Splitter Distillate Drum (D-0044). The associated flare emissions exceeded 500 pounds of sulfur dioxide (S02) on a 24-hour basis. CORRECTIVE ACTION ANALYSIS The standard procedure for unit shutdown was followed. After the unit shutdown was completed, Feed Preheater (X0342) was by-passed for inspection and cleaning, as needed. After the exchanges was isolated and by-passed, the Naphtha Hydrotreating Unit (NHU, Unit 13) was started up and was returned to normal operation as expeditiously as possible. Additional corrective actions may be implemented pending the outcome of the above-described further root cause analysis for the Feed Preheater (X-0342), and an update will be submitted within thirty days after completion of the implementation of any such additional corrective actions. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed conunencement and completion dates. Corrective Action Repairs were made. Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003256 EPA Inspection Report - Page 1707 of 1969 H.OLLYF.RONTIER #7-2018-08-28 FL-0402 NSPS JaFlow RCA Pagel of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: August 29, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from the FCCU Flare (FL-0402) per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 07/21/2018, the Fluid Catalytic Cracking Unit (FCC, Unit 10) had a loss of compressor (C-0945) for the Lift Air Blower. This caused a shut-down of the FCC unit. Losing the compressor causes swing in the unit due to an air imbalance. Emergency steam kicks in to prevent plugging and causes back pressure in the Main Air Blower. Safeguards that are in place cause a shut-down of the unit automatically to prevent a more significant event. Instrument techs, electricians and maintenance were called out to check systems and found no known causes. A malfunction of the Bently Nevada Vibration Relay is believed to be the cause of the flaring event but further investigations are pending. At approximately 18:00 on 07/22/2018 FL-0402 began exceeding its baseline limit until approximately 17:00 on 07/23/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 07/22/2018 18:00 Event Duration: 07/22/2018 18:00 -07/23/2018 17:00; 24 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) FCCU Flare (FL-0402) Measured Quantity of Gas Discharged over Event Duration (dscf) 697,930 24-Hour Period 07/22/2018 18:00 - 07/22/2018 23:59 07/23/2018 00:00 - 07/23/2018 17:00 Quantity of Gas Discharged in 24-Hour Period (dsc:I) 526,320 171,610 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or botl1 the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(]) from a fuel gas combustion device, either the measured concentration of H2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of tl1e allowable li1nits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. HFNA-000003257 EPA Inspection Report - Page 1708 of 1969 #7-2018-08-28 FL-0402 NSPS Ja Flow RCAPa Page 2 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 Not applicable to this event. 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess emissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Repairs were made to C-0952 to minimize excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d), including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60. l03a(e). Affected Facility(s): FCCU Flare (FL-0402) Date of Discharge: 07/2212018 Duration of Discharge: 24 hours ROOT CAUSE ANALYSIS On 07/21/2018, the Fluid Catalytic Cracking Unit (FCC, Unit 10) had a loss of compressor (C-0945) compressor for the Lift Air Blower. This caused a shutdown of the FCC unit. Losing the compressor causes swing in the unit due to an air imbalance. Emergency steam kicks in to prevent plugging and causes back pressure in the Main Air Blower. Safeguards that are in place cause a shut-down of the unit automatically to prevent a more significant event. CORRECTIVE ACTION ANALYSIS The root cause analysis indicates that vibration of the C-0945 Lift Air Blower caused the Bently Nevada Vibration relay to lose electrical contact, which in tum caused the loss of the Lift Air Blower. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60. l03a(e), a description oftl1e corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action Electricians reset the tripped relay after the Lift Air Blower tripped. Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003258 EPA Inspection Report - Page 1709 of 1969 H.OLLYF.RONTIER #8-2018-09-05 FL-0402 NSPS JaFlow RCA Pagel of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: September 5, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from the FCCU Flare (FL-0402) per 60. l03a(c)(l) I 60.l08a(c)(6)(i) A description of the discharge. On 08/27/2018, the Fluid Catalytic Cracking Unit (FCC, Unit 10) began exceeding its baseline limit. This was due to scheduled maintenance for repairs of the Alky Flare (FL-0403). Charges were reduced to reduce excess flow flaring until the exceedance could be minimized. At approximately 03 :00 on 08/27/2018 FL-0402 began exceeding its baseline limit until approximately 00:00 on 09/03/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 08/27/2018 Event Duration: 08/27/2018 03 :00 - 09/03/2018 00:00; 166 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) FCCU Flare (FL-0402) Measured Quantity of Gas Discharged over Event Duration (dscf) 38,526,300 24-Hour Period 08/27/2018 03:00 - 08/27/2018 23:59 08/28/2018 00:00 - 08/28/2018 23:59 08/29/2018 00:00 - 08/29/2018 23:59 08/30/2018 00:00 - 08/30/2018 23:59 08/31/2018 00:00 - 08/31/2018 23:59 09/01/2018 00:00 - 09/01/2018 23:59 09/02/2018 00:00 - 09/02/2018 23:59 09/03/2018 00:00 - 09/03/2018 00:59 Quantity of Gas Discharged in 24-Hour Period (dsc:I) 6,109,150 5,526,610 6,529,930 6,520,590 6,528,810 6,275,250 1,025,760 10,200 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(]) from a fuel gas combustion device, either the measured concentration of H 2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4). Not applicable to this event. HFNA-000003259 EPA Inspection Report - Page 1710 of 1969 #8-2018-09-05 FL-0402 NSPS JaFlow RCA Page 2 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 60.108a(c)(6) (vi) For each discharge greater than 5001bs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. 60.108a(c)(6) (vii) For each discharge greater than 5001bs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess e1nissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d). including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): FCCU Flare (FL-0402) Date of Discharge: 08/27/2018 Duration of Discharge: 166 hours ROOT CAUSE ANALYSIS On 0812712018, the Fluid Catalytic Cracking Unit (FCC, Unit 10) began exceeding its baseline limit. This was due to scheduled 1naintenance for repairs of the Alky Flare (FL-0403). CORRECTIVE ACTION ANALYSIS Charges were reduced to drop excess flow flaring until the exceedance could be minimized. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60. l03a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed conunencement and completion dates. Corrective Action Reduced charges Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planued startup or shutdown of a refinery process unit or ancillary equipment conuected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003260 EPA Inspection Report - Page 1711 of 1969 H.OLLYF.RONTIER #9-2018-10-08 FL-0402 NSPS Ja Flow RCA Page 1 of2 HollyFrontier Navajo Refining LLC .P.O.Bex 1fill Artesia, NM 88211 (575) 365-8365 DATE: October 8, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfdfrom the FCCUFlare (FL-0402) per 60.l 03a(c)(l) I 60 .108a(c)(6)(i) Adescription of the discharge. On 09/05/2018, the Fluid Catalytic Cracking Unit (FCC, Unit l 0) Flare began exceeding its baseline threshhold. Tiris was due to the loss of a compressor (C-0945) for the Lift Air Blower. This caused a shutdo"'n of the FCC Unit. Losing C-0945 causes a rning in the Unit due to an air imbalance. Emergency stean1 kicked in to prevent plugging and caused back pressure in the Main Air Blower. Safeguards in place caused a shut-do"'n of the unit automatically to prevent a more significant event. Instrument technicians, electricians, and maintenance checked systems and found that C-0945 had unexpectedly tripped. At approximately 04:00 on 09/05/2018FL-0402 began exceeding its baseline threshhold tmtil approximately 04:00 on 09/06/2018. I 60 .108a(c)(6)(ii) The date and time the discharge was first identified and the duration ofthe discharge. Event Start Date& Time: 09/05/2018 Event Duration: 09/05/2018 04:00- 09/06/2018 04:00; 25 hours 60 .108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) FCCU Flare (FL-0402) Measured Quantity of Gas Discharged over Event Duration (dscf) 1,095,600 24-Hour Period 09/05/2018 04:00- 09/05/2018 23 :59 09/06/2018 00:00- 09/06/2018 04:59 Quantity of Gas Discharged in 24-Hour Period (dscf) 1,047,600 48,000 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hourperiod from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.I08a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60 l 02a(g)(l) from a fuel gas combustion de"ice, either the measured concentration ofH2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion de-vices, but cannot be used to make these estimates for flares, except as provided in 60.I07a(e)(4). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery pl ant, either the measured concentration ofreduced sulfur or S02 discharged to the atmosphere. HFNA-000003261 EPA Inspection Report - Page 1712 of 1969 Not applicable to this event. #9-2018-10-08 FL-0402 NSPS Ja Flow RCA Page 2 of2 HollyFrontier Navajo Refining LLC .P.O.Bex 1fill Artesia, NM 88211 (575) 365-8365 60 .108a(c)(6) (vii) For each discharge greater than 5OOlbs S02 in any 24-hour period from any affected flare or discharge greater than 5OOlbs S02 in excess ofthe allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity ofH2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion ofreduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Not applicable to this event. I 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact ofthe excess emissions on ambient air quality. The gas \\as safely combusted in a steam-assisted flare. Repairs were made to C-0952 to minimize excess flaring. 60 .108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.1 03a(d), including an identification ofthe affected facility, the date and duration ofthe discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation ofwhy corrective action is not necessary under 60.103a(e). AffectedFacility(s): FCCUFlare (FL-0402) Date of Discharge: 0910512018 DurationofDischarge: 25 hours ROOT CAUSE ANALYSIS On 09105/2018, the Fluid Catalytic Cracking Unit (FCC, Unit 10) Flare began exceeding its baseline limit. This was due to an unexpected trip ofC-0945. A nuisance trip ofthe GE Multilins 369 motor protection relay, a component of the C0945 Lift Air Blower (see below) caused the loss of the Lift Air Blower. The loss ofC-0945 Lift Air Blower caused a shutdown ofthe FCC Unit. CORRECTIVE ACTION ANALYSIS Electricians replaced the GE Multilins 369 motor protection relay. A Preventative Maintenance work order has been generated so this relay will be inspected annually. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description ofthe corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action Electricians replaced the GE Multilins 369 motor protection relay. A Preventative Maintenance work order has been generated so this relay will be inspected annually. Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60. l 08a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003262 EPA Inspection Report - Page 1713 of 1969 H.OLLYF.RONTIER #10-2018-10-25 FL-0402 NSPS JaBaseline Flow RCA Pagel of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: October 25, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from the FCC Flare (FL-0402) baseline per 60.103a(c)(l) I 60.108a(c)(6)(i) A descriptionofthe discharge. On 09/25/2018, the FCC Flare (FL-0402) began exceeding its baseline threshold. This was due to a power outage that affected Units 33 (Diesel Hydrotreater), 44 (Distillate Hydrodesulfurization), 45 (GOH), 70 (CCR), 10 (FCC), and the North Plant. The affected units ended up causing excess flaring to the FCC Flare. The outage lasted approximately 2-3 hours. At approximately 14:00 on 09/25/2018 FL-0402 began exceeding its alternative baseline threshold until approximately 12 :00 on 09/26/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 09/25/2018 14 :00 Event Duration: 09/25/2018 14:00 - 09/26/2018 12:00; 23 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) FCC Flare (FL-0402) Measured Quantity of Gas Discharged over Event Duration (dscf) 642,000 24-Hour Period 09/25/2018 13:00 - 09/25/2018 23:59 09/26/2018 00:00 - 09/26/2018 12:59 Quantity of Gas Discharged in 24-Hour Period (dscf) 496,340 145,660 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(]) from a fuel gas combustion device, either the measured concentration of H2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable li1nits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. HFNA-000003263 EPA Inspection Report - Page 1714 of 1969 #10-2018-10-25 FL-0402 NSPS JaBaseline Flow RCA Page 2 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps that the owner or operator took to linlit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess emissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Unit feed rates were reduced to mini1nize excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d), including an identification of the affected facility, the date and duration of the discharge. a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60. l03a(e). Affected Facility(s): FCC Flare (FL-0402) Date of Discharge: 09/25/2018 Duration of Discharge: 23 hours ROOT CAUSE ANALYSIS A power outage led to an excess of flaring. CORRECTIVE ACTION ANALYSIS Power was restored for the Plant. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation. including proposed commencement and completion dates. Corrective Action Power was restored for the plant Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003264 EPA Inspection Report - Page 1715 of 1969 4 F: HOLLYFRONTIER #11-2018-08-28 FL-402 NSPS Ja RCA S02 Pagel of3 ...............................................................................................................HollyFrontier Navajo RefiningLLC 501 E. Main Artesia, NM 88201 (575) 748-3311 DATE: June 18, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for S02 from Flares per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 07/21/2018, the Fluid Catalytic Cracking Unit (FCC, Unit 10) had a loss of compressor (C-0945) compressor for the Lift Air Blower. This caused a shutdown of the FCC unit. Losing the compressor causes swing in the unit due to an air imbalance. Emergency steam kicked in to prevent plugging and causes back pressure in the Main Air Blower. Safeguards in place caused a shut-down of the unit aut01uatically to prevent a more significant event. Instrument techs, electricians and maintenance were called out to check systems and found no known causes. A malfunction of the Bently Nevada Vibration Relay is believed to be the cause of the flaring event but further investigations are pending. At approximately 03 :00 on 07/22/2018 FL-0402 began exceeding its baseline limit until approximately 18:00 on 07/23/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 07/22/2018 03 :00 Event Duration: 07/22/2018 03 :00 - 07/23/2018 18:00; 40 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) FCC Flare FL-0402 24-hour Period 07/22/2018 03:00 - 07/22/2018 23:59 07/23/2018 00:00 - 07/23/2018 18:00 Quantity of Gas Discharged over Event Duration (dscf) 997,220 181,090 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Date 07/22/2018 03:00 - 07/22/2018 23:59 07/23/2018 00:00 - 07/23/2018 18:00 Number of hours 21 19 Hourly Average Measured Total Sulfur Concentration During Event (ppm) {60.108a(c)(6)(iv)} 23,387.80 194.92 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(1) from a fuel gas combustion device, either the measured concentration of H2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)(4). Not applicable to this event. HFNA-000003265 EPA Inspection Report - Page 1716 of 1969 #11-2018-08-28 FL-402 NSPS Ja RCA S02 Page 2 of3 .....................................................................................................................................................................................HollyFrontier ..Navajo...R e f i n i n g L L C 501 E. Main Artesia, NM 88201 (575) 748-3311 60.108a(c)(6) (vi) For each discharge greater than 5001bs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. 60.108a(c)(6) (vii) For each discharge greater than 5001bs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant. the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H 2S to S02. Affected Facility FCC (FL-0402) Cumulative Quantity ofH2S Released (pounds) 16.50 Cumulative Quantity of S02 Released (pounds) 3,074.95 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess emissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Maintenance worked quickly to determine what steps needed to be taken to reduce excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d), including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): FCC Flare (FL-0402) Date of Discharge: 07/2212018 - 07/23/2018 Duration of Discharge: 40 hours ROOT CAUSE ANALYSIS On 07/21/2018, the Fluid Catalytic Cracking Unit (FCC, Unit 10) had a loss of compressor (C-0945) compressor for the Lift Air Blower. This caused a shutdown of the FCC unit. Losing the compressor causes swing in the unit due to an air imbalance. Emergency steam kicks in to prevent plugging and causes back pressure in the Main Air Blower. Safeguards that are in place cause a shut-down of the unit automatically to prevent a more significant event. CORRECTIVE ACTION ANALYSIS Weekly monitoring data indicated a change in the vibration noise of the C-0949 gearbox. Based on our inspection, the gear teeth were damaged due to unknown causes. Our review shows that the gear box has nm for approximately 20 years and had a preventative maintenance schedule for inspection during every tum-around. The last complete inspection was done 02/2017 during our last major tum-around. The oil filters were change the week of 05107/2018. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed conunencement and completion dates. Corrective Action Repairs to C-0949 gear box Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA HFNA-000003266 EPA Inspection Report - Page 1717 of 1969 #11-2018-08-28 FL-402 NSPS Ja RCA S02 Page 3 of3 .....................................................................................................................................................................................HollyFrontier ..Navajo...R e f i n i n g L L C 501 E. Main Artesia, NM 88201 (575) 748-3311 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003267 EPA Inspection Report - Page 1718 of 1969 4 F: HOLLYFRONTIER #12-2018-09-04 NSPS JaRCA S02 FL-0402 Page 1 of3 ...............................................................................................................HollyFrontier Navajo RefiningLLC 501 E. Main Artesia, NM 88201 (575) 748-3311 DATE: September 4, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for S02 from Flares per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 08/27/2018, the Fluid Catalytic Cracking Unit (FCC, Unit 10) began exceeding its S02 limit. This was due to scheduled maintenance for repairs of the Alky Flare (FL-0403). Charges were reduced to reduce S02 flaring until the exceedance could be minimized. At approximately 09:00 on 08/27/2018 FL-0402 began exceeding its S02 limit until approximately 09:00 on 08/31/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 08/27/2018 09:00 Event Duration: 08/27/2018 09:00 - 08/31/2018 09:00; 97 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) FCC Flare FL-0402 24-hour Period 08/27/2018 09:00 - 08/27/2018 23:59 08/28/2018 00:00 - 08/28/2018 23:59 08/29/2018 00:00 - 08/29/2018 23:59 08/30/2018 00:00 - 08/30/2018 23:59 08/31/2018 00:00 - 08/31/2018 09:59 Quantity of Gas Discharged over Event Duration (dscf) 4,703,060 5,526,610 6,529,930 6,520,590 2,723,710 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Date 08/27/2018 09:00 - 08/27/2018 23:59 08/28/2018 00:00 - 08/28/2018 23:59 08/29/2018 00:00 - 08/29/2018 23:59 08/30/2018 00:00 - 08/30/2018 23:59 08/31/2018 00:00 - 08/31/2018 09:59 Number of hours 15 24 24 24 10 Hourly Average Measured Total Sulfur Concentration During Event (ppm) {60.108a(c)(6)(iv)} 1,387 1,193 2,382 1,419 227 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(]) from a fuel gas combustion device, either the measured concentration of H 2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4). HFNA-000003268 EPA Inspection Report - Page 1719 of 1969 #12-2018-09-04 NSPS JaRCA S02 FL-0402 Page 2 of3 .....................................................................................................................................................................................HollyFrontier ..Navajo...R e f i n i n g L L C 501 E. Main Artesia, NM 88201 (575) 748-3311 Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Affected Facility FCC (FL-0402) Cumulative Quantity ofH2S Released (pounds) 34.0 Cumulative Quantity of S02 Released (pounds) 6,346.5 I 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess emissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Maintenance worked quickly to determine what steps needed to be taken to reduce excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d). including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): FCC Flare (FL-0402) Date of Discharge: 08/27/2018 Duration of Discharge: 97 hours ROOT CAUSE ANALYSIS On 0812712018, the Fluid Catalytic Cracking Unit (FCC, Unit 10) began exceeding its S02 limit. This was due to scheduled maintenance for repairs of the Alky Flare (FL-0403). CORRECTIVE ACTION ANALYSIS Charges were reduced to drop S02 flaring until the exceedance could be minimized. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60. l03a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed conunencement and completion dates. Corrective Action Charges were reduced Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA HFNA-000003269 EPA Inspection Report - Page 1720 of 1969 #12-2018-09-04 NSPS JaRCA S02 FL-0402 Page 3 of3 .....................................................................................................................................................................................HollyFrontier ..Navajo...R e f i n i n g L L C 501 E. Main Artesia, NM 88201 (575) 748-3311 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003270 EPA Inspection Report - Page 1721 of 1969 4 F: HOLLYFRONTIER #13-2018-10-08 NSPS Ja RCA S02 FL-0402 Page 1 of3 H<::>IIYfr9nJiE:lL Nc:1vc:1j9 RE:ifining J,,1.,,G 501 E. Main Artesia, NM 88201 (5 75) 748-3311 DATE: October 8, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for S02 from Flares per 60.103a(c)(]) I 60 .108a(c)(6)(i) Adescription ofthe discharge. On 09/04/2018, the Fluid Catalytic Cracking Unit (FCC, Unit 10) began exceeding its S02 limit. This was due to the loss of a compressor (C-0945) for the Lift Air Blower. This caused a shutdown ofthe FCC Unit. Losing C-0945 caused a swing in the Unit due to an air imbalance. Emergency steam kicked in to prevent plugging and caused back pressure in the Main Air Blower. Safeguards in place caused a shut-do~n of the unit automatically to prevent a more significant event. Instrument technicians, electricians, and maintenance checked systems and found that C-0945 had unexpectedly tripped. At approximately 16:00 on 09/04/2018FL-0402 began exceeding its S02 limit until approximately 05:00 on 09/06/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 09/04/2018 16:00 Event Duration: 09/04/201816:00-09/06/2018 05:00; 38 hours 60 .108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) FCC Flare FL-0402 24-hour Period 09/04/201816:00- 09/04/2018 23:59 09/05/2018 00:00- 09/05/20! 8 23:59 09/06/2018 00:00- 09/06/20!8 05:59 Quantity of Gas Discharged over Event Duration(dscf) 173,250 1,110,860 58,850 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Date 09/04/2018 16:00- 09/04/2018 23:59 09/05/2018 00:00- 09/05/2018 23:59 09/06/2018 00:00- 09/06/2018 05:59 Number of hours 8 24 6 Hourly Average Measured Total Sulfur Concentration During Event (ppm) {60.108a(c)(6)(iv)} 28,909 5,372 776 60 .108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60 l 02a(g)(l) from a fuel gas combustion de"ice, either the measured concentration ofH2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)(4). Not applicable to this event. HFNA-000003271 EPA Inspection Report - Page 1722 of 1969 #13-2018-10-08 NSPS Ja RCA S02 FL-0402 Page 2 of3 H<::>IIYfr9nJiE:lL Nc:1vc:1j9 RE:ifining J,,1.,,G 501 E. Main Artesia, NM 88201 (5 75) 748-3311 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery pl ant, either the measured concentration ofreduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. 60 .108a(c)(6) (vii) For each discharge greater than 5OOlbs S02 in any 24-hour period from any affected flare or discharge greater than 5OOlbs S02 in excess ofthe allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity ofH2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion ofreduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Affected Facility FCC (FL-0402) Cmnulative Quantity ofH2S Released (potmds) 12.5 Cumulative Quantity of S02 Released (pounds) 2,337 I 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact ofthe excess emissions on ambient air quality. The gas \\as safely combusted in a steam-assisted flare and scavenger was injected into the system. Maintenance worked quickly to determine what steps needed to be taken to reduce excess flaring. 60 .108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.1 03a(d), including an identification of the affected facility, the date and duration ofthe discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation ofwhy corrective action is not necessary under 60.103a(e). AffectedFacility(s): FCC Flare (FL-0402) Date of Discharge: 0910412018 DurationofDischarge: 38 hours ROOT CAUSE ANALYSIS On 09104/2018, the Fluid Catalytic Cracking Unit (FCC, Unit 10) began exceeding its S02 limit. This \\as due to the loss of a compressor (C-0945) for the Lift Air Blower. A root cause analysis \\as conducted which determined that the probable cause ofthe loss of the blower was a nuisance trip of the GE Multilins 369 motor protection relay, a component of the C-0945 Lift Air Blower that \\as in use beyond its recommended life. The root cause ofthe trip is mechanical fatigue. CORRECTIVE ACTION ANALYSIS Electricians replaced the GE Multilins 369 motor protection relay. A Preventative Maintenance work order has been generated so this relay will be inspected annually. 60. l 08a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60. l03a(e). a description ofthe corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action C-0945 \\as restarted Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA HFNA-000003272 EPA Inspection Report - Page 1723 of 1969 #13-2018-10-08 NSPS Ja RCA S02 FL-0402 Page 3 of3 Hollyfrnnti~r N~v~jq R~fining lJ,C 501 E. Main Artesia, NM 88201 (5 75) 748-3311 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003273 EPA Inspection Report - Page 1724 of 1969 4 F: HOLLYFRONTIER #14-2018-10-25 NSPS JaRCA S02 FL-0402 Page 1 of2 ...............................................................................................................HollyFrontier Navajo RefiningLLC 501 E. Main Artesia, NM 88201 (575) 748-3311 DATE: October 25, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for S02 from Flares per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 09/24/2018, the FCC Flare (FL-0402) began exceeding its S02 threshold. This was due to a power outage that affected Units 33 (Diesel Hydrotreater), 44 (Distillate Hydrodesulfurization), 45 (GOH), 70 (CCR), 10 (FCC), and the North Plant. The flaring associated with the units's shutdown and subsequent startup resulted in emissions from the FCC Flare (FL-0402) to exceed 500 lbs S02 in a 24-hour period. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 09/25/2018 14:00 Event Duration: 09/25/2018 14:00 - 09/26/2018 14:00; 25 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) FCC Flare FL-0402 24-hour Period 09/25/2018 14:00 - 09/26/2018 14:59 Quantity of Gas Discharged over Event Duration (dscf) 664,520 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Date 09/25/2018 14:00 - 09/25/2018 23:59 09/26/2018 00:00 - 09/26/2018 14:59 Number of hours 10 15 Hourly Average Measured Total Sulfur Concentration During Event (ppm) {60.108a(c)(6)(iv)} 75,105 3,014 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(l) from a fuel gas combustion device, either the measured concentration ofH2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)(4). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. HFNA-00000327 4 EPA Inspection Report - Page 1725 of 1969 #14-2018-10-25 NSPS JaRCA S02 FL-0402 Page 2 of2 .....................................................................................................................................................................................HollyFrontier ..Navajo...R e f i n i n g L L C 501 E. Main Artesia, NM 88201 (575) 748-3311 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant. the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Affected Facility FCC Flare (FL-0402) Cumulative Quantity ofH2S Released (pounds) 7.0 Cumulative Quantity of S02 Released (pounds) 1,297 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess emissions on ambient air quality. The gas was safely combusted in a steam-assisted flare and scavenger was injected into the system. Maintenance worked quickly to determine what steps needed to be taken to reduce excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d), including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): FCC Flare (FL-0402) Date of Discharge: 09/25/2018 DurationofDischarge: 25 hours ROOT CAUSE ANALYSIS An unexpected power outage affected Units 33 (Diesel Hydrotreater), 44 (Distillate Hydrodesulfurization), 45 (GOH), 70 (CCR), 10 (FCC), and the North Plant. The affected units ended up causing excess S02 flaring to the FCC Flare. The outage lasted approximately 2-3 hours. CORRECTIVE ACTION ANALYSIS The electrical supply was promptly shifted to four additional substations that provide the electrical power to other sections of the refinery, allowing the electrical power to be restored. The frequency of preventative maintenance activities performed by the third-party electrical substation was increased fonn semiannual to monthly basis. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed connnencement and completion dates. Corrective Action Power was restored and units restarted. Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003275 EPA Inspection Report - Page 1726 of 1969 H.OLLYF.RONTIER #15-2018-08-28 FL-0403 NSPS JaFlow RCA Page 1 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: August 28, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from the Alky Flare (FL-0403) per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 08/22/2018, the Alky Flare (FL-0403) began exceeding its baseline threshold by >500,000 scfd while flaring. The excess flaring was caused by the Propane Treater (D-0629) being depressurized to the flare for scheduled maintenance. D-629 requires replacement of media so that the propane can be neutralized prior to being sent to storage. Flaring continued until D-629 reached no pressure and maintenance could work on the vessel. At approximately 11 :00 on 08/22/2018 FL-0403 began exceeding its baseline threshold until approximately 22 :00 on 08/22/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 08/11/2018 11:00 Event Duration: 08/11/2018 11:00 -08/11/2018 23:00; 13 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) Alky Flare (FL-0403) Measured Quantity of Gas Discharged over Event Duration (dscf) 270,230 24-Hour Period 08/11/2018 11:00 -08/11/2018 22:59 Quantity of Gas Discharged in 24-Hour Period (dscf) 270,230 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(]) from a fuel gas combustion device, either the measured concentration of H2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. HFNA-000003276 EPA Inspection Report - Page 1727 of 1969 #15-2018-08-28 FL-0403 NSPS JaFlow RCA Page 2 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess emissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Unit feed rates were reduced to mini1nize excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d), including an identification of the affected facility, the date and duration of the discharge. a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60. l03a(e). Affected Facility(s): Alky Flare (FL-0403) Date of Discharge: 08/11/2018 Duration of Discharge: 12 hours ROOT CAUSE ANALYSIS Scheduled maintenance on the propane treater (D-0629) resulted in excess flaring during depressurization of the vessel. CORRECTIVE ACTION ANALYSIS Maintenance finished depressurization of the vessel and excess flaring was reduced. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60. l03a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action Depressurization finished Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003277 EPA Inspection Report - Page 1728 of 1969 H.OLLYF.RONTIER #16-2018-10-05 FL-0403 NSPS JaFlow RCA Page 1 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: October 5, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from the Alky Flare (FL-0403) per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 09/18/2018, the Alky Flare (FL-0403) began exceeding its baseline threshold by >500,000 scfd while flaring. The excess flaring was caused by non-condensables from the depropanizer (W-0079) being vented to the flare. Flaring continued until W-79 no longer had condensables in the system. At approximately 18:00 on 09/18/2018 FL-0403 began exceeding its baseline threshold until approximately 00:00 on 09/21/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 09/18/2018 18:00 Event Duration: 09/18/2018 18:00 - 09/21/2018 00:00; 55 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) Alky Flare (FL-0403) Measured Quantity of Gas Discharged over Event Duration (dscf) 1,383,800 24-Hour Period 09/18/2018 18:00 - 09/18/2018 23:59 09/19/2018 00:00 - 09/19/2018 23:59 09/20/2018 00:00 - 09/20/2018 23:59 09/21/2018 00:00 - 09/21/2018 00:59 Quantity of Gas Discharged in 24-Hour Period (dscf) 177,090 594,430 589,590 22,690 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(]) from a fuel gas combustion device, either the measured concentration of H 2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. HFNA-000003278 EPA Inspection Report - Page 1729 of 1969 #16-2018-10-05 FL-0403 NSPS JaFlow RCA Page 2 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 Not applicable to this event. 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps thatthe owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess emissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Unit feed rates were reduced to mini1nize excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d), including an identification of the affected facility, the date and duration of the discharge. a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60. l03a(e). Affected Facility(s): Alky Flare (FL-0403) Date of Discharge: 09/18/2018 DurationofDischarge: 55 hours ROOT CAUSE ANALYSIS W-79 began venting non-condensables to FL-0403. CORRECTIVE ACTION ANALYSIS W-79 completed venting non-condensables and flaring was minimized. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60. l03a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and. for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action W-79 completed venting non-condensables and flaring stopped. Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003279 EPA Inspection Report - Page 1730 of 1969 H.OLLYF.RONTIER #17-2018-08-25 FL-0404 NSPS Ja Alt Baseline Flow RCA Pagel of2 ........................................................................................................HollyFrontier ..N a v a i o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: August 25, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from GOHT Flare (FL-0404) alternative baseline per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. Hydrogen venting to the GOH Flare (FL-0404) during startup of the Hydrogen Plant No.l (Unit 63 ), and increased rate in the CCR contributed to the increase of hydrogen flow directed to the flare. At approximately 16:00 on 07/19/2018 FL-0404 began exceeding its alternative baseline threshold until approximately 02 :00 on 07/20/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 07/19/2018 16:00 Event Duration: 07/19/2018 16:00 -07/20/2018 02:00; 10 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) GOH Flare (FL-0404) Alternative Baseline Measured Quantity of Gas Discharged over Event Duration (dscf) 3,840,640 24-Hour Period 07/19/2018 16:00 - 07/20/2018 02:00 Quantity of Gas Discharged in 24-Hour Period (dsc:I) 3,840,640 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60 I02a(g)(I) from a fuel gas combustion device, either the measured concentration of H2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4 ). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. HFNA-000003280 EPA Inspection Report - Page 1731 of 1969 #17-2018-08-25 FL-0404 NSPS Ja Alt Baseline Flow RCA Page 2 of2 ........................................................................................................HollyFrontier ..N a v a i o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess emissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Unit feed rates were reduced to mini1nize excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d), including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60. l03a(e). Affected Facility(s): GOH Flare (FL-0404) Date of Discharge: 07/19/2018 DurationofDischarge: 10 hours ROOT CAUSE ANALYSIS Hydrogen venting to the GOH Flare (FL-0404) during startup of the Hydrogen Plant No.l (Unit 63), and increased rate in the CCR contribute to the increase of hydrogen flow directed to the flare. CORRECTIVE ACTION ANALYSIS The startup of Unit 63 was completed and the production rate in the hydrogen Plant No.2 (Unit 64) was dialed back to minimum rate, reducing the hydrogen flow vented to the flare. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action Unit 63 startup was completed. Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003281 EPA Inspection Report - Page 1732 of 1969 H.OLLYF.RONTIER #18-2018-10-25 FL-0404 NSPS Ja Alt Baseline Flow RCA Page 1 of2 ........................................................................................................HollyFrontier ..N a v a i o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: October 25, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from GOHT Flare (FL-0404) alternative baseline per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 07/23/2018, the GOH Flare (FL-0404) began exceeding its alternative baseline threshold. This was due to Unit 70, the Continuous Catalytic Reformer (CCR) being nm at full rates and Unit 33, the Diesel Hydrotreater (DHT) nmning at reduced rates. The CCR produces additional hydrogen that, under nonnal operating conditions, the DHT is able to use. Due to the reduced rates the excess hydrogen was flared. At approximately 02 :00 on 07/23/2018 FL-0404 began exceeding its alternative baseline threshold until approximately 19:00 on07/23/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 07/23/2018 02 :00 Event Duration: 07/23/2018 02:00 -07/23/2018 19:00; 18 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) GOH Flare (FL-0404) Alternative Baseline Measured Quantity of Gas Discharged over Event Duration (dscf) 5,888,970 24-Hour Period 07/23/2018 02:00 - 07/23/2018 19:59 Quantity of Gas Discharged in 24-Hour Period (dsc:I) 5,888,970 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(]) from a fuel gas combustion device, either the measured concentration of H 2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. HFNA-000003282 EPA Inspection Report - Page 1733 of 1969 #18-2018-10-25 FL-0404 NSPS Ja Alt Baseline Flow RCA Page 2 of2 ........................................................................................................HollyFrontier ..N a v a i o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess emissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Unit feed rates were reduced to mini1nize excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d), including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60. l03a(e). Affected Facility(s): GOH Flare (FL-0404) Date of Discharge: 07/23/2018 DurationofDischarge: 18 hours ROOT CAUSE ANALYSIS Unit 70 was mnning at full capacity and Unit 33 was mmring at reduced rates. Excess hydrogen from Unit 70 wasn't able to be used in Unit 33 due to the reduced rates and had to be directed to the flare. CORRECTIVE ACTION ANALYSIS Unit 33 was able to process more hydrogen. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action Unit 33 was able to process more hydrogen. Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003283 EPA Inspection Report - Page 1734 of 1969 H.OLLYF.RONTIER #19-2018-10-25 FL-0404 NSPS Ja Alt Baseline Flow RCA Page 1 of2 ........................................................................................................HollyFrontier ..N a v a i o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: October 25, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from GOHT Flare (FL-0404) alternative baseline per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 07/23/2018, the GOH Flare (FL-0404) began exceeding its alternative baseline threshold. This was due to Unit 9, the Alkylation Unit being down for repairs. Because Unit 9 was down and there were decreased rates throughout the facility excess hydrogen was sent to the GOH Flare. At approximately 18:00 on 08/27/2018 FL-0404 began exceeding its alternative baseline threshold until approximately 05 :00 on 08/30/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 08/27/2018 18:00 Event Duration: 08/27/2018 18:00 - 08/30/2018 05 :00; 60 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) GOH Flare (FL-0404) Alternative Baseline Measured Quantity of Gas Discharged over Event Duration (dscf) 23,764,370 24-Hour Period 08/27/2018 18:00 - 08/27/2018 23:59 08/28/2018 00:00 - 08/28/2018 23:59 08/29/2018 00:00 - 08/29/2018 23:59 08/30/2018 00:00 - 08/30/2018 05:59 Quantity of Gas Discharged in 24-Hour Period (dsc:I) 2,493,880 9,740,000 9,445,270 2,085,220 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(]) from a fuel gas combustion device, either the measured concentration of H2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. HFNA-000003284 EPA Inspection Report - Page 1735 of 1969 #19-2018-10-25 FL-0404 NSPS Ja Alt Baseline Flow RCA Page 2 of2 ........................................................................................................HollyFrontier ..N a v a i o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess e1nissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Unit feed rates were reduced to mini1nize excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d). including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): GOH Flare (FL-0404) Date of Discharge: 08/27/2018 DurationofDischarge: 60 hours ROOT CAUSE ANALYSIS The GOH Flare exceeded its alternative baseline threshold due to Unit 9 being down for repairs. This led to excess hydrogen being routed to the GOH Flare. CORRECTIVE ACTION ANALYSIS Unit 9 repairs were finished and the unit was brought back online. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60. l03a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action Unit 9 was brought back into service. Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003285 EPA Inspection Report - Page 1736 of 1969 H.OLLYF.RONTIER #20-2018-10-16 FL-0404 NSPS Ja Alt Baseline Flow RCA Page 1 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: October 16, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from GOHT Flare (FL-0404) alternative baseline per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 09/23/2018, the GOH Flare (FL-0404) began exceeding its alternative baseline threshhold. This was due to a power outage that affected Units 33 (Diesel Hydrotreater), 44 (Distillate Hydrodesulfurization), 45 (GOH), 70 (CCR), 10 (FCC), and the North Plant. The affected units ended up causing excess flaring to the GOH Flare. The outage lasted approximately 2-3 hours. While this was occurring, Unit 34 (Mild Hydrocracker) was shut down for a scheduled catalyst change. Unit 34 uses hydrogen in its process and when the unit is down Units 63 and 64 (Hydrogen Plants 1 and 2) are able to reduce their rates but not fully shut off for safety concerns. Because of this excess hydrogen was flared to FL0404 leading to an exceedance of FL-0404 's alternative baseline. Due to the nature of a catalyst change in Unit 34 the duration of the startup event and the quantity of excess hydrogen flared was ,greater than a typical startup event. At approximately 20:00 on 09/23/2018 FL-0404 began exceeding its alternative baseline threshhold until approximately 02:00 01109/25/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 09/23/2018 20 :00 Event Duration: 09/23/2018 20:00 -09/25/2018 02:00; 31 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) GOH Flare (FL-0404) Alternative Baseline Measured Quantity of Gas Discharged over Event Duration (dscf) 13,448,870 24-Hour Period 09/23/2018 20:00 - 09/23/2018 23:59 09/24/2018 00:00 - 09/24/3018 23:59 09/25/2018 00:00 - 09/25/2018 02:59 Quantity of Gas Discharged in 24-Hour Period (dscf) 2,385,850 9,937,950 1,125,070 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60 I02a(g)(I) from a fuel gas combustion device, either the measured concentration of H2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4). Not applicable to this event. HFNA-000003286 EPA Inspection Report - Page 1737 of 1969 #20-2018-10-16 FL-0404 NSPS Ja Alt Baseline Flow RCA Page 2 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H 2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess e1nissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Unit feed rates were reduced to mini1nize excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d), including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): GOH Flare (FL-0404) Date of Discharge: 09125/2018 DurationofDischarge: 31 hours ROOT CAUSE ANALYSIS A power outage along with a planned shutdown of Unit 34 led to an excess of flaring. CORRECTIVE ACTION ANALYSIS Power was restored for the Plant. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action Power was restored for the plant Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003287 EPA Inspection Report - Page 1738 of 1969 H.OLLYF.RONTIER #21-2018-10-17 FL-0404 NSPS Ja Alt Baseline Flow RCA Page 1 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: October 17, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from GOHT Flare (FL-0404) alternative baseline per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 09/28/2018, the GOH Flare (FL-0404) began exceeding its alternative baseline threshold. This was due to Unit 34 being brought back in line following the planned catalyst change. Unit 34 uses hydrogen in its process and when the unit is down Units 63 and 64 (Hydrogen Plants l and 2) are able to reduce their rates but not fully shut off for safety concerns. Because of this excess hydrogen was flared to FL-0404 leading to an exceedance of FL-0404 's alternative baseline. Due to the nature of a catalyst change in Unit 34 the duration of the startup event and the quantity of excess hydrogen flared was greater than a typical startup event. At approximately 15 :00 on 09/28/2018 FL-0404 began exceeding its alternative baseline threshold until approximately 05:00 01109/29/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 09/28/2018 15 :00 Event Duration: 09/28/2018 15:00 -09/29/2018 05:00; 15 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) GOH Flare (FL-0404) Alternative Baseline Measured Quantity of Gas Discharged over Event Duration (dscf) 5,107,160 24-Hour Period 09/28/2018 15:00 - 09/28/2018 23:59 09/29/2018 00:00 - 09/29/2018 05:59 Quantity of Gas Discharged in 24-Hour Period (dscf) 3,581,570 1,525,590 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60 I02a(g)(I) from a fuel gas combustion device, either the measured concentration of H 2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. HFNA-000003288 EPA Inspection Report - Page 1739 of 1969 Not applicable to this event. #21-2018-10-17 FL-0404 NSPS Ja Alt Baseline Flow RCA Page 2 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H 2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess emissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Unit feed rates were reduced to mini1nize excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d), including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60. l03a(e). Affected Facility(s): GOH Flare (FL-0404) Date of Discharge: 09128/2018 DurationofDischarge: 15 hours ROOT CAUSE ANALYSIS The startup of Unit 34 led to an excess of flaring. CORRECTIVE ACTION ANALYSIS Startup continued as planned and flaring was minimized as Unit 34 was brought back online. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action Unit 34 was brought back online. Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003289 EPA Inspection Report - Page 1740 of 1969 4 F: HOLLYFRONTIER #22-2018-10-25 NSPS JaRCA S02 FL-0404 Page 1 of3 ...............................................................................................................HollyFrontier Navajo RefiningLLC 501 E. Main Artesia, NM 88201 (575) 748-3311 DATE: October 28, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for S02 from Flares per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 09/28/2018, the GOH Flare (FL-0404) began exceeding its S02 threshold. At approximately 03:00 on 09/28/2018, operations began a planned startup of the Mild Hydrocracker Unit (Unit 34) following a planned shutdown to replace the catalyst in the Guard Bed Reactor (D-3401). Due to low temperature and no steam in the Stripper (W-3401) all pressure built up in the Fractionator (W-3402) has nowhere to go except to be vented to the GOHT Flare (FL-0404). At approximately 10:00 on 09/28/2018, operations fired the Reactor Charge Heater (H-3403) to begin heating up the process to nonnal operating temperature. Once H-3403 is running, it heats the temperature through the Reactors (D3400/01/02), the Hot Oil Separator (D-3404), the Stripper (W-3401), and the Fractionator (W-3402). At approximately 20:42 on 09/28/2018, the temperature in W-340 l was hot enough for steam to remain in vapor state and operations began adding stripping steam to W-340 l. When stripping steam is added, the steam pushes the diesel light ends (naphtha) to the Stripper Overhead Accumulator (D-3411) and operations can send the process downstream to North Division units instead of flaring. Othenvise, the process is pushed to W-3402 and flaring begins. The flaring is caused by low temperature and no steam in (W-340 l ). Until temperature is hot enough for stripping steam to be added, all built up pressure in (W-3402) is vented to FL-0404. At approximately 23 :00 on 09/28/2018 FL-0404 began exceeding its S02 threshold until approximately 22 :00 on 09/29/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 09/28/2018 23 :00 Event Duration: 09/28/2018 23:00 - 09/29/2018 22:00; 24 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) GOH Flare FL-0404 24-hour Period 09/28/2018 23:00 - 09/29/2019 22:59 Quantity of Gas Discharged over Event Duration (dscf) 4,827,960 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Date 09/28/2018 23:00 - 09/28/2018 23:59 09/29/2018 00:00 - 09/29/2018 22:59 Number of hours l 23 Hourly Average Measured Total Sulfur Concentration During Event (ppm) {60.108a(c)(6)(iv)} 4,130 437 HFNA-000003290 EPA Inspection Report - Page 1741 of 1969 #22-2018-10-25 NSPS JaRCA S02 FL-0404 Page 2 of3 .....................................................................................................................................................................................HollyFrontier ..Navajo...R e f i n i n g L L C 501 E. Main Artesia, NM 88201 (575) 748-3311 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-tenn emissions limit in 60102a(g)(l) from a fuel gas combustion device, either the measured concentration ofH2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares. except as provided in 60.107a(e)(4). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Affected Facility GORT Flare (FL-0404) Cumulative Quantity ofH2S Released (pounds) 3.1 Cumulative Quantity of S02 Released (pounds) 572 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess emissions on ambient air quality. The gas was safely combusted in a steam-assisted flare and scavenger was injected into the system. Maintenance worked quickly to detennine what steps needed to be taken to reduce excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d). including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): GOH Flare (FL-0404) Date of Discharge: 09/28/2018 Duration of Discharge: 24 hours ROOT CAUSE ANALYSIS The flaring is caused by low temperature and no steam in (W-3401). Until temperature is hot enough for stripping steam to be added, all built up pressure in (W-3402) is vented to FL-0404. CORRECTIVE ACTION ANALYSIS No corrective actions are planned. Operations continues to investigate alternatives to startup procedures for the purpose of identifying potential methods to reduce or eliminate the need to flare during unit startup. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action Actions Completed within 45 days Proposed Start Date Completion Date HFNA-000003291 EPA Inspection Report - Page 1742 of 1969 #22-2018-10-25 NSPS JaRCA S02 FL-0404 Page 3 of3 .....................................................................................................................................................................................HollyFrontier ..Navajo...R e f i n i n g L L C I Temperature was hot enough for W-3401 I Yes IN/A IN/A 501 E. Main Artesia, NM 88201 (575) 748-3311 I 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003292 EPA Inspection Report - Page 1743 of 1969 H.OLLYF.RONTIER #23-2018-11-06 FL-0404 NSPS Ja Alt Baseline Flow RCA Page 1 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: November 6, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from GOHT Flare (FL-0404) alternative baseline per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 10/29/2018, the GOH Flare (FL-0404) began exceeding its alternative baseline threshhold. This was due to the Recycle Hydrogen Compressor (C-693) unexpectedly shutting down. Because of this shutdown excess hydrogen was sent to the flare. Water was found in the conduit for the seal oil level indication causing an issue with the electrical connections for the level transmitter of the seal oil tank. The seal was replaced for the conduit and the electrical wiring was tenninated for the seal oil tank level. At approximately 07:00 on 10/29/2018 FL-0404 began exceeding its alternative baseline threshhold until approximately 02:00 on 10/30/2018. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 10/29/2018 07 :00 Event Duration: 10/29/2018 07:00 -10/30/2018 02:00; 20 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) GOH Flare (FL-0404) Alternative Baseline Measured Quantity of Gas Discharged over Event Duration (dscf) 6,643,130 24-Hour Period 10/29/2018 06:00 - 10/29/2018 23:59 10/30/2018 00:00 -10/30/2018 02:59 Quantity of Gas Discharged in 24-Hour Period (dscf) 6,279,630 363,500 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60 I02a(g)(I) from a fuel gas combustion device, either the measured concentration of H 2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. HFNA-000003293 EPA Inspection Report - Page 1744 of 1969 Not applicable to this event. #23-2018-11-06 FL-0404 NSPS Ja Alt Baseline Flow RCA Page 2 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H 2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess e1nissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Unit feed rates were reduced to mini1nize excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d). including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): GOH Flare (FL-0404) Date of Discharge: 10/29/2018 Duration of Discharge: 20 hours ROOT CAUSE ANALYSIS The unexpected shutdown of C-693 led to an excess of flaring. CORRECTIVE ACTION ANALYSIS C-693 was repaired and brought back online. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action C-693 was repaired. Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planued startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003294 EPA Inspection Report - Page 1745 of 1969 H.OLLYF.RONTIER #24-2018-12-06 FL-0404 NSPS Ja Baseline Flow RCA Pagel of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 DATE: December 6, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for flow >500,000 scfd from GOHT Flare (FL-0404) alternative baseline per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. Between 11/19/18 and 11/26/2018, the GOH Flare (FL-0404) flow baseline reporting threshold was exceeded. During this period, discharges to the flare associated to the startup of the ROSE (Unit 25), the venting of hydrogen associated with an unexpected shutdown of the Diesel Hydrotreater (DHT, Unit 33) Recycle Hydrogen Compressor (C-0693 ), the plam1ed shutdown of the Mild Hydrotreater (MHC) unit, and the unit startup of several process units after an unexpected interruption of electrical power to the refinery, contributed to increasing the flare flow above the reporting threshold. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 11/19/2018 16:00 Event Duration: 11/19/2018 16:00 -11/26/2018 19; 370 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) GOH Flare (FL-0404) Alternative Baseline Measured Quantity of Gas Discharged over Event Duration (dscf) 27,060,572 24-Hour Period 11/19/2018 11/20/2018 11/21/2018 11/22/2018 11/23/2018 11/24/2018 11/25/2018 11/26/2018 16:0016:0016:0016:0016:0016:0016:0016:00- 11/20/2018 11/21/2018 11/22/2018 11/23/2018 11/24/2018 11/25/2018 11/26/2018 11/26/2018 15:00 15:00 15:00 15:00 15:00 15:00 15:00 19:00 Quantity of Gas Discharged in 24-Hour Period (dsc:I) 1,716,595 1,395,740 1,624,797 1,425,801 1,006,709 9,005,060 9,355,030 1,530,840 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Not applicable to this event. 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(]) from a fuel gas combustion device, either the measured concentration of H 2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4). Not applicable to this event. HFNA-000003295 EPA Inspection Report - Page 1746 of 1969 #24-2018-12-06 FL-0404 NSPS Ja Baseline Flow RCA Page 2 of2 ........................................................................................................HollyFrontier ..N a v a j o R e f i n i n g L L C . P.O. Box 159 Artesia, NM 88211 (575) 365-8365 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Not applicable to this event. 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess e1nissions on ambient air quality. The gas was safely combusted in a steam-assisted flare. Unit feed rates were reduced to mini1nize excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d). including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): GOH Flare (FL-0404) Date of Discharge: 10/29/2018 Duration of Discharge: 20 hours ROOT CAUSE ANALYSIS Between 11/19118 and 1112612018, the GOH Flare (FL-0404) flow baseline reporting threshold was exceeded. During this period, discharges to the flare associated to the startup of the ROSE (Unit 25), the venting of hydrogen associated with an unexpected shutdown of the Diesel Hydrotreater (DHT, Unit 33) Recycle Hydrogen Compressor (C-0693), the planned shutdown of the Mild Hydrotreater (iv1HC) unit, and the unit startup of several process units after an unexpected interruption of electrical power to the refinery, contributed to increasing the flare flow above the reporting threshold. CORRECTIVE ACTION ANALYSIS Units were restarted, C-693 was repaired returned online. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action Units were restarted, C-693 was repaired returned online. Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003296 EPA Inspection Report - Page 1747 of 1969 4 F: HOLLYFRONTIER #25-2018-10-08 NSPS JaRCA S02 FL-0404 Pagel of2 ...............................................................................................................HollyFrontier Navajo RefiningLLC 501 E. Main Artesia, NM 88201 (575) 748-3311 DATE: October 8, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for S02 from Flares per 60.103a(c)(l) I 60.108a(c)(6)(i) A description of the discharge. On 09/24/2018, the FCC Flare (FL-0402) began exceeding its S02 threshold. This was due to a power outage that affected Units 33 (Diesel Hydrotreater), 44 (Distillate Hydrodesulfurization), 45 (GOH), 70 (CCR), 10 (FCC), and the North Plant. The flaring associated witht he units's shutdown and subsequent startup resulted in emissions from the GOH Flare (FL-0404) to exceed 500 lbs S02 in a 24-hour period. I 60.108a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 09/24/201801:00 Event Duration: 09/24/2018 01:00 - 09/24/2018 10:00; 10 hours 60.108a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.107a(g). Affected Facility(s) GOH Flare FL-0404 24-hour Period 09/24/2018 01:00 - 09/24/2018 10:59 Quantity of Gas Discharged over Event Duration (dscf) 5,037,970 60.108a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Date 09/24/2018 01:00 - 09/24/2018 10:59 Number of hours 10 Hourly Average Measured Total Sulfur Concentration During Event (ppm) {60.108a(c)(6)(iv)} 244 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-term emissions limit in 60102a(g)(l) from a fuel gas combustion device, either the measured concentration ofH2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares, except as provided in 60.107a(e)( 4 ). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the HFNA-000003297 EPA Inspection Report - Page 1748 of 1969 #25-2018-10-08 NSPS JaRCA S02 FL-0404 Page 2 of2 .....................................................................................................................................................................................HollyFrontier ..Navajo...R e f i n i n g L L C 501 E. Main Artesia, NM 88201 (575) 748-3311 cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Affected Facility GOH Flare (FL-0404) Cumulative Quantity ofH2S Released (pounds) 1.13 Cumulative Quantity of S02 Released (pounds) 210.72 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess e1nissions on ambient air quality. The gas was safely combusted in a steam-assisted flare and scavenger was injected into the system. Maintenance worked quickly to determine what steps needed to be taken to reduce excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d), including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): GOH Flare (FL-0404) Date of Discharge: 09/24/2018 Duration of Discharge: 10 hours ROOT CAUSE ANALYSIS An unexpected power outage affected Units 33 (Diesel Hydrotreater), 44 (Distillate Hydrodesulfurization), 45 (GOH), 70 (CCR), 10 (FCC), and the North Plant. The affected units ended up causing excess S02 flaring to the GOH Flare. The outage lasted approximately 2-3 hours. CORRECTIVE ACTION ANALYSIS The electrical supply was promptly shifted to four additional substations that provide the electrical power to other sections of the refinery, allowing the electrical power to be restored. The frequency of preventative maintenance activities performed by the third-party electrical substation was increased fonn semiannual to monthly basis. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action Power was restored. Actions Completed within 45 days Yes Proposed Start Date NIA Completion Date NIA 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003298 EPA Inspection Report - Page 1749 of 1969 4 F: HOLLYFRONTIER #26-2018-10-25 NSPS JaRCA S02 FL-0404 Pagel of3 ...............................................................................................................HollyFrontier Navajo RefiningLLC 501 E. Main Artesia, NM 88201 (575) 748-3311 DATE: October 28, 2018 RE: 40 CFR Part 60 Subpart Ja: Investigation for S02 from Flares per 60.103a(c)(l) I 60.I08a(c)(6)(i) A description of the discharge. On 09/28/2018, the GOH Flare (FL-0404) began exceeding its S02 threshold. At approximately 03:00 on 09/28/2018, operations began a planned startup of the Mild Hydrocracker Unit (Unit 34) following a planned shutdown to replace the catalyst in the Guard Bed Reactor (D-3401). Due to low temperature and no steam in the Stripper (W-3401) all pressure built up in the Fractionator (W-3402) has nowhere to go except to be vented to the GOHT Flare (FL-0404). At approximately 10:00 on 09/28/2018, operations fired the Reactor Charge Heater (H-3403) to begin heating up the process to nonnal operating temperature. Once H-3403 is running, it heats the temperature through the Reactors (D3400/01/02), the Hot Oil Separator (D-3404), the Stripper (W-3401), and the Fractionator (W-3402). At approximately 20:42 on 09/28/2018, the temperature in W-340 l was hot enough for steam to remain in vapor state and operations began adding stripping steam to W-3401. When stripping steam is added, the steam pushes the diesel light ends (naphtha) to the Stripper Overhead Accumulator (D-3411) and operations can send the process downstream to North Division units instead of flaring. Othenvise, the process is pushed to W-3402 and flaring begins. The flaring is caused by low temperature and no steam in (W-340 l ). Until temperature is hot enough for stripping steam to be added, all built up pressure in (W-3402) is vented to FL-0404. At approximately 23 :00 on 09/28/2018 FL-0404 began exceeding its S02 threshold until approximately 22 :00 on 09/29/2018. I 60.I08a(c)(6)(ii) The date and time the discharge was first identified and the duration of the discharge. Event Start Date & Time: 09/28/2018 23 :00 Event Duration: 09/28/2018 23:00 - 09/29/2018 22:00; 24 hours 60. l08a(c)(6)(iii) The measured or calculated cumulative quantity of gas discharged over the discharge duration. If the discharge duration exceeds 24 hours, record the discharge quantity for each 24-hour period. For a flare, record the measured or calculated cumulative quantity of gas discharged to the flare over the discharge duration. If the discharge exceeds 24 hours, record the quantity of gas discharged to the flare for each 24-hour period. Engineering calculations are allowed for fuel gas combustion devices, but are not allowed for flares, except for those complying with the alternative monitoring requirements in 60.I07a(g). Affected Facility(s) GOH Flare FL-0404 24-hour Period 09/28/2018 23:00 - 09/29/2019 22:59 Quantity of Gas Discharged over Event Duration (dscf) 4,827,960 60. l08a(c)(6)(iv) For each discharge greater than 500lbs S02 in any 24-hour period from a flare, the measured total sulfur concentration or both the measured H2S concentration and the estimated total sulfur concentration in the fuel gas at a representative location in the flare inlet. Date 09/28/2018 23:00 - 09/28/2018 23:59 09/29/2018 00:00 - 09/29/2018 22:59 Number of hours 1 23 Hourly Average Measured Total Sulfur Concentration During Event (ppm) {60.I08a(c)(6)(iv)} 4,130 437 HFNA-000003299 EPA Inspection Report - Page 1750 of 1969 #26-2018-10-25 NSPS JaRCA S02 FL-0404 Page 2 of3 .....................................................................................................................................................................................HollyFrontier ..Navajo...R e f i n i n g L L C 501 E. Main Artesia, NM 88201 (575) 748-3311 60.108a(c)(6)(v) For each discharge greater than 500lbs S02 in excess of the applicable short-tenn emissions limit in 60102a(g)(l) from a fuel gas combustion device, either the measured concentration ofH2S in the fuel gas or the measured concentration of S02 in the stream discharged to the atmosphere. Process knowledge can be used to make these estimates for fuel gas combustion devices, but cannot be used to make these estimates for flares. except as provided in 60.107a(e)(4). Not applicable to this event. 60.108a(c)(6) (vi) For each discharge greater than 500lbs S02 in excess of the allowable limits from a sulfur recovery plant, either the measured concentration of reduced sulfur or S02 discharged to the atmosphere. Not applicable to this event. 60.108a(c)(6) (vii) For each discharge greater than 500lbs S02 in any 24-hour period from any affected flare or discharge greater than 500lbs S02 in excess of the allowable limits from a fuel gas combustion device or sulfur recovery plant, the cumulative quantity of H2S and S02 released into the atmosphere. For releases controlled by flares, assume 99-percent conversion of reduced sulfur or total sulfur to S02 For fuel gas combustion devices, assume 99-percent conversion of H2S to S02. Affected Facility GORT Flare (FL-0404) Cumulative Quantity ofH2S Released (pounds) 3.1 Cumulative Quantity of S02 Released (pounds) 572 60.108a(c)(6) (viii) The steps that the owner or operator took to limit the emissions during the discharge. Operations followed procedures to minimize the impact of the excess emissions on ambient air quality. The gas was safely combusted in a steam-assisted flare and scavenger was injected into the system. Maintenance worked quickly to detennine what steps needed to be taken to reduce excess flaring. 60.108a(c)(6) (ix) The root cause analysis and corrective action analysis conducted as required in 60.103a(d). including an identification of the affected facility, the date and duration of the discharge, a statement noting whether the discharge resulted from the same root cause(s) identified in a previous analysis and either a description of the recommended corrective action(s) or an explanation of why corrective action is not necessary under 60.103a(e). Affected Facility(s): GOH Flare (FL-0404) Date of Discharge: 09/28/2018 Duration of Discharge: 24 hours ROOT CAUSE ANALYSIS The flaring is caused by low temperature and no steam in (W-3401). Until temperature is hot enough for stripping steam to be added, all built up pressure in (W-3402) is vented to FL-0404. CORRECTIVE ACTION ANALYSIS No corrective actions are planned. Operations continues to investigate alternatives to startup procedures for the purpose of identifying potential methods to reduce or eliminate the need to flare during unit startup. 60.108a(c)(6) (x) For any corrective action analysis for which corrective actions are required in 60.103a(e), a description of the corrective action(s) completed within the first 45 days following the discharge and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates. Corrective Action Actions Completed within 45 days Proposed Start Date Completion Date HFNA-000003300 EPA Inspection Report - Page 1751 of 1969 #26-2018-10-25 NSPS JaRCA S02 FL-0404 Page 3 of3 .....................................................................................................................................................................................HollyFrontier ..Navajo...R e f i n i n g L L C I Temperature was hot enough for W-3401 I Yes IN/A IN/A 501 E. Main Artesia, NM 88201 (575) 748-3311 I 60.108a(c)(6) (xi) For each discharge from any affected flare that is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare, a statement that a root cause analysis and corrective action analysis are not necessary because the owner or operator followed the flare management plan. Not applicable to this event. HFNA-000003301 EPA Inspection Report - Page 1752 of 1969 New l\'lexko En\'ironment Department Ai:r Quality Bureau Compliance and Enforcement Section 525 Camino de fos Marquez, Suite 1 Version 05.02.13 Santa Fe, NM 87505 Phone (505) 476-4300 Fax (505) 476-4375 NMED USE ONLY l ' ~--=-~--:~~-----1----------------------J REPORTING SUBMITTAL FORM L PLEASE NOTE: - Indicates reauired field NMEQJ.JSE ONLY -------1 Staff Admin ...................-.. - - - ~ SECTION I w GENERAL COMPANY AND FACILITY INFORMATION A Company Name: D. Facility Name: HollyFrontier Navajo Refining LLC HollyFrontier Navajo Refining LLC B.1 Company Address: E.1 Facility Address: PO Box 159 501 E.Main St. ... ...-......., ......., .. B.2City: Artesia \ ~~ State: j Ba:2~1~~:~~------------------- ~~e~:ity: ____l__~A State: I~8~~~i:: ~?:-~~~; ;_~,ie~;;: I ~ C.1 Company Environmental Contact: ! C.2 Title: Scott M. Denton Environmental Manager F.1 Facility Contact: Scott M. Denton i F.2 Title: I Environmental Manager -;;;_~ :~~~~ Number: ~~mber: : Number: ~~:~~ ~,:,-~-m""b-e-r:----~ 45 4 1 7 7 64 C.5 E=m-ai_l_A-d-d-re_s_s-:----~------------+-F~.-5~~E~m-ai-l~Address:........................................, .............--..--------------------------..-~.. Scott.Denton@hollyfrontier.com Scott.Denton@hollyfrontier.com G. Resoonsible Official: mue VonM: H. Title: !. Phone Number: Parrish R. Miller Vice President & Refinery 575-748-3311 Manacer K. Al Number: ! l. Title V Permit Number: ~ M. Title V Permit ls~ue Date~ N. NSR Permit Number: 198 P051-R2 05/06/2015 PSD-NM-0195-M37 TReporting Period: -.--------------------------------------------'---------------;-1................. ,1. From: 01/01/2019 To: 03/31/2019 ,=====N;..\.-..:=:.::=::= = = J. Fax Number: 575-746-5451 0. NSR Permit Issue Date: 08/12/2016 SECTION II -TYPE Of SUBMITTAi.. (check one that applies) j Title V Annual Compliance Permit Condition(s): AD i ~~~oo !Description: . ' s.o I Title V Semi-annual Monitoring Report Permit Condition(s): jDescriotion: C. D NSPS Requirement (40CFR60} Reaulation: Section{sl: Description: MACT Requirement (40CFR63} Reaulation: Section(sl: Description: E.D F.D NMAC Requirement (20.2.xx) or NESHAP Requirement (40CFR61) Permit or Notice of Intent (NOi} Requirement Reaulation: Section{si: Permit No.D: or NOi No.D: Condition(s): Descri otion: Description: G.[gj Requirement of an Enforcement Action NOVNo. 0: orSFO No. 0: Section(s): or CD No. [gj: or Other D: CIV-01 1422LH Paragraphs 37 and 23.0 Description: EPA Consent Decree Quarterly Report for HollyFrontier Navajo Refining (Artesia and Lovington) SECTION IV w CERTIFICATION ----------------------------------.......- .................- - . -....- ..- .........- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -...............................................................,...,..... After reasonable inquiry, I Parrish R. Miller ...................... certify that the information in this submittal is true, accurate and complete. {name of reporting official) Title: Vice President & Refinery I Manager " Date 0413012019 Responsible Official for Title V? [gJ Yes Reviewed By: Date Reviewed: HFNA-000003302 EPA Inspection Report - Page 1753 of 1969 New Mexico Environment Department Air Quality Bureau Compliance and Enforcement Section 525 Camino de fos :J\,farquez, Suite 1 Santa Fe, Nl\1 87505 Version 05.0:!.13 Phone (505) 476-4300 Fax (505) 476-4375 L._"'" t:JMED USE;,QNbX TEMPO PLEASE NOTE: indicates required field l::,..........................N....M_____E____D_ USE ONLY ----------~\ REPORTING SUBMITTAL FORM Staff Adm in :::::::::::::::::::::::: :::::::::: ::: ] SECTION I w GENER.Al COMPANY AND FACILITY INFORMATION A. Company Name: D. Facmtv Name: HollyFrontier Navajo Refining LLC HollyFrontier Navajo Refining LLC B.1 Company Address: ...................................................-------I,E,.1,'@"'--~Faciiity Address: PO Box 159 .. !J~~~C.ity: i~J State: ~:2~1"=~:59-1 7406 South Main E~~i~g~~~yi "" ................ l~~ State: ~~1:c;zi'ii:-o J C.1 Company Environmental Contact: l C.2 Title: ------~-F-.1-_F_a_c_m_ty_C_o_n_t_a-ct-:- - - Scott M. Denton i Environmental Manager Scott M. Denton c::fPhone Number: rcA..ii!i"Fa,di.i"i:imber: hone Number: 575-746-5487 C.5 Email Address: .. ..... 575-746-5451 ...... .................. 575-746-5487 F.5 Email Address: 1F.2 Title: ! Environmental Manager iF.4FaxNumber: 575-746-5451 ScottDenton hol! rontier.com Scott.Denton@hollyfrontier.com G. Resoonsible Official: ITitle VonM: I. Phone Number: I 575-748-3311 P. Reporting Period: From: 01/01/2019 To: 03/31/2019 M. Title V Permit Issue Date: 07/13/2015 SECTION II -TYPE OF SUBMITTAL {check one that applies} D i Title V Annual Compliance 'Permit Condition{s): ;Description: A. ! Certification B. D Title V Semi-annual Monitoring Report Permit Condition(s): J>escription: C. D NSPS Requirement (40CFRS0) Reau lation: Section!sl: """""---------- !Description: D. D MACT Requirement (40CFR63} . Reaulation: Sectionisl: E. D F.O NMAC Requirement (20.2.xx) or NESHAP Requirement (40CFR61) Permit or Notice of Intent (NOi) Requirement Rem.alation: Section{sl: Permit No.D: or NOi No.D . Condition(s): IDescription: I ! Description: ! 'Description: G.IXJ . Requirement of an Enforcement Action NOV No. D: or SFO No. D: . Section(s): or CD No. 181: or Other D: Paragraphs 37 and 23.0 CIV-01 1422LH Description: EPA Consent Decree Quarterly Report for HollyFrontier Navajo Refining (Artesia and Lovington) S;gnar~:~;~r ,..-,,..,..,,,""'"' SECTION IVM CERTIFICATION ~ =~~~~-~------- --------------------------------------------- ------~~~~~~~~~~=~~~~~~~~~~~~~~~~~~------------- After reasonable inquiry, I Parrish R. Miller certify that the information in this submittal is true, accurate and complete. Title: Vice President & Refinery I Manager Date 04/3012019 Responsible Official for Tltle V? IXJ Yes Reviewed By: _ _ _ _ _ __ Date Reviewed: HFNA-000003303 EPA Inspection Report - Page 1754 of 1969 July 30, 2019 :HOLLY"FRONTIER~ U.S. Environmental Protection Agency Director, Air Enforcement Division Ariel Rios Building 1200 Pennsylvania Avenue, N.W. Mail Code 2242-A Washington, DC 20460 Certified Mail/Retum_Receipt 7018 0360 0001 7923 5828 Re: Quarterly Implementation Progress Report Pursuant to the Consent Decree entered March 5, 2002 by the U.S. District Court for the District of New Mexico in United States of America et al. v. Navajo Refining Company, LLC et at Dear Director: Pursuant to Paragraphs 37 and 23.0 of the subject consent decree, this submittal provides the status of implementation of consent decree requirements through the calendar quarter ending June 30, 2019 for HollyFrontierNavajo Refining LLC (formerly Navajo Refining Company, L.L.C), (Navajo's) Artesia and Lovington, N'"M refineries. As specified by Paragraph 37, a statement of certification is provided on the following page. In accordance with the notice provisions ofParagraph 91, copies ofthis report are being mailed to EPA Region 6 (i.e., the Applicable EPA Region) and to both addresses listed for the State ofNew Mexico. Navajo is also providing an additional hardcopy to EPA's contractor and an electronicmail copy to the address provided in the email from EPA Region 6 dated January 31, 2019. If you have any questions regarding this submittal, please contact me at 575-746-5487 or Ray Smalts at 575-746-5490. Sincerely, Scott M. Denton Environmental Manager HollyFrontier Navajo Refining LLC P.O. Box 159 Artesia, New Mexico 88211-0159 Phone: (575) 746-5487 E-mail: HollyFrontier Navajo Refining LLC 501 East Main Artesia, NM 88210 {575) 748-3311 nrn1:/!w:w:w.,pg.1):yfr1;mtjey,9:).m HFNA-000003304 EPA Inspection Report - Page 1755 of 1969 By signature below, the undersigned hereby certifies to the following: Statement.of Certification I certify under penalty of law that this information was prepared under my direction or supervision in accordance with a system designed to assure that qualified personnel properly gather and evaluate the information submitted. Based on my directions and my inquiry of the person(s) who manage the system, or the person(s) directly responsible for gathering the information, the information submitted is, to the best of my knowledge and belief, true, accurate, and complete. Enclosure cc (w/enc.): Bureau Chief Air Quality Bureau New Mexico Environment Department 525 Camino de los Marquez, Suite 1 Santa Fe, NM 87507 U.S. Environmental Protection Agency c/o Matrix Environmental & Geotechnical Services Matrix New World Engineering, Inc. 26 Columbia Turnpike Florham Park, NJ 07932 General Counsel Office of General Counsel New Mexico Environment Department P.O. Box 26110 Santa Fe, NM 87502-61 lO Electronic cc (w!enc.): Electronic cc (w/enc.): Environmental File: (6{.:/\.:\(.:::,:>,J;..,:;::,::i:\;:e.c.;:,": HollyFrontier: P. Miller, B. Romine, K Srnalts J. Stump, T. Jones, T. \Vheeler, S. Gokhale; R. Bagherian 5.2.3 .1 Consent Decree\Subm-Resp\Quarterly Reports\2019\2019-07-30 2QT Report\2019-07-30 2QT Consent Decree Report.pdf HollyFrontier Navajo R.etming LLC 501 East Main Artesia, Ni\188210 (575) 748-3311 l;mp;//'-\'W\"!,hollyfri.:mtier,com HFNA-000003305 EPA Inspection Report - Page 1756 of 1969 New lVIexico Environment Department Air Qualify Bureau Compliance and Enforcement Section 525 Camino de los Marquez, Suite 1 Santa Fe, Nl\1 87505 Version 05.02.13 Phone (505) 476-4300 Fax (505) 476-4375 NMED USE ONLY . .TEMPo.L___J REPORTING SUBMITTAL FORM - ~ St~;ED~USE...ONlY............... 1 Adm;n PLEASE NOTE: indicates required field SECTION i M GENERAL COMPANY AND FACILITY INFORMATION A. Company Name: HollyFrontier Navajo Refining LLC 8.1 Company Address: PO Box 159 . 8.2City: Artesia C.1 Company Environmental Contact: Scott M. Denton D. Facmtv Name: :.f i~~:::::~ HollvFrontierNavajoRefining LLC E.1 Facility Address: ........ 501 E.Main St. i~~:::::: .. ~~/~p:1 - O 1 5 9 ~:::::ty Contact; ................................. ~~~~Zip:............................. i Environmental Manager Scott M. Denton Environmental Manager 5C7.55-746E-m54a8il7Address: C.3 Phone Number: .........................J...;+:-~~~~4~~mber: :?~-~:S~;;:7 Number: F.5 Email Address: ~7~~%6~~~~1_:~:~: Scott.Denton@hollyfrontier.com Scott.Denton@hoHyfrontier.com G. Resoonsible Official: ffitle V onM: H. Title: Vice President & Refinery I. Phone Number: J. Fax N'umber: , Parrish R. Miller Manager, HollyFrontier Navajo 575-748-3311 . 575-746-5451 Refinina LLC D SECTION II-TYPE OF SUBMITTAL (check one that applies) ................... (-'--------------------------------------------------------------~---------------------------------------------------- ---------- ..................... ~ ~~ ......~~~~~~~~~~ A. Title V Annual Compliance Permit Condition(s): Description: Certification a. D Title V Semi-annual Monitoring Report Permit Condltion{sl: Description: C. D NSPS Requirement {40CFR60) Reaulation: Section(sl: Description: D. D MACT Requirement {40CFR63) Reaulation: Sectionlsi: Description: E. D F.D NMAC Requirement (20.2.xx) or NESHAP Requirement (40CFR61) Permit or Notice of Intent {NOi) Requirement Reaulation: Section(sl: Permit No.D: or NOi No.O Com::lition{s): Descriotion: i Description: G. l'8J Requirement of an Enforcement Action ! NOV No. 0: or SFO No. 0: Section(s): or CD No. t8l: or Other O: Paragraphs 37 and 23.0 ICIV-01 1422LH Description; EPA Consent Decree Quarterly Report for HollyFrontier Navajo Refining (Artesia and Lovington) -S;gn,tu:t,::_ y,4Z__ SECTION IV w CERTIFICATION After reasonable j.tt~lry, ! Parrish R. Miller /~ 1,-.,f Npo...... offidol] -c-cc """"""'" ......................................................."'"""""""'" certify that the information in this submittal is true, accurate and complete. cc CCC Title: Vice President & Refinery Manager, HollyFrontier Navajo Refininu LLC Date 07/30/2019 Responsible Official for Title II? r;gj Yes 0No Reviewed By: Date Reviewed: HFNA-000003306 EPA Inspection Report - Page 1757 of 1969 New Mexico En'\'ironment Department Ai:r Quality Bureau Compliance and Enforcement Section 525 Camino de fos Marquez, Suite 1 Santa Fe, NM 87505 Version 05.02.13 Phone (505) 476-4300 Fax (505) 476-4375 ITEMP:~EDUSEONLY ' REPORTING SUBMITTAL FORM PLEASE NOTE:. Indicates required field SECTION I w GENERAL COMPANY AND FACILITY INFORMATION A. Company Name: D. Facmtv Name: HollyFrontier Navajo Refining LLC HollyFrontier Navajo Refining LLC 13.1 Company Address: PO Box 159 E.1 Facility Address: 7406 South Main St~~ED USE.ON~)' I ............................. ) Admin --0:2 City: Artesia C.1 Company Environmental Contact: Scott M. Denton !13.3 State: i EU Zip: E.2 City: NM 8 8 2 1 1 - 0 1 5 9 Lovington C.2 Title: ----~-F-.-1--F-a-c-i.l..i.t..y.....contact: Environmental Manager Scott M. Denton I E.3 State: E.4 Zip: NM F.2 Title: 88260 ........................................................ . Environmental Manager C.3 Phone Number: 575-746-5487 C.4 Fax Number: 575-746-5451 F.3 Phone Number: 575-746-5487 F.4 Fax Number: 575-746-5451 C.5 Email Address: Scott.Denton@hollyfrontler.com G. Resoonsib!e Official: /Title V onlvl: Parrish R. Miller F.5 Email Address: Scott.Denton@hollyfrontier.com H. Title: -======~'=1.' Phone 't'.i;'.;mber: Vice President & Refinery Manager, HollyFrontier Navajo I 575-748-3311 J. Fax Number: 575-746-5451 ""'"""""""""""""""""""""""'""'""'.... Refinino UC ! r......... ~ f..... ~ .J22 A!Number:00000000000 ] LPri~~~R~~~rmit. Number=......... ~iJl~.~~;J1';frmrit'ssueDi!!te:''..N6:l'3~M~~.r...r.i-t~N~u-m-b-.e..r..,.=.....,,....... 1....1.........:.......1.... o............6ermitlss;:;eDat;:i I I I P. Reporting Period: From: 04/01/2019 To: 06/30/2019 SECTION II-TYPE OF SUBMITTAL {check one that apelies)___ D Title V Annual Compliance .Permit Condition(s): Description: A. Certification B.O. Title V Semi-annual Monitoring Report \Permit Condition(s}: Descriotion: C. D NSPS Requirement (40CFR60) Reiwlation: Section{s): .. ....................., ..................................................................._,,""""""""'"" " Descriotion: D. D MACT Requirement {40CFR63) Reaulation: Section(s): Descriotion: D NMAC Requirement IRecmlation: Section(s): Descriotlon: " E. (20.2.xx} or NESHAP Requirement (40CFR61} I F.0 Permit or Notice of Intent {NOi) Requirement Permit No.O: or NOi No.O: Condition{s}: Description: G.[gj Requirement of an Enforcement Action NOV No. 0: or SFO No. 0: Section(s): or CD No. tEl: or Other D: CIV-01 1422LH Paragraphs 37 and 23.0 Description: EPA Consent Decree Quarterly Report for HollyFrontler Navajo Refining {Artesia and Lovington) Reviewed By: Date Reviewed: HFNA-000003307 EPA Inspection Report - Page 1758 of 1969 CALENDAR QUARTERLY REPORT SUBMITTED PURSUANT TO SECTION IX OF THE CONSENT DECREE ENTERED IN UNITED STATES OF AMERICA ET Al. V. NAVA.JO REFINING COMPANY, l.P., AND MONTANA REFINING COMPANY (ENTERED MARCH 5, 2002) Cumulative from Lodging (December 20, 2001) Through June 30, 2019 HollyFrontier Navajo Refining LLC (formerly Navajo Refining Company, l.LC.) Artesia and Lovington, NM Refineries P.O. Box 159 Artesia, NM 88211-0159 HFNA-000003308 EPA Inspection Report - Page 1759 of 1969 al~ndar Quarterly Report - 2nd Quarter 2019 Ho!lyFrontier Navajo Refining LLC, Artesia and Lovington Refineries TABLE OF CONTENTS 1.0 INTRODUCTION ............................................................................................................:1:~- 2.0 PROGRESS REPORT ON IMPLEMENTATION OF SECTION V OF THE CONSENT DECREE .....................................................................................................................................2 3.0 SUMMARY OF ACTUAL OR ANTICIPATED PROBLEMS IN IMPLEMENTING THE REQUIREMENTS OF SECTION V...........................................................................................24 4.0 SUMMARY Of EMISSIONS DATA ..............................................................................24 5.0 IMPLEMENTATION OF ENVIRONMENTALLY BENEFICIAL PROJECTS ..................28 6.0 OTHER MATTERS .......................................................................................................33 ATTACHMENTS ATTACHMENT 1 -APPENDIX G SUMMARY REPORT ATTACHMENT 2 - APPENDIX H SUMMARY REPORT ATTACHMENT 3 - QUARTERLY EOL SUMMARY ATTACHMENT 4 - 2QT 2019 EOL ANALYTICAL REPORTS ii HFNA-000003309 EPA Inspection Report - Page 1760 of 1969 Calendar Quarterlv Report - 2nd Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries CALENDAR QUARTERLY REPORT Cumulative from Lodging (DECEMBER 20, 2001) Through June 30, 2019 HollyFrontier Navajo Refining LLC (Navajo) Artesia and Lovington, NM Refineries 1.0 INTRODUCTION In accordance with the requirements of Section !X of the Consent Decree entered in UNITED STA TES OF AMERICA ET Al., D. V.M NAVAJO REFINING COMPANY, L.P., AND MONTANA REFINING COMPANY (entered March 5, 2002), Navajo submits the following "calendar quarterly report" for the Artesia and Lovington, NM refineries. Section IX requires that the quarterly report be submitted within 30 days following the calendar quarter. Today's report covers actions through the second quarter 2019. For completeness, this report addresses relevant actions or activities not just within the current quarter but anytime after the December 20, 2001 Date of Lodging. The contents of this report include: 1. A progress report on the implementation of the requirements of Section V (Section 2.0) 2. A description of any problems anticipated with respect to meeting the requirements of Section V (Section 3.0) 3. A summary of the emissions data as required by Section V (Section 4.0); 4. A description of environmentally beneficial projects and SEP implementation activity during this reporting period (Section 5.0); and 5. Such other matters as Navajo believes should be brought to the attention of EPA (Section 6.0). Summaries showing the progress on Consent Decree Appendices G and H are provided as Attachments 1 and 2, respectively, 1 HFNA-000003310 EPA Inspection Report - Page 1761 of 1969 Calendar Quarterly Report - 2nd Quarter 2019 Hol!yFrontier Navajo Refining LLC, Artesia and Lovington Refineries 2.0 PROGRESS REPORT ON IMPLEMENTATION OF SECTION V OF THE CONSENT DECREE A. Section V, Paragraphs 11 and 14: NOx and CO Emission Rech.1ctions from FCCUs Paragraph 12: S02 Emission Reductions from fCCUs Paragraph 13: PM Emission Reductions from FCCUs ; . -A-rt es-ia-FCCU( N o FC-CU- a~t L~ovi~ n t..o....n.... 1: ,,.............................................................................................................. _ .. Requirement CD Status/Comment 1 ..........................----+---P-a-ra--r-a--h--~~--------.......................................................................................................--..,,..; i Begin baseline period, 11.B Requirement completed. The optimization period perform notices of Low- NOx was completed and the optimized addition rate to be promoter and optimization used during the demonstration period was study. Baseline period data submitted to EPA with supporting documentation on collection from 1/1/04 - 2/24/05. 6/30/04. Optimization period , to commence no later than li_::;;;3~ L I June 30, 2004. ........................................... ...................................................----------------............................................................ [ Commencement of NOx 11.D i As agreed between Navajo and EPA, the i Additive Demonstration ' i Demonstration Period ended 05/31/2006. Navajo i ~~bo~'.~~1ii~r:~:o_n_c-e_n_tr-at-io_n_-_ba_s_e_d_N_O_x-lim-its 2 HFNA-000003311 EPA Inspection Report - Page 1762 of 1969 Requirement ............... co Status/Comment """"""------, ~-----------P_aragr~ph........................................................................................ - Install/certify CEMS to 11.F CEMS installed and certification RATA performed monitor FCCU NOx and 02 11/13/03. Report showing initial certification by 12/31/03. submitted to NMED on 1/7/04. Pursuant to 40 CFR 60 App F, annual RATA performed 02/14 and 02/15/06. Report showing certification submitted to NMED on 03/15/06. Pursuant to 40 CFR 60 App F, annual RATA performed 01/24/07. Report showing certification submitted to NMED on 02/22/07. Pursuant to 40 CFR 60 App F, annual RATA performed 01/22/08. Report showing certification submitted to NMED on 02/18/08. Pursuant to 40 CFR 60 App F, annual RATA performed 03/03/09. Report showing certification submitted to NMED on 03/30/09. Pursuant to 40 CFR 60 App F, annual RATA performed 03/02/2010 and 03/03/2010. Report showing certification submitted to NMED on 04/05/2010. Pursuant to 40 CFR 60 App F, annual RATA performed 03/01/2011. Report showing certification submitted to NMED on 03/28/2011. Pursuant to 40 CFR 60 App F, annual RATA performed 01/17/2012. Report showing certification submitted to NMED on 02/17/2012. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2013. Report showing certification submitted to NMED on 02/07/2013. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2014. Report showing certification submitted to NMED on 02/04/2014. Annual RATA performed 01/06/2015. Report submitted to NMED on 02/05/2015. Annual RATA performed 01/05/2016. Report submitted to NMED on 02/04/2016. Annual RATA performed 01/03/2017. Report submitted to NMED on 02/04/2017. Annual RATA performed 01/09/2018. Report submitted to NMED on 02/09/2018. Annual RATA performed 02/13/2019. Report submitted to NMED on 03/23/2019. A review of documentation of QC procedures under 40 CFR 60 App. F was recently undertaken. Documentation of all QC procedures in accordance with 40 CFR 60 App. F was completed as of 12/31/2017, 3 HFNA-000003312 EPA Inspection Report - Page 1763 of 1969 , rtesia and Lovington Re ineries .......... ............................................................ .......... Requirement ------------- CD Submit plan to minimize NOx Par~g(~P~ 11.G from FCCU during GOHT outages within 180 days of lodging Date. Install and operate wet gas scrubber on FCCU to meet 25 ppmv (annual avg) and 50 ppmv (7-day) S02 by 12/31/03. 12.B ssssssssssssssssssssssssssssssss,,, ,-..........,,-. ------------- Status/Comment .......................... ssssssssssssssssssssss Plan Submitted on 6/18/02. EPA's response letter dated 12/9/04 enumerated the requirements for Navajo to have relief from the short term NOx emission limit. Wet gas scrubber installed and operational during 4th Quarter 2003. S02 performance testing completed on 10/16/03; report submitted 1/7/04. ......... 4 HFNA-000003313 EPA Inspection Report - Page 1764 of 1969 Calendar Quarterly Report - 2nd Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries I ~:~~~~::.e~~ : :::::: }Par~:aph ::::::::: ... ........... -~~:~~~'~_o_m_m_e_n_ t _____ Install and calibrate S02 12.D CEMS installed and certification RATA performed CEMS in accordance with 40 11 /13/03. Report showing initial certification CFR 60.11, 60. 13 and Part submitted to NMED on 1/7/04. 60 App. F Pursuant to 40 CFR 60 App F, annual RATA performed 02/14 and 02/15/06. Report showing certification submitted to NMED on 03/15/06. Pursuant to 40 CFR 60 App F, annual RATA performed 01/24/07. Report showing certification submitted to NMED on 02/22/07. Pursuant to 40 CFR 60 App F, annual RATA performed 01/22/08. Report showing certification submitted to NMED on 02/18/08. Pursuant to 40 CFR 60 App F, annual RATA performed 03/03/09. Report showing certification submitted to NMED on 03/30/09. Pursuant to 40 CFR 60 App F, annual RATA performed 03/02/2010 and 03/03/2010. Report showing certification submitted to NMED on 04/05/2010. Pursuant to 40 CFR 60 App F, annual RATA performed 03/01/2011. Report showing certification submitted to NMED on 03/28/2011. Pursuant to 40 CFR 60 App F, annual RATA performed 01/17/2012. Report showing certification submitted to NMED on 02/17/2012. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2013. Report showing certification submitted to NMED on 02/07/2013. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2014. Report showing certification submitted to NMED on 02/04/2014. Annual RATA performed 01/06/2015. Report submitted to NMED on 02/05/2015. Annual RATA performed 01/05/2016. Report submitted to NMED on 02/04/2016. Annual RATA performed 01/03/2017. Report submitted to NMED on 02/04/2017. Annual RATA performed 01/09/2018. Report submitted to NMED on 02/09/2018. Annual RATA performed 02/13/2019. Report submitted to NMED on 03/23/2019. See entry for Paragraph 11.F. regarding 40 CFR 60 ........ ""~Rf?.: F QC procedures. ................................. 5 HFNA-000003314 EPA Inspection Report - Page 1765 of 1969 Calendar Quarterly Report- 2nd Quarter 2019 HollyFrontier Navajo Refining llC, Artesia. and Lovington Refineries I Requirement "f""""" CD I " Status/Commin"i"""-"""" I 1wGSshaH achieve 1 lb p.i\ifrE~rr~~P..~Twet gas scrubber installedandope.raiionaTciuring""""""; per 1000 lb coke bum on 3-hr l 4th Quarter 2003. basis by 12/31/03. I PM testing completed 11/13/03 and report submitted 1/7/04. Results of 0.5-0.6 lb PM per 1,000 lb coke burn compared to <1.0 lb PM per 1,000 lb coke bum standard. Additional testing was performed 3/3/04 following repairs to the scrubber. These test results indicate <0.25 lb PM per 1,000 lb coke bum (i.e., 25% of standard). 1.................. --------- _I 6 HFNA-000003315 EPA Inspection Report - Page 1766 of 1969 Calendar Quarterly Reoort - 2nd Quarter 2019 HollyFrontier Navajo Refining llC, Artesia and Lovington Refineries ~:s~! r...... 4~~Ina...... ~----.,........... """"',""'"""""'""""'"""""""" ..............................................- - - - - Requirement CD I Status/Comment ! Paragraph I I ;~~ ~~~~~~vo~n1-hr .. 1.. L~~:i~~o~~~~~:s~~~~~~~du~tt/~.~~~~-6/~;p~~MS "1 annual avg. by 12/31/03. Install/Certify CEMS for FCCU CO and 02 by 12/31/03. showing certification submitted to NMED on 1/7/04. Pursuant to 40 CFR 60 App F, annual RATA performed 02/14 and 02/15/06. Report showing certification submitted to NMED on 03/15/06. Pursuant to 40 CFR 60 App F, annual RATA performed 01/24/07. Report showing certification submitted to NMED on 02/22/07. Pursuant to 40 CFR 60 App F, annual RATA performed 01/22/08. Report showing certification submitted to NMED on 02/18/08. Pursuant to 40 CFR 60 App F, annual RATA performed 03/03/09. Report showing certification submitted to NMED on 03/30/09. Pursuant to 40 CFR 60 App F, annual RATA performed 03/02/2010 and 03/03/2010. Report showing certification submitted to NMED on 04/05/2010. Pursuant to 40 CFR 60 App F, annual RATA performed 03/01/2011. Report showing certification submitted to NMED on 03/28/2011. Pursuant to 40 CFR 60 App F, annual RATA performed 01/17/2012. Report showing certification submitted to NMED on 02/17/2012. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2013. Report showing certification submitted to NMED on 02/07/2013. Pursuant to 40 CFR 60 App F, annual RATA performed 01/08/2014. Report showing certification submitted to NMED on 02/04/2014. Annual RATA performed 01/06/2015. Report submitted to NMED on 02/05/2015. Annual RATA performed 01/05/2016. Report submitted to NMED on 02/04/2016. Annual RATA performed 01/03/2017. Report submitted to NMED on 02/03/2017. Annual RATA performed 01/09/2018. Report submitted to NMED on 02/09/2018. Annual RATA performed 02/13/2019. Report submitted to NMED on 03/23/2019. See entry for Paragraph 11.F. regarding 40 CFR 60 App. F QC procedures. 7 HFNA-000003316 EPA Inspection Report - Page 1767 of 1969 Calendar Quarterl:t: Report- 2nd Quarter 2019 HollyFronUer Navajo Refining LLC, Artesia and Lovington Refineries B. Section V, Paragraph 15: NSPS Applicability of FCCUs 1==~~~~~i~~~o.FC:r~~J:~::L................. Slalus/Coni===-=--J , NSPS becomes applicable to ! 15 I Wet gas scrubber installed and operational during I I FCCU for S02, PM, CO and I 4th Quarter 2003. PM performance testing, initial I I opacity on 12/31/03. GEMS certification RATA for S02 and CO completed 11/13/03 and report submitted 117/04. AMP for opacity submitted 12/31/03; pending written approval. Method 9 readings indicate O- 5% opacity. Annual PM testing per AMP was performed 2/8/05 indicating 0.11 lb PM/1000 lb coke. Annual PM testing per AMP was performed 2/15/06 indicating 0.19 lb PM/1000 lb coke. Annual PM testing per AMP was performed 1/24/07 indicating 0.34 lb PM/1000 !b coke. Annual PM testing per AMP was performed 1/22/08 indicating 0.13 lb PM/1000 lb coke. Annual PM testing per AMP was performed 3/3/09 indicating 0.47 lb PM/1000 lb coke burned. Annual PM testing per AMP was performed 03/02/2010 and 03/03/2010.indicating 0.54 lb PM/1000 lb coke burned. Annual PM testing per AMP was performed 03/01/2011 indicating 0.23 lb PM/1000 lb coke burned. Annual PM testing per AMP was performed 01/17/2012 indicating 0.39 lb PM/1000 lb coke burned. Annual PM testing per AMP was performed 01/08/2013, which did not show compliance, and again on 3/04/2013 indicating 0.204 lb PM/1000 lb coke burned. Annual PM testing per AMP performed 01/08/2014 indicating 0. 71 lb PM/1000 !b coke burned. Report showing certification submitted to NMED on 02/04/2014. Annual PM testing per AMP performed 01/06/2015 indicating 0.11 lb PM/1000 lb coke burned. Report submitted to NMED on 02/05/2015. Annual PM testing per AMP performed 01/05/2016 indicating 0.35 !b PM/1000 lb coke burned. Report submitted to NMED on 02/04/2016. Annual PM testing per AMP performed 01/03/2017 indicating 0.03 lb PM/1000 lb coke burned. Report submitted to NMED on 02/03/2017. Annual PM testing per AMP performed 01/09/2018 indicating 0.50 lb PM/1000 lb coke burned. Report submitted to NMED on 02/09/2018. Annual PM testing per AMP performed 02/13/2019 indicating 0.10 lb PM/1000 lb coke burned. Report submitted to NMED on 8 HFNA-000003317 EPA Inspection Report - Page 1768 of 1969 Calendar Quarterly Report- 2nd Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries , ....c. Section.v,..Para9r~phJ6:__NOx Emissions Reductionsfrom...Heaters an~Boilers..... 1 Requirements I CD I Status/Comment L" " """" ..... Install NOx control on B-7 by 12/31/02 to meet 0.06 lb/MMBtu and operate CEMS on B-7 for NOx and 02. L.Paragraph I 16.B.ii. and 16.C.i. J ............................................. ------------ 1 FGR started up on 12/17/2002. CEMS installed Iand was successfully certified by a RATA performed 12/18/2002. Test results and CEMS indicate B-7 meets NOx control requirement. 1 Pursuant to 40 CFR 60 App F, annual RATA performed 09/26/2006, 09/13/2007, 09/09/2008, 09/17/2009, 08/24/2010, 08/16/2011, 08/15/2012, 08/07/2013. .......................................... Install NOx control on B-8 by 12/31/03 to meet 0.06 lb/MMBtu and operate CEMS on B-8 for NOx and 02. 1ifrfii. and 16.C.i. RATA performed 07/30/2014. Certification report submitted to NMED on 09/11/2014. RATA performed 07/23/2015. Certification report submitted to NMED on 08/20/2015. RATA performed 07/13/2016. Certification report ' submitted to NMED on 08/05/2016. RATA performed 06/21/2017. Certification report submitted to NMED on 07/20/2017. RATA performed 03/06/2018. Certification report submitted to NMED on 03/29/2018. RATA performed 03/19/2019. Certification report submitted to NMED on 04/18/2019. I s=s'5eiian acfi:iaffriTffai startlip_a_n_d_s_h_a-ke-d-own [ period on 7/23/03. NOx controls and CEMS ' operational. CEMS RATA and B-8 performance testing done 10/29/03. Test report submitted 12/8/03. Pursuant to 40 CFR 60 App F, annual RATA performed 09/26/2006, 09/13/2007, 09/09/2008, 09/17/2009, 08/24/2010 08/16/2011, 08/15/2012, 08/06/2013, 07/30/2014. : RATA was performed 07/29/2014. Certification I report submitted to NMED on 09/11/2014. : RATA was performed 07/22/2015. Certification report submitted to NMED on 08/20/2015. ;i RATA was performed 07/13/2016. Certification I report submitted to NMED on 08/05/2016. 1 RATA performed 06/21/2017. Certification report : submitted to NMED on 07/20/2017. j RATA performed 03/07/2018. Certification report ! submitted to NMED on 03/29/2018. I RATA performed 03/19/2019. Certification report ............ !...submitted to NMED on 04/18/2019. .......... .................."""'""- g HFNA-000003318 EPA Inspection Report - Page 1769 of 1969 Calendar Quarterly Regort - 2na Quarter 2019 Hol!yFrontier Navajo Refining LLC, Artesia and Lovington Refineries J........................- ......... j...-~--~~q~u~ir~e~m~e~n~t__s______~_ [. 4 Par;fJ~aph .. ~~~~~~~--~~:-~~~~~~.::::~ --~--1 I Install next-generation ultra- j 16.B.i., I H-601 burners installed. Testing conducted on , low NOx control on H-20 and !.. PHe-~o1rma:Ancrteesteia treHf~ne~.nd 11 "' 5 - 20 Cl! H-601. Establish compliance i 16.C.iii., and 3/2/04. Report including proposed compliance I1 Appendix C / indicators and permit limits was submitted 5/14/04. i H-20 burners installed prior to 12/31/05 deadline I and heater resumed operation 12/29/05. indicators by an initial :I H-20 performance test conducted on 02/16/06. performance test . Report submitted to NMED on 03/23/06. Permit I limit proposed in air permit application submitted to i NMED on 4/27/06. NMED issued permit 6/23/06. I ccccccccc=cc_ _ _ _ _""""W 10 HFNA-000003319 EPA Inspection Report - Page 1770 of 1969 Calendar Quarterly Renort - 2nd Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries ~~------------ Requirements CD Status/Comment ss,-..n. "<Pa_r_ag-r_a~p_h-_ _ _ _ _ __ Install next-generation ultra- 16.B.i., Heater H-101 was removed from service low NOx control on H-101 at 16.C.ii., and November 2003. Lovington refinery. Operate Appendix C Navajo installed NGULNBs in the new Crude Oi! CEMS or PEMS on H-101 by 12/31/05. Charge Heater (H-103) that replaced H-101. Installation of H-103 was completed during December 2003 turnaround and began operation after 4th Quarter turnaround. As-installed duty of NGULNBs was < 150 MM Btu/hr, but > 100 MM Btu/hr. H-103 initial testing done 03/04/04. Test report, including proposed parametric monitoring plan and permit limits, was submitted 05/14/04. The permit with new limits was approved on 02/21/2006. In 02/2009, Navajo installed eight additional NGULNBs in the Crude Oil Charge Heater (H-103) that replaced H-101. As-installed duty of NGULNBs was > 150 MM Btu/hr, so a NOx CEMS was installed. An initial performance test and the NO:x: CEMS RATA were conducted 05/21/2009. Pursuant to 40 CFR 60 App F, annual RATA performed 05/20/2010, 08/16/2011, 05/24/2012. RATA was performed 05/14/2013. Certification report submitted to NMED on 06/10/2013. RATA was performed 05/13/2014. Certification report submitted to NMED on 06/12/2014. RATA was performed 05/06/2015. Certification report submitted to NMED on 06/04/2015. RATA was performed 05/04/2016. Certification report submitted to NMED on 06/03/2016. RATA was performed 04/25/2017. Certification report submitted to NMED on 05/16/2017. RATA was performed 02/14/2018. Certification report submitted to NMED on 03/14/2018. RATA was performed 03/05/2019. Certification report submitted to NMED on 04/08/2019. Based on a review, not all QC procedures for heaters and boilers with CEMS may be documented in accordance with 40 CFR 60 App. F. The 4th quarter 2017 Consent Decree progress report inadvertently cross-referenced the entry for Paragraph 11.F. (pertaining to the FCCU) and did not explain that QC procedures for heaters and boilers with CEMS may not have been fully documented. A review of documentation of QC procedures under 40 CFR 60 App F was undertaken. A QA/QC manual was finalized in January 2019. 11 HFNA-000003320 EPA Inspection Report - Page 1771 of 1969 Calendar Quarterly Report- 2nd Quarter 2019 Hol!yFrontier Navajo Refining lLC, Artesia and Lovington Refineries !_____ Requ~:~~::::~~~::::: :::::::::::::::::,.:::::;~!~g~~P.h."'.L Status/Comme~~::::::::::::::::::::::: ... :::::::::::::::::::::"'"'"' Install next-generation ultra- 16.B.i., 1 H-600: Air permit 0195-M25-R3 authorizing the low NO:x: control on H-600 16.C.iii., and I burner retrofit was issued by NMED on 05/14/08. and 70-H1/H2/H3 at Artesia Appendix C The retrofit was completed in 02/2009. The refinery. Performance test H- performance test was conducted 03/04/09 and the 600, and 70-H1/H2/H3. test report submitted 03/30/09. Administrative Establish compliance permit revision 0195-M26-R1 effective 04/14/2009. indicators by 12/31/09. 70-H1/H2/H3: NGULNBs were installed in CCR Heaters 70-H 1/H2/H3 in May 2006 and heaters resumed operation on 6/2/06. Performance test conducted 7/11/06 and test report submitted 8/15/06. An application for a proposed permit limit was submitted to NMED 9/28/06. NMED issued PSD-NM-0195-M25 on 12/14/2007. An air permit application proposing installation low NOx control on B-SG- 16.C.iii., and of NGUlNBs in SG-1101A and SG-11018 was 1101 A and B-SG-1101Bat Appendix C submitted to NMED on 12/21/2007. Permit 0273- Lovington refinery by M? authorizing the retrofit with NGULN8s was 12/31 /09. Conduct issued by NMED on 05/06/2008. Navajo performance test 8-SG- subsequently decided to replace the existing 1101 A and B-SG-1101Band i boilers with new boilers using NGUlNBs. Permit establish compliance 0273-M7-R1 authorizing the replacement boilers indicators. was issued by NMED on 10/14/2009. Boiler SG- 11 OB was permanently shut down on 12/05/2009. Its replacement, B0-1104, began operation on 12/17/2009. Initial performance testing was conducted 01/28/2010 on 80-1104 and the report submitted to NMED on 02/24/2010. Because of initial operating problems with 80-1104, the second boiler, SG-1101A was not permanently shut down until 01/04/2010. Its replacement, B0- 1105, began operation on 01/15/2010. Initial performance testing was conducted 01/26/2010 on B0-1105 and the report submitted to NMED on 2/24/2010. The B0-1105 initial performance test was conducted on 1/26/2010, and the report submitted to the AQB on 02/24/2010. The B0- 1104 initial performance test was conducted on 01/28/2010, and the report submitted to the AQB on 02/24/2010. The burners installed with B0- 1105 and B0-1104, were subsequently found to not meet the NGULN8 performance specification in the Consent Decree. The installation of NGULN8 in 80-1105 was completed 06/20/2013. The installation of B0-1104 NGULNB was completed 07/29/2013. B0-1105 NOx Performance Test was completed 07/12/2013 and the results were submitted to NMED on 08/06/2013. 80-1104 NOx Performance Test was completed 09/04/2013 and the results were submitted to NMED on 12/05/2013. 12 HFNA-000003321 EPA Inspection Report - Page 1772 of 1969 Calendar Quarterly Report - 2nd Quarter 2019 Ho!lyFrontier Navajo Refining lLC, Artesia and Lovington Refineries ;.----R_e_q_u_ir_e_m_e_n_ts--~J....Par~;aph.....I....................::::::::::::::::::::::~::... Status/C::::.nt Submit proposed NOx permit 16.D I Requirement completed. ~ limits within 120 days of NOx .,.,. B-7: Pro.posed B-7 NOx limit submitted to NMED control technology 0 113 1103 installation. B-8: Proposed B-8 NOx limit submitted to NMED 12/8/03. H-601: Proposed H-601 NOx limit submitted 5/14/04 in stack test report and permitted in 195- M17 as issued 12/15/04. H*103 (Lovington Refinery): Proposed H-103 NOx limit submitted 5/14/04 in stack test report; on 2/21/06 NMED issued 0273-M4 to add the NO.x limit After installing additional NGUlNBs in 02/2009, the limits were confirmed in the 05/21/2009 test and included in Permit 0273-M7- ! R1 issued by NMED on 10/14/2009. H-20: Proposed H-20 NOx limit submitted to NMED in air permit application on 04/27/06; permit 0195-M24 issued 06/23/06. 70-H1/H2/H3: Proposed 70-H1/H2/H3 NOx limit submitted to NMED in air permit application on 09/28/06; permit PSD-NM-0195-M25 issued 12/14/2007. H-600: Proposed H-600 NO.x limit authorized by NMED air permit administrative revision effective on 04/14/09. B0-1104 and B0-1105: (replacement boilers for 8-SG-110A and B-SG-1101 B). Proposed 80-1104 and B0-1105 NOx limits submitted to NMED in air permit application on 04/13/201 O; permit 0273-MB issued 07/19/2010. 13 HFNA-000003322 EPA Inspection Report - Page 1773 of 1969 I Submit annual progress report on NOx control technology meries 16.E 1 First report was submitted 12/19/02. The report for 2003 was submitted 12/29/03 with supplemental information provided 1/8/04. 2004 report submitted 12/31/2004. 2005 report submitted 12/31/2005. 2006 report submitted 12/11/2006. 2007 report submitted 12/20/2007. 2008 report submitted 12/19/2008. 2009 report submitted 12/28/2009. 2010 report submitted 12/15/2010. 2011 report submitted 12/31/2011. 2012 report submitted 12/11/2012. 2013 report submitted 12/18/2013. 2014 report submitted 12/19/2014. 2015 report submitted 12/31/2015. 2016 report submitted 12/30/2016 2017 report submitted 12/28/2017. 2018 report submitted 12/27/2018. D. Section V, Paragraph 17: S02 Emissions Reductions from Heaters and Boilers and ...................... f\l.SPS_Applicabilit Requirements CD '"""""" ............................. -- -- Status!Comment NSPS Subparts A and J Para ra h ssssssssss--17.B i Commenced 12/20/01 become applicable to Heaters See entry for Paragraph 16.B.i., 16.C.ii., and and Boilers by Date of Appendix C on p. 12 of this report regarding 40 lodging. CFR 60 App. F QC procedures. --------"-----~- E. Section V, Pc1rc19_r~e!i!; :1.~ and J~~ N~F~APP.li~~l:>ili~yff?.r..~.E ~~I:!~ Flaring Devices. Requirements ......... . CD Status/Comment .....Paragraph I SRP shall comply with NSPS 18.C.i. and I J limit and monitor tail gas 18.C.ii. I emissions by Date of L_Lodging. ccccccccccccc--------- Com meneed 12/20/01. I See entry for Paragraph 11.F. regarding 40 CFR 60 App. F QC procedures. 14 HFNA-000003323 EPA Inspection Report - Page 1774 of 1969 Calendar Quarterly Regort - 2nd Quarter 2019 "' Ho!lyFrontier Navajo Refining LLC, Artesia and Lovington Refineries __________ _ --------"'Requirements________ I CD _________________________ "' Status/Comment J____Parag-r_a~p_h-_ _ _ __ NSPS Subparts A and J Appendix E Commenced 12/20/01. become applicable to Flares by Date of Lodging. The recent implementation of flare monitoring t requirements under NSPS Ja resulted in the identification and repair of several relief valves that were leaking to the flare. In addition, three flare gas streams with higher sulfur levels were identified as routed to the Lovington flare. These I three streams were rerouted to the fuel gas system. As of November 11, 2015, all gas streams currently routed to the flares are monitored for 't compliance with the NSPS Ja requirements. Excess emission information for the flares at Artesia and Lovington for the semiannual period: January-June 2016 was included in Attachment 4 to the 3rd quarter 2016 Consent Decree Progress Report The excess emission information for events occurring during the semiannual period: July-December 2016 was included in the semiannual NSPS monitoring report submitted on January 30, 2017, and was attached to the 1st quarter 2017 Consent Decree Progress Report. Excess emission information for events occurring during the semiannual period: January-June 2017 was included in the semiannual NSPS Ja monitoring report submitted on July 28, 2017, and was attached to the 3rd quarter Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: July-December 2017 was included in the semiannual NSPS monitoring report submitted on January 30, 2018, and was attached to the 1st quarter 2018 Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: January- June 2018 was included in the semiannual NSPS monitoring report submitted on July 30, 2018, and was attached to the 3rd quarter 2018 Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: July- December 2018 was included in the NSPS monitoring report submitted on January 30, 2019, and was attached to the 1st quarter Consent Decree Progress Report. 1mit AMP plan for Flares FL-400, Fl-401, FL-402 and FL-403 within 90 days of Lodging Date. Appendix E Submitted 3/19/02. 15 HFNA-000003324 EPA Inspection Report - Page 1775 of 1969 Calendar Quarterly Regort - 2nd Quarter 2019 Ho!lyFrontier Navajo Refining LLC, Artesia and Lovington Refineries --------------------------------------------------- Requirements NSPS Subparts A and J ! become applicable to Flare FL-1001 at Lovington refinery on 12/31/06. Submit AMP plan for Flare FL-1001 at Lovington refinery by_7/30/07. ... -------------, : Submit enhanced I Maintenance and Operation ! plan for SRP (PMO plan) i within 270 days of Date of APpaprae.ngdraixphE Off-Gas Sc CD -r-ub be--r-~s~y:s~t~e-m:-~f~ocrnsnw::e::e~t:_e__::n::i:n:g::"s"-o--u--r LPG] before combusting in flare completed by 12/31/06. ............................................ ------""""""""""" ---- --------------- ------i Appendix E An approvable AMP was submitted 02/14/07. AMP is pending EPA approval. 18.D ...................................... ---------------~................,,,................ --------------~ Plan submitted on 9/16/02 and updated on i 03/24/05. The !ast revision was completed on 09/2017 [Lodging._____ --------------------------------~----~- ! Begin optimization study on 18.E ! Study commenced by 1/1/04 deadline. i:-~~~::u~~~~e'~~~~~: I SRP by 1/1/04. i------j Complete optimization study ! on SRP and report results by i 12/31/04. i i shutdowns affecting 18.E 19.E - ~ - - . , , . ,.... i Navajo retained a third party to coordinate performance testing for the optimization study and , prepare a report which was submitted to EPA on 1 12/31/04. Commenced 12/20/01. ----------------------! ! Lovington refinery by Date of lodging. '""" ------------------------------ c.,,,,. .,,,,,,....... ---------- F. Section V, Paragraphs 20 and 21: Control of Acid Gas Flaring, Tail Gas Incidents and Hydrocarbon Flaring ------------------------------------------------------ -----------------'------------------ Requirements CD Status/Comment Paragraph (--------.;------ Perform root cause analyses 20 Commenced 12/20/01, for acid gas and tail gas incidents beginning on -~edging Date. Perform root cause analyses ... :ir-~ '"com"menced 12126R51: ---------------------------------< for hydrocarbon flaring incidents beginning on Lodging Date. ------- -----------------~-------------,--............, ......... . G. Section V, Paragraph 22: Benzene Waste NESHAP t -------------------------------------~.--9_...JJ__________ _ Requirements ---------r-~:;~~=-~- Status/Comment ---------------------------- I 16 HFNA-000003325 EPA Inspection Report - Page 1776 of 1969 Calendar Quarter!, R HollyFrontier Navajo rt - 2110 Quarter 2019 ing LLC, Artesia and Lovington Refineries ..................................................................................................................." " " " ' ~ - - - - ~ Requirements CD Status/Comment Pa h !1 review and verification of the !.Complete Phase Oneofthe----"" 22.CJ. Completed 09/11/02. i TAB by 9/16/02. !,-,- - - - - - - ~ - - - - - - - - + - - - - - - - - - - - .......................................................................i I Submit BWN Phase One 22.CJ. Report of results submitted on 10/09/02. I Compliance Review and Verification report for EPA approval by 10/16/02. 1 Submit amended TAB report , 22.D.i. Amended TAB report waS included in the 10/09/02 if BWN Compliance Review !,,,,,. shows reporting applied. . submittal. Establish annual review program 22.E [ Completed as part of Phase One review and is 1 now ongoing. ~-) Train employees who conduct ' sampling. ............................................... 22.G and 22, M.iLa(1) ......................................... . A training plan was developecFon 12/06/62 for the Artesia Refinery (Le., since its TAB is greater than 1.0 Mg/yr). The first training session was held 01/07/03 at both the Artesia and Lovington refineries. The second training session for the two refineries was held 1/27/04 and 01/28/04. Annual refresher training for the two refineries was performed the weeks of 02/08/05, 03/27/06, 03/05/07, 02/25/08 (lov), 11/07/08 (Art), 12/18/09, 12/17/1 Oand 12/20/2011. BWON TAB training was conducted on at the Artesia and Lovington refineries on 11/08/2012 01/14/2013 and 04/18/2013, 11 /12 to 11/14/2013, 05/24/2014, 06/22/2014, 12/12/2014, 3/16/2015, 4/1/2015, 5/15/2015, 2/29/2016, 3/8/2016, 3/17/2016, 09/25/2017, 11/08/2018, and 11/12/2018. ! Submit schematics of Waste/Slop/Off-Spec Oil ! Management by 03/20/02. 22.H.L ! Submitted on 03/19/02. Revised schematics reflecting NSPS QQQ were submitted 04/29/04. Schematics are awaiting approval by EPA. Conduct annual sampling of waste streams which the BWN Compliance Review and Verification Report showed to be 0.05 Mg/yr or greater. 22.J.i. and 22.MJi.a(2) The annual sampling was performed in February 2005. The results were in Attachment 4 to the first quarter 2005 report. Annual sampling performed in February 2006. The results were in Attachment 4 of the first quarter 2006 report. Annual sampling was performed in September and December 2007. The results were submitted in attachment 4 of the first quarter 2008 report as I required by ~22.M.ii.a(2). Annual sampling was performed in December 2008. The results were in attachment 4 of the first i quarter 2009 report as required by 'If22.M.!La(2). Annual sampling was performed in December 2009. The results were submitted in attachment 4 ........................ ........... ......of.thefirstquarter..2010 report. as..require_d_b'"""y_ ____, 17 HFNA-000003326 EPA Inspection Report - Page 1777 of 1969 Calendar Quarterly Reeort- 2nd Quarter 2019 HollyFrontier Navajo Refining lLC, Artesia and Lovington Refineries Requirements """""""""1...Par~g~aph.....1...........................................................St~~~~.~~::~:~: -- ::::::::::::::::::::::::::::::: J ,I22.M.ii.a(2). I Annual sampling was performed in December 2010. The results were in attachment 4 of the first quarter 2011 report as required by ,I22.M.ii.a(2). Annual sampling was performed in December 2011. The results are ln Attachment 4 of the first quarter 2012 report as required by ,I22.M.ii.a(2). Annual sampling was performed in December 2012. The results were submitted in Attachment 4 of the first quarter 2013 report as required by 1f22.M.ii.a(2). Annual sampling was performed in December 2013. The results were submitted in Attachment 4 of the first quarter 2014 report as required by 1f22.M.ii.a(2). Annual sampling was performed in December 2014. The results were submitted in Attachment 4 of the 1st quarter 2015 report as required by ,T22.M.ii.a(2). Annual sampling was performed in December 2015. The results were included in Attachment 4 of the 1st quarter 2016 report as required by ,T22.M.ii.a(2). Annual sampling was performed in October 2016. The results were included in Attachment 4 of the 1st quarter 2017 report as required by 1f22.M.ii.a(2). Annual sampling was performed in December 2017. The results were included in Attachment 4 and 7 of the 1st quarter 2018 report as required by ,r22.M.ii.a(2). ' Annual sampling was performed in December 2018. The results were included in the 1st quarter ....... """""""""""""""""'""'':?g_:t9 report as required,J?yj}g?.:.M:Ji.:..:1.f.?1........ : Meet with NMEoancrEPA at 22.J.ii ' Navajo was notified by NMED and EPA via email the refinery and submit an dated 12/9/02 that the ,I22.J.li visit by the agencies annual end of line (EOl) would not occur. Navajo met the deadline by sampling plan - applicable to submitting the EOl sampling plan on 2/6/03. Artesia Refinery (i.e., TAB is Conditional approval of the plan was received from equal to or greater than 1 EPA by letter dated 1/23/04. Navajo responded by Mg/yr but less than 10 Mg/yr). submitting a revised EOL sampling plan by letter dated 3/31 /04. ~ ~ ~ - - - - - - - - - - ~ - - - - - - - - - - - - - - - ~ ' " " ssssssss""'~ 18 HFNA-000003327 EPA Inspection Report - Page 1778 of 1969 Calendar Quarterl;t; f.<eport- 2nd Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries '""-'"""~------------- Requirements CD Paragraph Conduct quarterly EOL 22.J.m. and sampling and submit the 22.M.il.a(3) : results to EPA in quarterly ! report. ssssooss,"--~~~~~~~~~~~~~~~~~~~~~~~~~~..w. .sssss Status/Comment These requirements are not applicable until EPA approves the sampling plan. Although EPA has not approved or commented on the revised sampling plan submitted 03/31/2004, Navajo conducted its first EOl sampling during the week of 3/22/2004. The EOl benzene quantity (BQ) for the fourth quarter of 2004 was 0.8 Mg (projected annual< 10 Mg). The annual TAB, submitted 4/05 was 4.9 Mg for Artesia and 1.5 Mg for Lovington. The 1st, 2nd, 3rd, and 4th quarter 2005 EOl BQs were each <2.5 Mg. The 1st, 2nd, 3ra, and 4th quarter 2006 EOL BQs were each <2.5 Mg. The Pt, 2nd, and 3rd quarter 2007 EOL BQs were each <2.5 Mg. The 4th quarter 2007 EOl BQ result was greater than 2.5 Mg, but the projected 2007 TAB was < 10 Mg. The 1st quarter 2008 EOL BQ result was less than 2.5 Mg. The 2nd and 3rd quarter 2008 EOL BQ results were both greater than 2.5 Mg. The EOl BQ for the 4th quarter of 2008 was <2.5 Mg and the projected 2008 TAB was <10 Mg/yr. The EOL BQ for the 1st, 2nd, 3rd and 4th quarters of 2009 was <2.5 Mg and the projected 2009 TAB was <10 Mg/yr. The EOL BQ for the 1st, 2nd, 3rd, and 4th quarters of 2010 was <2.5 Mg and the projected 2010 TAB was < 10 Mg/yr. The EOl BQ for the 1st, 2nd, 3rd and 4th quarters of 2011 was <2.5 Mg and the projected 2011 TAB was <10 Mg/yr. The EOL BQ for the 1st, 2nd, 3rd and 4th quarters of 2012 were each <2.5 Mg and the projected 2012 TAB was <10 Mg/yr. The EOL BQ for the 1st, 2nd, 3rd, and 4th quarters of 2013 were each <2.5 Mg and the projected 2013 TAB was <10 Mg/yr. The projected 2013 TAB was < 10 Mg/yr. The EOL BQ for the 1st, 2nd, 3rd, and 4th quarters of 2014 were each <2.5 Mg and the projected 2014 TAB was <10 Mg/yr. The EOl BQ for the 1st, 2nd, 3rd, and 4th quarters of 2015 were <2.5 Mg and the projected TAB for 2015 was <10 Mg/yr. .............................................................1.... ii The EOL BQ for the 1st quarter of 2016 was <2.5 , Mg and the projected TAB for 2016 was <10 Mg/yr. I The EOl BQ for the 2nd quarter of 2016 was <2.5 i Mg and the projected TAB for 2016 was <10 Mg/yr. I The EOL BQ for the 3rd quarter of 2016 exceeded I 2.5 Mg. As required by paragraph 22.J.iv, Navajo ...L~.!:J.Q.f!!ili:~SL<:1J2clan with the fourth quarter 9.2r:'.l3.~Qt..........., 19 HFNA-000003328 EPA Inspection Report - Page 1779 of 1969 Calendar Quarterl't Reeort- 2nct Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries ~=~t:~e:n~~~:ar~i:~i~!1J~=~~~:t~~ Re.qi:ifreme.nts cc . ... ............................................statusicomment 1 ..............................- - . l'~~jj~~!i j to i ensure that the TAB does not exceed 10 Mg in the ! calendar year. ' The EOL BQ for the 4th quarter of 2016 was <2.5 Mg and the projected TAB for 2016 was <10 Mg/yr. I The EOL BQ for the 1st quarter of 2017 was <2.5 i i Mg and the projected TAB for 2017 was <10 Mg/yr. j The EOL BQ for the 2nd quarter of 2017 was <2.5 I Mg and the projected TAB for 2017 was <10 Mg/yr. I The EOL BQ for the 3rd quarter of 2017 was <2.5 I Mg and the projected TAB for 2017 was <10 Mg/yr. I The EOL BQ for the 4th quarter of 2017 was <2.5 : I Mg and the projected TAB for 2017 was <10 Mg/yr. i I The EOL BQ for the 1st quarter of 2018 was <2.5 I I Mg and the projected TAB for 2018 was <10 Mg/yr. I I The EOL BQ for the 2nd quarter of 2018 was <2.5 i Mg and the projected TAB for 2018 was <10 Mg/yr. The EOL BQ for the 3rd quarter of 2018 was <2.5 I Mg and the projected TAB for 2018 was <10 Mg/yr. I The EOL BQ for the 4th quarter of 2018 was <2.5 1 Mg and the projected TAB for 2018 was <10 Mg/yr. The EOL BQ for the 1st quarter of 2019 was <2.5 ~~ea~~t:6~~~~~:d2~~~:~e~~~ ~~~r. : ~;1a:;;~ I Mg and the projected TAB for 2019 was <10 Mg/yr. ......l ........"""""""""""""""""""""'""""""-"='"" ..,....Ms .... . r H. Section V,Para~aph23: LDAR ' Requirements CD Status/Comment Paragraph _ _ ,___, -,--------~----~----------------"""""""''' 1 Develop and maintain written 23.A I Completed before 4/19/02. I i facility-wide LOAR i i compliance program by I i 04/19/02. i l .............................................................................................................J................................................., ..................................................................................................................,......" ...." " " - " " - - - i LOAR Training within 1 year ' 23.B , Newly assigned personnel (both 3rd party and i of Date of Lodging. Navajo) are receiving training. On going training i programs have been implemented. I Perform initial LOAR 3rd party/internal audits by 12/20/02 and correct deficiencies. Repeat audits every two years. 23.C and 23.D 3rd party audits for Artesia and Lovington were conducted on 10/2002 and deficiencies were corrected per Paragraph 23.D. 3rd party audits for Artesia and Lovington were performed during 12/2004, 01/2007, 01/2009, and 01/2011. The Artesia and Lovington refineries underwent maintenance turnaround from January to March, 2013. The 2013 LOAR 3rd __artyaudit_was.... 20 HFNA-000003329 EPA Inspection Report - Page 1780 of 1969 Calendar guarterl't Re2ort - 2nd Quarter 2019 HollyFrontier Navajo Refining llC, Artesia and Lovington Refineries Requirements ----------i-----------ss~ CD I Status/Comment -------------------------------------1 Paragraph I ''""""""""""""' """'''''''""" ..............................................................." " " " " " " " " " " " " k " " " " " " " " " " " " " " " " ' " - - - - - - - conducted from 09/16 to 09/20/2013, after the refinery was back online and normal operation data had been collected for 1 complete quarter for comparative monitoring. A copy of the 2013 LOAR 3rd party audit report and resolutions were submitted in Attachment 5 of the 1st Quarter 2014 report. 3rd party audits for Artesia and Lovington were performed during the week of October 5th to I 9th, 2015. A copy of the 2015 LOAR 3rd party audit i report and resolutions are included in Attachment 5 I of the 1st Quarter 2016 report. . The 2017 LOAR 3rd party audit was conducted from I, 05/17 to 05/18/2017. A copy of the audit report I was attached to the 3rd Quarter 2017 Consent J Decree Progress Report. The audit resolutions Iwere included as Attachment 5 to the 1st Quarter i 2018 report. I The 2019 LOAR 3rd party audit was conducted from 1t---V- alves use 500 ppm leak I definition by 2 years after j 1~;~i~~E~~~~GG ~:~~~=~~:;~~~~~r ~nFCCU 12/31/03. 23.E.i. 23.E.iii 04/29 to 05/03/2019. ""'""""""""""""""""""""""" Completed prior to 12/20/03. -------------------------------------------------------------------------------------------~ Compressor seal system was upgraded during 2003 FCCU turnaround. Operational beginning December 2003. Pump monitoring using 23.E.ii.a., b., List of pumps comprising >85% was developed internal leak definition of and c. and these pumps are using the 2,000 ppm leak 2,000 ppm in accordance with definition for all monitoring subsequent to 12/20/03. phased-in schedule - i.e., All pump monitoring using internal leak definition of 50% by 6/20/03, 85% by 2,000 ppm after 4/20/05. 12/20/03, and 100% by 4/20/05 NSPS Subpart GGG 23.E.iii This was completed upon CD lodging. Crude Vent I becomes applicable to Crude Compressor (C-150A/B) is now included in the I vent compressor at Lovington LOAR monitoring program. refinery as of Date of l___lodging .___ -------------------------------ssssss-.---""""""""'"I,""""""'" First attempt at repairs on 23.G valves that have voe reading Commenced with January 2002 quarterly monitoring. I > 200 ppm within 90 days of .._lodging __Date.__________________________________________________________._____________________________________ ccccccccccc------- Quarterly monitoring of valves 23.H.ii. Completed by 12/20/01. - no Skip Period by Date of l lodgin~;. ____WWW __ LDAR database to include date, time, operator, and 23.1.i. """""""""""""""""'"""""""""---'''" Commenced with May 2002 monitoring. instrument within 6 months of I __Date__of__Lodging...__ -------------------------------------..--.1...- - - - ~ - - - 21 HFNA-000003330 EPA Inspection Report - Page 1781 of 1969 Calendar Quarterly Re2ort - 2nd Quarter 2019 Hoi!yFrontier Navajo Refining lLC, Artesia and Lovington Refineries Requirements Pa;;g';..ph I - ~/Comment Submit operational 23.1.ii., and Submitted 6/19/02. specifications designed to 23.0.i.b. m!n!mize non-electronic data collection and transfer within 6 months of Date of _Lodgin;g Develop/ implement 23:J Procedure developed on 3119102 and includec:fa~ i procedure for LOAR data an appendix in the written LOAR program. J QA/QC within 90 days of LLodging,_Date.....................- ....- .........._ E~~;~~ ::_I__:~ I 1a~;a~~~:e _,,__ _ _ _- + - - - - - - - - - - - -........................................................................ i Completed by 12120101. I l~~S'.~~l3.L l -~~~~~~02ana1s [ Conduct calibration/drift 23.M I assessments of monitoring i instruments at the end of 1 ! each shift by the Date of I ~0 o~;i';~~ingeni'defay..of're.pafr .. 1..... 23.N:iL i requirements including drill II. i and tap for valves reading I >10,000 ppm by Date of l.. L : lodging. 1 <-----------,,i,,~, ! Submit written facility-wide ! 23.0.i.a. ~~~~~~~-~.li~nce progra: i Submit LDAR report with 23. O.ii.c. MACT Periodic reports. Commenced on 12/20/01. 1Commenced on 12)26701. ss""_ __ I Submitted 05/13/2002. The monitoring results were incorporated into the periodic reports submitted pursuant to 40 CFR 63.654 on: 3/15/02, 9/13/02, 3/15/03, 9/15/03, 3/15/04, 9/15/04, 3/14/05 (3/15/05 for Lovington), 9/13/05 (9/15/05 for Lovington), 3/17/06, 9/13/06 (9/06/06 for Lovington), 3/16/07, 09/14/07, 3/17/08, 9/12/08, 03/16/09, 08/27/09, 03/16/2010, 09/13/2010, 03/16/2011, 03/09/2012 and 09/06/2012 (09/06/2012 for Lovington), 03/15/2013, 09/16/2013, 02/25/2014 (Artesia), 08/26/2014 (Lovington), 02/26/2015 (Artesia and Lovington), 08/27/2015 (Artesia and Lovington), 02/18/2016 (Artesia and Lovington), 08/29/2016 (Artesia and Lovington), 02/28/2017 (Artesia and Lovington), 08/29/2017 (Artesia and Lovington), 08/30/2018 (Artesia and Lovington), and 02/28/2019 (Artesia and Lovington). ..........................................................................................................,.., - - 22 HFNA-000003331 EPA Inspection Report - Page 1782 of 1969 Calendar Quarterly Report - 2n Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries I. S~~:~~:~::;:graph 24:Jnc~gorate[CD__Requiremen~t~~~~/~~:~:~~le"Permits 1,---------------------------------------------------------------------------------------I"'Par-a----graph I -----------------------------------------------------------"""---"--------------"-----------------------------------""""""..............__ : Within 180 days of Date of 24.A Applications to revise the NSR permits for the I Lodging, submit an j application for Federally I Artesia and Lovington refineries were submitted i 5/28/02. Permit revision issued for Lovington on : enforceable NSR permit to I incorporate of limits, I standards, or schedules I effective on the Date of 10/15/03. Permit revision for Artesia issued 12/15/04. !...Lodging ..... II Submit applications within 30 ---~-------------~----------------------------------------------------------< 24.B : Navajo's understanding is that ,I16 NOx limits for . days of the effective date or I establishment of limits, I boilers and heaters, which require permit 1 I application filing within 120 days after start-up II I standards, or schedules .pursuant to the CD. " ""........ : under ,I16.D, are not subject to 1[24.B. No other limits under Section V have occurred__to.date._____J 5::~:;;::b~ ~ RequirementC;~:::~mmem Section V, Paragraph 25: --------------------ssssssss~nnnnn-- Obtaining Construction Permits ~ UtiUze construction permits to ~h implement control projects I The 5/28/02 NSR permit revision application for the required by the CD. :~~s~a~=~i~~z;~;'~~~=~ted the installation of the Navajo submitted an application to NMED on ! 4/9/03 to install a new crude heater (H-103) at the Lovington refinery. The permit was issued II 10/15/03. H-103 began operation in 12/03. Since heater H-103 replaced H-101 (i.e., the existing crude heater which requires burner retrofit by 12/05 II under the CD) and uses NGULNBs, this effectively II achieves early implementation of the NOx emission reductions sought by the CD. In order to retrofit heater H-20 with NGULNB by 12/31 /05, Navajo submitted a significant revision air permit application to NMED on 04/12/05. Since 11 NMED had not completed the application review, a waiver allowing limited construction activities to begin was granted on 10/11/05. Permit Oi95-M21, authorizing NGUlNB for H-20, was issued by NMEDon 11/18/05. II An air permit application proposing the installation .........................1..9.LN.G.l:J.b.N~!:;JIJ ~9~J1Q_m:>rmerly SG-11 O1A) am:l 23 HFNA-000003332 EPA Inspection Report - Page 1783 of 1969 rt - 2nd Quarter 2019 g LlC, Artesia and Lovington Refineries '''''"' ' R t \ CD ,................................::.~.1.~:.::."-s--..............J.....~.~~~graph I I Status/Comment B0-1104 (formerly SG-1101 B) was submitted to NMED on 12/21/2007. Permit 0273-M? authorizing the NGULNBs in SG-1101A and SG-1101 B was issued by NMED on 05/06/2008. Navajo subsequently decided to replace the existing boilers with new boilers using NGUlNBs. Permit 0273-M7-R1 authorizing the replacement boilers was issued by NMED on 10/14/2009. The installation of NGULNB in B0-1105 was completed 06/20/2013. The installation of B0-1104 NGULNB was completed 07/29/2013. H-600: Air permit 0195-M25-R3 authorizing the burner retrofit was issued by NMED on 05/14/08. The retrofit was in 02/2009. 3.0 SUMMARY OF ANTICIPATED PROBLEMS IN IMPLEMENTING THE REQUIREMENTS OF SECTION V. None at this time. 4.0 SUMMARY Of EMISSIONS DATA The Boiler B-7 initial performance stack test and CEMS RATA was conducted on 12/18/2002 and the results submitted to the NMED on 01/31/2003. The Boiler B-8 initial performance stack test and CEMS RATA was conducted on 10/29/2003 and the results submitted to the NMED on 12/08/2003. The Heater H-601 initial performance stack test was conducted on 03/02/2004 and the results were submitted to the NMED on 05/14/2004. The Heater H-103 (replacement for H-101) initial performance stack test was conducted on 03/04/2004 and the results were submitted to the NMED on 05/14/2004. Data was collected for reporting pursuant to Paragraph 11 (e.g., FCCU NOx optimization and demonstration period data.) NOx Additive Demonstration Period report with proposed NOx concentration-based limits submitted 07/27/2006. The FCCU Regenerator Scrubber_CEMS RATA was conducted on February 14 and 15, 2006 and the results were submitted to the NMED on 03/15/2006. The FCCU Regenerator Scrubber annual PM test was conducted on 02/15/2006 and the results were submitted to the NMED on 03/15/2006. Heater H-20 was retrofit with NGULNBs in December 2005. A performance stack test was conducted on 02/16/2006 and the results were submitted to the NMED on 03/23/2006. Heaters H-352, H-353, and H-354 (formerly identified as 70-H1/H2/H3) were retrofit with NGULNBs in June 2006. A performance stack test was conducted on 07/11/2006 and the results were submitted to the NMED on 08/15/2006. The Boiler B-7and Boller B-8 annual CEMS RATAs were conducted on 09/26/2006 and the results submitted to the NMED on 10/17/2006. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/24/2007 and the results were submitted to the NMED on 02/22/2007, 24 HFNA-000003333 EPA Inspection Report - Page 1784 of 1969 Calendar Quarterlz' Re2ort - 2nd Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries The FCCU Regenerator Scrubber annual PM test was conducted on 01/24/2007 and the results were submitted to the NMED on 02/22/2007. The Heater H-20 annual performance stack test was conducted on 01/25/2007 and the results were submitted to the NMED on 02/22/2007. The Boiler B-7and Boiler B-8 annual CEMS RATAs were conducted on 09/13/2007 and 09/12/2007 respectively, and the results submitted to the NMED on 10/11/2007. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/22/2008 and the results were submitted to the NMED on 02/18/2008. The FCCU Regenerator Scrubber annual PM test was conducted on 01/22/2008 and the results were submitted to the NMED on 02/18/2008. The Heater H-20 annual performance stack test was conducted on 01/23/2008 and the results were submitted to the NMED on 02/18/2008. The Boiler B-7and Boiler B-8 annual GEMS RATAs were conducted on 09/09/2008 and the results submitted to the NMED on 10/09/2008. The FCCU Regenerator Scrubber GEMS RATA was conducted on 03/03/2009 and the results were submitted to the NMED on 03/30/2009. The FCCU Regenerator Scrubber annual PM test was conducted on 03/03/2009 and the results were submitted to the NMED on 03/30/2009. Heater H-600 was retrofit with NGULNBs in 02/2009. The Heater H-600 initial performance stack test was conducted on 03/04/2009 and the results were submitted to the NMED on 03/30/2009. The Heater H-20 annual performance stack test was conducted on 03/05/2009 and the results were submitted to the NMED on 03/30/2009. After adding additional burners, the Heater H-103 (replacement for H-101) performance stack test and NOx GEMS RATA was conducted on 05/21/2009 and the results were submitted to the NMED on 06/22/2009. The Boiler B-7and Boiler B-8 annual CEMS RATAs were conducted on 09/17/2009 and the results submitted to the NMED on 10/14/2009. The B0-1105 (replacement boiler for Lovington boiler 8SG-1101A) initial performance testing was conducted 01/26/2010 and the report submitted to NMED on 02/24/2010. The B0-1104 (replacement boiler for Lovington boiler BSG-1101 B) initial performance testing was conducted 01/28/2010 and the report submitted to NMED on 02/24/2010. The FCCU Regenerator Scrubber GEMS RATA was conducted on 03/02 and 03/2010 and the results were submitted to the NMED on 04/05/2010. The FCCU Regenerator Scrubber annual PM test was conducted on 03/02 and 03/2010 and the results were submitted to the NMED on 04/05/2010. The Heater H-20 annual performance stack test was conducted on 03/04/2010 and the results were submitted to the NMED on 04/05/2010. The Heater H-103 {replacement for H-101) NOx GEMS RATA was conducted on 05/19/2010 and 05/20/2010, and the results were submitted to the NMED on 06/16/2010. The Boiler B-7and Boiler B-8 annual GEMS RATAs were conducted on 08/24/2010 and the results submitted to the NMED on 09/14/2010. The FCCU Regenerator Scrubber CEMS RATA was conducted on 03/01/2011 and the results were submitted to the NMED on 03/28/2011. The FCCU Regenerator Scrubber annual PM test was conducted on 03/01/2011 and the results were submitted to the NMED on 03/28/2011. The Heater H-20 annual performance stack test was conducted on 03/02/2011 and the results were submitted to the NMED on 03/28/2011. 25 HFNA-000003334 EPA Inspection Report - Page 1785 of 1969 Calendar Quarterly Report - 2nd Quarter 2019 Hol!yFrontier Navajo Refining llC, Artesia and Lovington Refineries The Boiler B-7and Boiler B-8 annual GEMS RATA's were conducted on 08/16/2011 and the results submitted to the NMED on 09/16/2011. The Heater H-103 (replacement for H-101) NOx GEMS RATA was conducted on 05/3/2011 and the results were submitted to the NMED on 05/31/2011. The Heater H-20 annual performance stack test was conducted on 01/19/2012 and the results were submitted to the NMED on 02/27/2012. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/17/2012. Report showing certification submitted to NMED on 02/17/2012. The FCCU Regenerator Scrubber annual PM test was conducted on 01/17/2012. Report showing certification submitted to NMED on 02/17/2012. The Heater H-103 (replacement for H-101) NOx CEMS RATA was conducted on 05/24/2012, and the results were submitted to the NMED on 06/20/2012. The Boiler B-7and Boiler B-8 annual CEMS RATA's were conducted on 08/15/2012 and the results submitted to the NMED on 09/13/2012. The Heater H-20 annual performance stack test was conducted on 01/09/2013 and the results were submitted to the NMED on 02/07/2013. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/08/2013. Report showing certification submitted to NMED on 02/07/2013. The FCCU Regenerator Scrubber annual PM test was conducted on 01/08/2013. Report showing certification submitted to NMED on 02/07/2013. The Heater H-103 (replacement for H-101) NOx and CO GEMS RATA was conducted on 05/14/2013, and the results were submitted to the NMED on 06/10/2013. The FCCU Regenerator Scrubber annual PM was retested on 03/05/2013. Report showing certification submitted to NMED on 04/01/2013. The Boiler B-7annual CEMS RATA's was conducted on 08/07/2013 and the results submitted to the NMED on 09/17/2013. The Boiler B-8 annual GEMS RATA's was conducted on 08/06/2013 and the results submitted to the NMED on 09/17/2013. The Heater H-20 annual performance stack test was conducted on 01/09/2014 and the results were submitted to the NMED on 02/04/2014. The FCCU Regenerator Scrubber annual PM was tested on 01/08/2014. Report showing certification submitted to NMED on 02/04/2014. The FCGU Regenerator Scrubber CEMS RATA was conducted on 01/08/2014. Report showing certification submitted to NMED on 02/04/2014. After the installation of NGULNB was completed, the B0-1105 (replacement boiler for Lovington boiler BSG-1101A) initial performance testing was conducted 07/12/2013 and the report submitted to NMED on 08/06/2013. After the installation of NGULNB was completed, the 80-1104 (replacement boiler for Lovington boiler BSG-1101 B) initial performance testing was conducted 09/04/2013 and the report submitted to NMED on 12/05/2013. The Heater H-103 (replacement for H-101) NOx and CO CEMS RATAwas conducted on 05/13/2014, and the results were submitted to the NMED on 06/12/2014. The Boiler B-7annual CEMS RATA's was conducted on 07/30/2014 and the results submitted to the NMED on 09/11/2014. The Boiler B-8 annual CEMS RATA's was conducted on 07/29/2014 and the results submitted to the NMED on 09/11/2014. The Heater H-20 annual performance stack test was conducted on 02/17/2015 and the results were submitted to the NMED on 03/09/2015. The FCCU Regenerator Scrubber annual PM was tested on 01/06/2015. Report showing certification submitted to NMED on 02/05/2015. 26 HFNA-000003335 EPA Inspection Report - Page 1786 of 1969 Calendar Quarter!J: Re.gprt - 2nd Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/06/2015. Report showing certification submitted to NMED on 02/05/2015. The Heater H-103 (replacement for H-101) NOx and CO CEMS RATA was conducted on 05/06/2015, and the results were submitted to the NMED on 06/04/2015. The Boiler B-7 annual CEMS RATA's was conducted on 07/23/2015 and the results submitted to the NMED on 08/20/2015. The Boiler B-8 annual CEMS RATA's was conducted on 07/22/2015 and the results submitted to the NMED on 08/20/2015. The Heater H-20 annual performance stack test was conducted on 01/07/2016 and the results were submitted to the NMED on 02/05/2016. The FCCU Regenerator Scrubber annual PM was tested on 01/05/2016. Report showing certification submitted to NMED on 02/04/2016. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/05/2016. Report showing certification submitted to NMED on 02/04/2016. The Heater H-103 (replacement for H-101) NOx and CO CEMS RATAwas conducted on 05/04/2016, and the results were submitted to the NMED on 06/03/2016. The Boiler B-7 annual CEMS RATA's was conducted on 07/13/2016 and the results submitted to the NMED on 08/05/2016. The Boiler B-8 annual CEMS RATA's was conducted on 07/13/2016 and the results submitted to the NMED on 08/05/2016. The Heater H-20 annual performance stack test was conducted on 01/05/2017 and the results were submitted to the NMED on 02/03/2017. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/03/2017. Report showing certification submitted to NMED on 02/03/2017. The FCCU Regenerator Scrubber annual PM was conducted on 01/03/2017. Report showing certification submitted to NMED on 02/04/2017. The Boiler B-7 annual CEMS RATA's was conducted on 06/21/2017 and the results submitted to the NMED on 06/20/2017. The Boiler B-8 annual CEMS RATA's was conducted on 06/21/2017 and the results submitted to the NMED on 06/20/2017. The Heater H-103 (replacement for H-101) NOx and CO CEMS RATA was conducted on 04/25/2017, and the results were submitted to the NMED on 05/16/2017. The Heater H-20 annual performance stack test was conducted on 01/11/2018 and the results were submitted to the NMED on 02/09/2018. The FCCU Regenerator Scrubber CEMS RATA was conducted on 01/09/2018. Report showing certification submitted to NMED on 02/09/2018. The FCCU Regenerator Scrubber annual PM stack test was conducted on 01/09/2018. Report showing certification submitted to NMED on 02/09/2018. The Boiler B-7 annual CEMS RATA's was conducted on 03/06/2018 and the results submitted to the NMED on 03/29/2018. The Boiler B-8 annual CEMS RATA's was conducted on 03/07/2018 and the results submitted to the NMED on 03/29/2018. The Heater H-103 (replacement for H-101) NOx and CO CEMS RATA was conducted on 02/14/2018, and the results were submitted to the NMED on 03/14/2018.The Heater H-20 annual performance stack test was conducted on 02/20/2019 and the results were submitted to the NMED on 03/21/2019. The FCCU Regenerator Scrubber CEMS RATA was conducted on 02/13/2019. Report showing certification submitted to NMED on 03/23/2019. The FCCU Regenerator Scrubber annual PM stack test was conducted on 02/13/2019. Report showing certification submitted to NMED on 03/23/2019. 27 HFNA-000003336 EPA Inspection Report - Page 1787 of 1969 Calendar Quarterlv Report - 2nd~Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries The Boiler B-7 annual CEMS RATA's was conducted on 03/19/2019 and the results were submitted to the NMED on 04/18/2019. The Boiler B-8 annual CEMS RATA's was conducted on 03/19/2019 and the results were submitted to the NMED on 04/18/2019. The Heater H-103 (replacement for H-101) NOx and CO CEMS RATA was conducted on 03/05/2019, and the results were submitted to the NMED on 04/08/2019. Consistent with past reports, any emissions excursions from Consent Decree limits have generally been reported to NMED pursuant to the NSPS, MACT and/or Title V programs semiannually (as well as pursuant to NMED's excess emissions reporting program). We are in this report identifying emissions excursions that occurred in the 2nd quarter 2019 for the emission limits and units below. For the flares at Artesia and Lovington, excess emission information for events occurring during the semiannual period: January-June 2019 will be reported in the semiannual NSPS Ja monitoring report due on July 30, 2019, and will be attached to the 3ra quarter 2019 Consent Decree Progress Report. Consent Decree Condition V.18.B: SRU S02 Emission limits SRU-2 [ S02 250 ppm 12-hr average ssss,~nn~nn,n=n-nf Start Time 2019-04-03 10:00 2019-06-14 22:00 2019-06-17 21:00 End Time ---------------------------------------------.----- 2QJl~94J.>~ ?Q:qq 2019-06-15 23:00 2019-06-18 09:00 Excess Emissions per Event {IIJ.ts.2 ......................- - . 1 0 . 9 5 c c c c c c c c c c c c c c c - - - - - - J 25.27 12.16 5. Implementation of ENVIRONMENTAllY beneficial Projects [Changes from Prior Quarter Italicized] Paragraph 35 requires certain information to be submitted for each project which has been completed. The projects for Paragraphs 30 and 32 have been completed. The following summarizes the status of the completed and ongoing projects, and highlights actions taken thus far: 28 HFNA-000003337 EPA Inspection Report - Page 1788 of 1969 Calendar Quarterly Report - 2nd Quarter 2019 HollyFrontier Navajo Refining llC, Artesia and Lovington Refineries Environmentally Beneficial 1 CD ---------------------~~~~~~~~~~~~~~~----~ Status/Comment t~:fSPS aa6~~c:~es t...Par;:~ph_____ : Prior to 12/31 /03, Navajo began operation ofthe - applicable to Artesia and new covered wastewater sepa(ator, completed the Lovington individual drain bypass of the South Plant API, installed covers on systems, oil-water separators, junction boxes and initiated drain inspections for and aggregate facilities by the Artesia refinery. Junction boxes at the 12/31/03 Lovington refinery were also covered and the routine inspection of drains (to assure proper water seal) was begun. Navajo otherwise ceased the use of an open culvert for draining oily process wastewater into the sewer. , In early September 2010, it was discovered that I the storm water catch basin of the A!kyiation Unit ' Tar Pit could still receive some oily-water and therefore could be considered as a junction box. A cover for the storm water basin was designed, constructed, and installed by 11/12/2010. In July 2014, it was discovered that visual inspections were not conducted initially and semiannually as required by 40CFR 60.692-2 (07/11/2014 self-disclosure letter to NMED. Certified Receipt Number: 70073020000030288246). Navajo Started semiannual inspections on 07/01/2015. A third party review of the QQQ program indicated that there may be a potential issue regarding certain aspects of the drain systems at the Artesia and Lovington refineries, in particular, the status of catch basins in these drain systems. Subpart QQQ exempts drain systems that have catch basins in their existing configuration prior to the rule's applicability date. Navajo is nevertheless evaluating the proactive retrofit of these catch basins with covers (inserts), and has initiated a capital project to address this. Retrofit work is in progress and is expected to be completed by the end of calendar year 2020. 29 HFNA-000003338 EPA Inspection Report - Page 1789 of 1969 Calendar Quarterly Report - 2nd Quarter 2019 Hol!yFrontier Navajo Refining LLC, Artesia and Lovington Refineries B. Section V, Paragraph 30: Operation of the 40 l TPD SRU {SRU1} on Standby Artesia SRP (No SRU at Lovington): :. Environmentally Beneficial I Complete i~~~~~~n of : equipment on SRU 1 to allow operation in standby service : by 12/31/03 - - ~ - - - - - - - - - - - .......,................ CD I Status/Comment .. Para3g0aph rsFfU1 was started up again on 5/10/03 operaffnga11 I a reduced rate in backup service. ' i A new 100 long ton per day sulfur recovery unit I (SRU3) began operating 05/11/2009. The I combined capacity of SRU2 and SRU3 provides excess sulfur recovery capacity. Therefore, as an energy and emissions conservation measure, SRU1 is no longer operated in standby service. [ Complete study plan on how .......................... ........................................................... .........................................! 30 Acid Gas Flaring and TGU Excess Emissions to limit excess TGU Study Plan submitted 2/27/04. Pursuant to the emissions and Acid Gas plan, Navajo completed the study and submitted a Flaring by 2/28/04 3/24/05 summary of the study including actions taken and recommendations. The study results were used to update the PMO plan with the modified PMO plan included with the 3/24/05 submittal. ............................................................1...................................................................- - - - - - - C. Section V, Paragraph 31: Installation of Spare FCCU Wet Gas Compressor Artesia FCCU (No FCCUat Lovington}: ---- ...... Environmentally Beneficial I CD Project Paragraph .................................................................. Status/Comment . tt:omp!ete installation of spare 31 A spare wet gas compressor was installed during J : wet gas compressor by I 12/31/03. Operate so as to i minimize the duration of AG the 4th Quarter of 2003 FCCU turnaround. On 01/07/2011, Navajo's outside legal counsel submitted a request to modify or remove this or HC flaring incidents during paragraph. Operating procedures to minimize the outages of the original duration of AG flaring were updated 04/30/2015. compressor, A preventive maintenance plan for the spare compressor C-0950 was completed on 05/11/2015. 30 HFNA-000003339 EPA Inspection Report - Page 1790 of 1969 Hol!yFrontier Navajo Refining lLC, Artesia and Lovington Refineries D. Section V, Paragraph 32: Supplemental Environmental Project (SEP) Benefiting the ........................ Artesia..Community_____ ------~-------- : Environmentally Beneficial CD I Project Paragraph Status/Comment I Complete implementation of ! SEP to benefit the Artesia community by June 30, 2003 32 Navajo completed the community SEP prior to the --1 revised 9/29/03 deadline and submitted cost certification data on 9/23/03 pursuant to Paragraph 91. The SEP installed mechanical mixers to replace air mixers on nine asphalt storage tanks to reduce odors. The tanks were T-0110, T-0404, T-0405, T- 0406, T-0409, T-0410, T-0428, T-0431, and T- 0432. I T-0404, T-0405, T-0406, and T-0409, and T-0428 ..................................... ..,...have..been.permanently. removed from service. E. Sectior,V,Paragraph__33: __EMS..Baseline.Assessment.for.Artesia..Refinery Environmentally Beneficial CD Status/Comment Project Paragraph ~~~~~~~~tDC~~~;~;t~1/~ -----------------------------------------------,ssssss--- 33.C Completed via letter from NMED dated 4/19/02. perform the baseline assessment r Execute contract with +3::f o' Completed as of 4/15/02 t...lndependent..Contractor ............... t............................................... ........ .. ................................. ...... ... ________________, Baseline Assessment Report 33. E Navajo received the baseline assessment report on to be received by Navajo 7/17/02. within 210 days of Date of Lodgin"' ~-~~-------------4""-------------- ssssssss~' Navajo to implement 33.F Navajo has accepted the recommendations and recommendations in accordance with the baseline report schedule schedule deadlines provided in the baseline report (the 8 recommendations are numbered in parenthesis in the discussion below). For the two (i.e., 1A and 5) recommendations with 10/1/02 deadlines, Navajo implemented both on time {i.e., prior to the deadline). The report to file required by CD ,T33.F.ii was completed 12/27/02. ;-------------------4""--------------~------ Navajo to implement 33.F Navajo did the roll-out of the refinery environmental recommendations in policy (1 B) and put environmental responsibilities accordance with the baseline (3) into a new specifically developed operator's report schedule -Cont'd manual prior to the baseline report recommendation deadline (Le., 2/1/03 and 3/1/03, respectively). 31 HFNA-000003340 EPA Inspection Report - Page 1791 of 1969 Calendar guarterlv Reeort - 2nd Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries ( Environmenta1iy Beneficial r..............cif...... .. ---""""""""""""" Status/Comment Project....- ................................1.....Parag.....r...a.....P......h.........,...................................................... - - -...................................... I Navajo to implement 33.F The position descriptions (6) which were I recommendations in recommended for Navajo's Environmental Affairs accordance with the baseline Department staff were prepared and distributed report schedule prior to the 7/1/03 deadline. An independent - Cont'd consultant performed an on-site evaluation of Navajo's implementation of the recommendations and prepared a 6/23/03 evaluation report prior to : the 6/30/03 deadline. .......- -..- - - - - - - - - - - - - - - +I - - - - - Navajo to implement 33.F [ Per the independent consultant's June 2003 recommendations in : evaluation report, the 9/1/03 original deadline for accordance with the baseline report schedule -Cont'd the recommended CBT training module (2) was revised to 3/1 /04. . .............J Navajo to implement recommendations in accordance with the baseline report schedule - Cont'd 33.F 1 Work commenced in November 2003 on I developing the CBT training module (2). The CBT I module was completed and rolled out on 2/27/04, I thus meeting the 3/1/04 deadline. The decision I was made to implement (7) via the electronic I option (6/1/04 deadline). Recommendation No. 8A, ! "Develop Environmental Records Retention Policy and Document Control Procedures" was implemented prior to the 12/1/03 deadline. :: ccccccccccc'CC c c c c c c c c c c c c c c c c c c c c c c c c c c c c c c c c c c c ~ - - - - - i - - - - - - - - - - - - - - - ....................................... , Navajo to implement 33.F Completed the evaluation of the LOAR program, recommendations in process and procedures (4) on 6/3/04 and accordance with the baseline determined that the program is working as report schedule -Cont'd intended. Integrated compliance requirements calendar (7) was implemented prior to the 6/1/04 deadline. Completed work to implement the environmental records management system (8B) during May 2004 with the aid of an outside consultant The records management system is in place and working. An independent consultant conducted the implementation evaluation presented in a June 30, 2004 report, thus meeting the deadline. A final closure letter on the EMS I improvement recommendations was issued I September 30, 2004 by the consultant concluding I no remaining EMS improvement actions for I Navajo. _ __ .........................S..... ...................................................................................." ..- .............. 32 HFNA-000003341 EPA Inspection Report - Page 1792 of 1969 Calendar Quarter! HollyFrontier Navajo - 2nd Quarter 2019 ng LLC, Artesia and Lovington Refineries 6.0 OTHER MATTERS The recent implementation of flare monitoring requirements under NSPS Ja resulted in the identification and repair of several relief valves that were leaking to the flare. In addition, three flare gas streams with higher sulfur levels were identified as routed to the Lovington flare. These three streams were rerouted to the fuel gas system. As of November 11, 2015, all gas streams currently routed to the flares are being monitored for compliance with the NSPS Ja requirements. Excess emission information for the flares at Artesia and Lovington for the semiannual period: January-June 2016 was included in Attachment 4 to the 3rd quarter 2016 Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: July-December 2016 was included in the semiannual NSPS monitoring report submitted on January 30, 2017, and was attached to the 1st quarter 2017 Consent Decree Progress Report. Excess emission information for events occurring during the semiannual period: January-June 2017 was included in the semiannual NSPS Ja monitoring report submitted on July 28, 2017, and was attached to the 3rd quarter Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: January-June 2018 was included in the semiannual NSPS Ja monitoring report submitted on July 30, 2018, and was attached to the 3rd quarter 2018 Consent Decree Progress Report. The excess emission information for events occurring during the semiannual period: July-December 2018 was included in the semiannual NSPS Ja monitoring report submitted on January 30, 2019. The excess emission information for events occurring during the semiannual period: January-June 2019 will be reported in the semiannual NSPS Ja monitoring report due on July 30, 2019, and will be attached to the 3rd quarter 2019 Consent Decree Progress Report. 33 HFNA-000003342 EPA Inspection Report - Page 1793 of 1969 Calendar Quarterly Report - 2nd Quarter 2019 HollyFrontier Navajo Refining LLC, Artesia and Lovington Refineries HFNA-000003343 EPA Inspection Report - Page 1794 of 1969 .ATTACHMENT 1 APPENDIX G SUMMARY REPORTS HFNA-000003344 EPA Inspection Report - Page 1795 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 2nd QUARTER 2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT REPORTS, PLANS AND CERTIFICATIONS UNDER THE BENZENE WASTE NESHAP ENHANCED PROGRAM PROVISIONS OF PARAGRAPI-I 22 OJT THE CONSENT DECREE IN UNITED STATES ET AL. V. NAVAJO REFINING CO. ET AL. IName or Summary of the l R~P9rt,fi~:i,,gr rl .C.-.-.-.-.e-.-.-.-r.-.-.-t----i----f-----i----c-------a------t----i-----o-------n----- i BWN Compliance Review and Verification Report CD SubPara No. C.L Rqd. ("R") v. Contingent ("C") One-Time ("l ") v. Quarterly orw/ 63.654 Reports (''> 1") R 1 Due Date 270 days after Lodging Review completed 09/11/2002. Report submitted 10/09/2002 Status uuuuu,u. --------;;/ .-.-.-.-.-.----=~ -----;;;;;;;;-;-;-;-:-.:-:-:-,= Amended BWN C.ii. C 1 Compliance Review and Verification Report uu -~~~~~~~~~ ~~~~~~ .-; ~~=~~~.-...-~~-.-.-= ~ 90 days after completing additional sampling requested by EPA Not Yet Applicable. EPA has not requested additional sampling. Amended TAB Report D.i C 1 60 days after completing BWN Compliance Review and Verification Report An Amended Report for the Artesia Refinery (>1 Mg, <10 Mg) was Submitted 10/09/2002 with the Verification Report uu~.-.-.-.-.-.-.-. ~~~~~~~~~~~~~~~~~~~-~~ Plan to comply w/ 6 BQ D.H; C 1 if TAB equals or is J.vi. greater than 10 :r-I ,,,, "Tl z 0 0 0 0 0 (,) (,) .i:,,. 01 180 days after completing BWN Compliance Review and Verification Report Not Applicable unless the Al1esia or Lovington Refinery exceeds 10 Mg/yr in the annual TAB report uuuuuuuu~~- nu~ Pagel of 12 EPA Inspection Report - Page 1796 of 1969 HoI1yFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 2nc1 QUARTER 2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT Name or Summary of the Re.port.,..Plan, or Certification, CD SubPara No. 1 1 iRqd. I0 ne-T.1me I("R") I("1 ") V. Iv. Corrt- Quarterly ingent orw/ (''C") 63.654 Reports ("> l "} DueDat~ ~~~~~~uuu~~~~~~~uuuuuu-~u-ccc ---------;;;- .;.;.;.;.;.;.;.;.;.;.;.;.;....~-;-;.uuuuuuu~ Status -.-.---.-.-.-.-.- .-,;-:-:-:-:----;,.z..;,.;,.;,.;,.;,.;,.;,, Compliance Certification D.iv C 1 Waste/Slop/Off-Spec Oil H.i. R 1 Schematics 30 days after completing all actions necessary to come into compliance 90 days after Lodging Not Applicable unless the Artesia or Lovington Refinery exceeds 10 Mg/yr in the annual TAB report. '""" .-.------------------------------------ Submitted on 03/19/2002. Revised plan reflecting plant modifications submitted 04/29/2004. Schematics are.~w~!!~O,/i ~rf!!;en. ae2roval by EPA. Submit revised H.i. C 1 Waste/Slop/Off-Spec Oil Mutually-agreed upon time between Navajo Not Applicable until EPA confers with Navajo on the Waste/Slop/Off-Spec Oil Schematics. Schematics reflecting and/or Montana agreement with EPA on comments. I, Schedule to complete H.ii. C l i installation of controls on waste management units I handling organic benzene Refining and EPA r t ' I Mutually-agreed upon time between Navajo and/or Montana Refining and EPA, not u u u u u u u ...... . . . . . . . . . . . . . . . . . . ~~~~~~~~ Not Applicable unless the Artesia or Lovington Refinery exceeds 10 Mg/yr in the annual TAB report waste to exceed 2 years ......................................... ..........................-.-.-.-.-.-...-...-...---.---~ ""........................-.-.-.--------- --------------------------------------------~~ ~~~~~~~ Plan to quantify H.iv. R l uncontrolled waste/slop/off-spec oil movements 90 days after EPA has approved schematics Not Applicable until EPA provides written approval of the Waste/Slop/OffSpec Oil Schematics. Although EPA has not commented on or approved the schematics submitted under paragraph 22.H.i, Navajo has quantified the tmcontrolled waste/slop/off-spec oil movements in the annual NESHAP :r-I ----------------~~~~~~----~~~------~~~~~~~~~~~~~-,,, "Tl z 0 0 0 0 0 (,) (,) .i:,,. 0) Subpart FF Total Annual Benzene (TAB) repm1. ........................................................- - . Page 2 of 12 EPA Inspection Report - Page 1797 of 1969 HollyFrontier Navajo Refming LLC Artesia and Lovington Refineries Al'TACHMENT 1 TO 2nd QUARTER 2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT =~~=~~=~=~=~~-~~,~=-=-;.,..,.-.~~-:-:-;-;-;-;-;-;...~~--~-=-=-;...~~- Name or Summary ofthe R~port, .. :PJ<1:n,.or Certification EOL Sampling Plan -----------------------------------: -.-....-.-.-.-.-.-.-.-.-.-.-uuuu.-,~ ""'"-"' " - " - - " ~ ' "'""""""""""""""---.-.-.-.-. -~~~~~nu,~,~ CD SubPara No. Rqd. ("R") v. Contingent ("C"} One-Time ("1 ") V. Qumter1y orw/ 63.654 Reports (">_I_") Due Date Stat~ """""""""" U; C 1 J.ii 2 months after the 22.D.iii Certification (if TAB is 10 mg/yr or greater); 90 days after submitting fmal BWN Compliance Review and Verification Report (if TAB is 1 Mg/yr or more but less than 10) EOL Sampling Plan submitted on 02/06/2003. EOL Revised Sampling I.ii; C Plan J.ii. As needed If and when Navajo and/or Montana Refm:ing become aware of factors Revised EOL Sampling Plan submitted 03/31/2004. indicating original plan no longer accurately reflects EOL benzene quantity ----.-.-~ ----.-.-.-----------------.-.-.-.-.-------.-. --------------------------------------------~~------------~~--~~~~~~~~~~ Applicable after refinery I.vii; C TAB exceeds ]0 Mg/yr Plan to ensure that As needed 30 days after the end of the quarter in which the projected calendar Not Applicable unless the Artesia or Lovington Refme1y exceeds l OMg/yr in the annual TAB report. uncontrolled benzene year benzene quantity I does not equal or exceed, "Tl z 6 Mg/yr or that it is :0r- minimized 0 0 0 0 (,) (,) .i:,,. -..,J is equal to or greater than6Mg. Page 3 of 12 u u u u u u u . . . . . . . . . . . . . . .- ~~~ EPA Inspection Report - Page 1798 of 1969 HoHyFro.mier Navajo Refining LLC 1\rtesia and Lovington Refineries AT'fACIIiV[EN'f 1 TO 2nct QUARTER 2019 STATUS REPORT APPENDIX G STATUS SUNlM.ARY REPORT u- -----------;; ;-;-;-;-;-;-;- Name or Summary of the CD Rqd, One-Time ReporkPlan, or Sub- ("R") (" l '1) V. Certification Para v, Cont- Quarterly No. ingent orw/ ("C") 63,654 Reports (''> 1") Qu~I?.11te Statyil Applicable if refinery TAB is > 1 but < l 0 J,iv- C J,v Mg/yr - Plan to ensure that uncontrolled benzene does not equa1 or exceed, as applicable, 10 Mg/yr or that it is minimized As needed 30 days ailcr the end of the quarter in which the projected calendar year benzene quantity is equal to or greater than 10 Mg, The 2007 4t1t quarter EOL benzene quantity;~;ee<l~d 2.5 Mg, but the calendar year 2007 Tlill did NOT exceed 10 Mg. Because the calendar year is over, and the TAB did not exceed 10 Mg-in the calendar year, submittal of a plan to prevent the calendar year TAB from exceeding 10 Mg, as required under 4! 22,J,iv, becomes moot, As required by ,i 22JvLii.a(3), Navajo specifically sought FPA's concurrence with this interpretation but no response has been received. The EOL BQ for the 131 quarter of 2008 was <2,5 Mg and the projected 2008 TAB was < l O Mg/yr so no plan was required. The EOL BQ for the 2"'1quarter of 2008 was > 2-5 Mg and the projected tab was > l OMg/yT, The required plan was included as a supplement to the 2"6 quarter report. Navajo specifically sought EPA\; concurrence with this plan but no response has been received, The EOL BQ for the 3n1quarter of 2008 was> 2.5 Mg and the pn~jected tab vms > 10 Mg/yr (sec Attachment 3), The required plan was included as a supplement to the ya quarter report As required by 9l 2Ll\tiLa(3), Navajo specifically sought EPA's concurrence with this plan but no response has been received. The TIOL BQ for the 4th quarter of 2008 was <2-5 Mg and the projected 2008 TAB was < l OMg/yr so no plan was required, The EOL BQs for the 1st, 2nd, ya a:nd 4th quarters of 2009 were <2.5 Mg and i '. I j the projected 2009 TAB ;,vas < 10 Mg/yT so no plan was required, The EOL BQ frx the 1st, 2"d, 3\ and 4th quarters of 2010 was <25 Mg and the projected 2010 TAB was < 10 Mg/yr so no plan was required. The EOL BQ for the 1st, 2"0, J>d and 4th quarters of 2011 was <2,5 Mg and I "Tl the projected 2010 TAB was < 10 Mg/yr so no plan is required. z :r- The EOL BQ for the l 1, 211d, 3ra and 4th quarters of 2012 ;,vas <2-5 Mg and 0 0 the projected 2010 TAB was< 10 Mg/yr so no plan is required, ~ 0 0 ,,,,,, ..I.!3E..t2.-b..~QJ?t_t,t_~;~t, 2"a, Jfd and 4th quarters of 2013 were each <2.5 M 0 (,) (,) Page 4 of 12 .i:,,. OJ EPA Inspection Report - Page 1799 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACIL"\'lENT 1 TO 2nd .QUARTER 2019 STA'IUS REPORT APPENDIX G STATUS SUJVIMARY REPORT Name or Summary of the CD Report Plan. or Sub~ Certification Para No. ,_ ~- -~~~~~~ -.-.-.-.-.-u uuuu=uu, Rqd, ("R") v, Contingent ("C") One-Time (" l ") V, Quarterly orw/ 63.654 Reports ("> 1") I "Tl z :r- 0 0 0 0 ' 0 (,) (,) .i:,,. (!) Due Date Status uu,u.-.-.-.-.- U U U U U U U U . ; ~~~~~~~~~~~~~~~~~~~~~~~ -~~~ and the projected 2012 TAB \Vas< 10 Mg/yr so no plan was required. The EOL BQ for the 1"' and 2nd quarters of 2014 was <2.5 Mg and the projected 2014 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the 1'', 2"'1, 3"\ and 41h quarters of 2014 ;,vere <2.5 Mg and the projected 2014 TA..B was< 10 Mg/yr so no plan was required, The EOL BQ fcir the 1"'quarter of 2015 was <2.5 Mg and the projected 2015 Ti\B was< 10 Mg/yT so no plan was required. The EOL BQ for the 2nd quarter of 2015 was <2,5 Mg and the projected 2015 TAB was < IO Mg/yr so no plan was required. The EOL BQ for the 2nd quarter of 2015 was <2.5 Mg and the projected 2015 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the 3rd quarter of2015 was <2.5 Mg and the projected 2015 TAB was < 10 Mg/yr so no plan was required. The EOL BQ for the 4th quarter of 2015 was <2.5 Mg and the projected 2015 TAB was < 10 Mg/yr so no plan was required. The EOL BQ for the 1st quarter of2016 was <2,5 Mg and the projected 2016 TAB was < 10 Mgiyr so no plan was required. The EOL BQ for the 2nd quarter of 2016 was <2.5 Mg and the projected 2016 TAB was < 10 Mg/yr so no plan was required. The EOL BQ for the 3rd quarter of 2016 exceeded 2,5 :tvlg but the calendar year 2016 TAB did NOT exceed 10 ]\:lg, As the first two quarters of2016 indicated significantly lower concentrations of benzene in the wastewater, the projected TAB remained below 10 Mg for the calendar year, and as such no specific actions need to be taken to ensure the TAB docs not exceed 1OMg. Regardless of that, however, Navajo developed a plan of targeted monitoring to help identify and address the benzene contributions during the third quarter. The plan was implemented by November 4, 2016 (attachment 4). Page 5 of 12 EPA Inspection Report - Page 1800 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 2nd QUARTER 2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT Name or Summary of the R~_;1ort, Plan. or Certification CD SubPara No. IRqd. IOne-Time I("R") I(" l ") v. l v. Cont-I Quarterly Iingent Ior w/ I("C") I63.654 I IReports I t !l ("> l ") I f : ; i I Due_Date Status .-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-~. -.-.-~- .......................................................................................-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-~.-.-~~ The EOL BQ for the 4th quarter of 2016 was <2.5 Mg and the projected TAB for 2016 was <10 Mg/yr. The EOL BQ for the 1st quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BQ for the 2nd quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BQ for the 3rd quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. The EOL BQ for the 4th quarter of 2017 was <2.5 Mg and the projected TAB for 2017 was <l OMg/yr. The EOL BQ for the 1st quarter of 2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr, so no plan was required. The EOL BQ for the 2nd quarter of2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr, so no plan was required. The EOL BQ for the 3rd quarter of 2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr, so no plan was required. The EOL BQ for the 4th quarter of 2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr, so no plan was required. The EOL BQ for the 1'1 quarter of 2019 was <2.5 Mg and the projected TAB for 2019 was <10 Mg/yr, so no plan was required. The EOL BQ for the 2"d quarter of2019 was <2.5 Mg and the projected TAB for 2019 was <10 Mg/yr, so no plan was required. I "Tl z :r- 0 0 0 0 0 (,) (,) 01 0 i I I ~~-~ . -~~~~~u.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~-------~~~~~~~~~~~~~~~~-~ --~~~~----~~~~~~~~=~=~~~~~~=~~~~~~~~~~ Page 6 of 12 EPA Inspection Report - Page 1801 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 2nd QUARTER 2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT --------------------------------------------------------------------------------------.-.-.-.-.- -.-.---=u.---u~ ~u.-.-.-uuuuu=U Name or Summary ofthe CD Rqd. One-Time R~port, .. Pl{l,1'.1,.9r Q,;rtificafam Sub- ("R") ("l ") V. Para v. Cont- Quarterly No. ingent orw/ ("C") 63.654 Reports ("> 1") :QeD,;ite: Proposal for Third-Party TAB Study and Compliance Review I-viii; C J.vi ~~~~~~~=~~~~~- ------~- ~~-- -----------------~ .----- Third-Party TAB Study I- C and Compliance Review viii; J.vi 1 -----------------u u---------~u----------uuuuuU 1 Last day of 4111 Quarter as set forth in, I.viii. (if TAB is 10 mg/yr or greater); As agreed by EPA and Navajo and/or Montana Refining (i:fTAB isl Mg/yr or more but less than 10) 30 days after receipt of the Third-Party Study and Compliance Review uuuu~u.-.-.-u-.-.-.-.-.-ooou-- -~~~nnnn~~ Status Not Applicable unless refinery cannot take actions to keep TAB below 10 Mg/yr. u-u-uu=uu-,------------u--------------------- ---------------------------------------------n~~=~ Not Applicable unless refinery cannot take actions to keep TAB below 10 Mg/yr. Plan to implement the J.vi; C l results of the Third-Party TAB Study and Compliance Review 120 days after receipt ofthe Third-Party TAB Study and Compliance Review Not Applicable unless refinery carmot take actions to keep TAB below 10 Mg/yr. I "Tl z :r- 0 0 0 0 0 (,) (,) Page 7 of 12 .0...1.. EPA Inspection Report - Page 1802 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 2nd OUARTER 2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT '"""-----------,-----r-----,-------,---------------,----------------------------------------------s Name or Summary of the CD Rqd. One-Time R~nort:,. Plmt..9r CertWc@tiQJ+ Sub- ("R") (" l ") V. Para v. Cont- Quarterly DueDate Status No. ingent orw/ ("C") 63.654 Reports ("> l ") Report on training done G.i- C Q in that Quarter iii.; Mii- Each Quarterly Report due under the Consent Decree A training plan was developed 12/6/02 for the Artesia Refinery (i.e., since its TAB is greater than LO Mg/yr). The first training session was held 1/7/03 at both the Artesia and Lovington refineries. The second training a(]) session for the two refineries was held 1/27/04 and 1/28/04. Annual refresher training performed the weeks of2/8/05, 3/27/06, 3/5/07, 2/25/08 (Lov), 11/07/08 (Art), 12/18/09, 12/17/2010 and 12/20/2011, 11/08/2012, 01/14/2013, 04/18/2013 11/12 to 11/14/2013, 05/24/2014, 06/19/2014, 06/20/2014, 12/02/2014, 3/16/2015, 4/1/2015, 5/15/2015, 2/29/2016, 3/8/2016, 3/17/2016 (Art. and Lov), 02/28/2017 (Artesia and Lovington), 08/29/2017 (Artesia and Lovington), 09/30/2018 (Artesia and Lovington) and 02/28/2019 (Artesia and Lovington). ~ - - - - - - - - - - - - - - - , . , __ _ _.,,,, ~ >>>>>>>>>>>" ~ ----------------------------------$ ------------------------------------................................. ....J.-~.............................., -............... -........................................-.-.-...-.-.-.-.-.-.-.-.-.-. .-.----------------------------------- ~~~~~~~~~~~~~~~~~~~~~~~~~NN~~~-----"' I "Tl z :r- 0 0 0 0 0 (,) (,) Page 8 of 12 01 N EPA Inspection Report - Page 1803 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries Results of annual sampling of>0.05 Mg/yr benzene streams J.i; Jc Mii- , a(2) : i j : I j ATTACHMENT 1 TO 2nd QUARTER 2019 STATUS REPORT APPENDIX G STATUS SUl\1MARY REPORT u~UU~u~U~uuuuucccc~cc--- ----- """"""""""""""" -------- '--=~~~~ Q In the first Quarterly The annual sampling was perfonned. in February 2005. The result1 were Rep011 for the first presented with the first quarter 2005 report. calendar quarter of Annual sampling was performed in February 2006. The results w1: ,e each year presented in Attachment 4 with the first quarter 2006 report. Annual sampling was pe1formed in September and December 200'. . The results were submitted in attachment 4 ofthe first quarter 2008 rep011 as required by iJ22.M.ii.a(2). Annual sampling was performed in December 2008. The results Vi ere submitted in attachment 4 ofthe first quarter 2009 report as require dby ,22.M.ii.a(2). Annual sampling was perfonned in December 2009. The results v. ere submitted in Attachment 4 of the first quarter 2010 report as requi1edby iJ22.M.ii.a(2). Annual sampling was performed in December 2010. The results Vi ere submitted in Attachment 4 of the first quarter 2011 report as requit edby iJ22.M.ii.a(2). Annual sampling was performed in December 2011. 'foe results Vi ere submitted in Attachment 4 of the fust quarter 2012 report as requi1 edby ,22.M.ii.a(2). Annual sampling was performed in December 2012. The results Vi ere submitted in Attachment 4 of the first quarter 2013 report as requil edby ,22.M.ii.a(2). Annual sampling was performed in December 2013. The results Vi ere submitted in Attachment 4 of the first quarter 2014 repmt as requil edby iJ22.M.ii.a(2). Annual sampling was performed in December 2014. The results VI ere submitted in Attachment 4 of the 1stqua11er 2015 report as required by 122.M.ii.a(2). l I "Tl z :r- 0 0 0 0 0 (,) (,) Page 9 of 12 01 (,) EPA Inspection Report - Page 1804 of 1969 HollyFronticr Navajo Refining LLC Artesia and Lovington Refineries Results of annual Jj; sampling of>0,05 Mg/yr J\fo- benzene streams a(2) ATTACHJVIENT 1 TO zmi QUARTER 2{H9 STATUS REPORT APPENDIX G STATUS SUlVflViARY REPORf C Q In the first Quarterly Report for the first calendar quarter of each year ! Annual sampling was performed in December 2015. The results were I included in Attachment 4 of the 1'tquarter 2016 report as required by I 922.1vu1.ac2,. ' Annual sampling was performed in October 2016. The results were included. in Attachment 4 of the l st quarter 2017 report as required by 922.M,ii.a(2). Annual sampling was performed in December 2017. The results were included in Attachment 4 of the 1st qurui:er 2018 report as required by ij;fi.'<F:.,);...M ; .1"1.ai_'2).. Annual srunpling was performed in December 2018. The results are included in the 1st quarter 2019 report as required by 4!22JvULa(2). Results of Quarterly EOL J.iii; C Q Sampling M.ii. a(3); M.ii- b(2) Each Quarterly Report due under the Consent Decree {after written EPA approval of EOL i,.1:1mpUnKPl.0en) 2004: Under the assumption that the sampling plan was accepted by EPA upon the 03/31/2004 submittal of the revised EOL Sampling Plan, Navajo conducted its first EOL sampling during the week of 3/22/04. The annual TAB, submitted 4/05 was 4.9 Mg fix Artesia and L5 Mg for Lovington, 2005: The EOL benzene quantity (BQ) for the 1", 2nct, 3rd, and 4th quarter of 2005 were each <2,5 Mg, 2006: The EOL BQ fbr the 1'1, 2"d, 3"\ and 41h quarters of 2006 were each <2,5 Mg, 2007: The 1'\ 2"'1, and 3,<l quarter 2007 EOL BQs were each< 25 Mg, The 2007 4,h qurui:er EOL benzene quantity exceeded 2,5 Mg, but the calendar year 2007 TAB did NOT exceed 10 Mg. 2008: The EOL BQ for the 1'' quarter of 2008 was <2.5 Mg and the pn.rjected 2008 TAB was< 10 Mg/yr. The EOL BQ for the 2n quarter of 2008 was> 2.5 Mg and the projected tab was> 10 ?vig/yr. The EOL BQ for the Td quarter of 2008 was> 2.5 Mg and. the projected tab was> 10 Mg/yT. The EOL BQ for the 4'1' quarter of 2008 was <2.5 Mg and the projected 2008 TAB was< 10 Mg/yT. 2009: The EOL BQ for the J5\ 2rn:1, 3'"0 a:nd 4th quarters of 2009 were <2.5 Mg and the projected 2009 TAB was< 10 Mg/yr so no plan was required, ; I 2010: The EOL BQ for the 1~t, 2"d, ]', and 4,h qurui:ers of 20 l Owas <2,5 Mg "Tl z and the projected 2010 TAB was< 10 Mg/yr so no plan was required. :0r- 2011: The EOL BQ for the l st, 2nd, 3ni and 4th quarters of 2011 was <2.5 Mg 0 0 and the pn~iected 20Hl TAB was< lO Mg/yr so no plan isJeg}reg. ___ 0 0 (,) (,) Page 10 of 12 01 .i:,,. EPA Inspection Report - Page 1805 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 2nd QUARTER 2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT 2012: The EOL BQ for the l st, 2nct, yct and 4th q~arte;;~:r::2012 was <2.5 Mg and the projected 2012 TAB was< 10 Mg/yr so no plan is required. 2013: The EOL BQ for the P\ 2ml, 3rd and 4th quarters of 2013 was <2.5 Mg and the projected 2012 TAB was< 10 Mg/yr so no plan is required. 2014: The EOL BQ for the 1st, 2nd, 3rd and 4th quarters of 2014 were <2.5 Mg and the projected 2014 TAB was < 10 Mg/yr so no plan was required. 2015: The EOL BQ for the 1st quarter of 2015 was <2.5 Mg and the projected 2015 TAB was< IO Mg/yr so no plan was required. The EOL BQ for the 2nd quarter of 2015 was <2.5 Mg and the projected 2015 TAB was < 10 Mg/yr so no plan was required. The EOL BQ for the 3rd quarter of2015 was <2.5 Mg and the projected 2015 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the 41h quarter of 2015 was <2.5 Mg and the projected 2015 TAB was < l OMg/yr so no plan was required. 2016: The EOL BQ for the 1st quarter of 2016 was <2.5 Mg and the projected 2016 TAB was< 10 Mg/yr so no plan was required. The EOL BQ for the 211dquarter of 2016 was <2.5 Mg and the projected 2016 TAB was < 10 Mg/yr so no plan was required. The EOL BQ for the 3ro quarter of 2016 exceeded 2.5 Mg. As required by paragraph 22.J.iv, Navajo submits the following plan that identifies the specific actions that will be taken, and the schedule for such actions, to ensure the TAB does not exceed 1OMg in the calendar year. As the first two quarters of 2016 indicated significantly lower concentrations of benzene in the wastewater, the projected TAB remained below 10 Mg for the calendar year, and as such no specific actions need to be taken to ensure the TAB does not exceed lOMg. Regardless of that, however, Navajo developed a plan of i targeted monitoring to help identify and address the benzene contributions l during the third quarter. The plan was implemented by November 4, 2016 l (attachment 4). I The EOL BQ for the 4th quarter of 2016 was <2.5 Mg and the projected TAB Ifor 2016 was <10 Mg/yr. I I 2017: The EOL BQ for the 1st quarter of 2017 was <2.5 Mg and the "Tl , z projected TAB for 2017 was <10 Mg/yr. :r- 0 J ~?f:!?-~~O 0 ' - - - - - - - - - - - ' - - - - ' - - - - - - ' - - - - ' - - - - - - - - - . . ..~~e2 ~;;_quarter of 2017 was <2.5 Mg and the projected TAB 0 0 0 (,) (,) Page 11 of 12 01 01 EPA Inspection Report - Page 1806 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 1 TO 2nd QUARTER 2019 STATUS REPORT APPENDIX G STATUS SUMMARY REPORT The EOL BQ for the 3ro quarter of2017 was <2.5 Mg an.d th~projected. TAB for 2017 was <10 Mg/yr. The EOL BQ for the 4th quarter of2017 was <2.5 Mg and the projected TAB for 2017 was <10 Mg/yr. 2018: The EOL BQ for the 1st qumter of 2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr. The EOL BQ for the 2nd quarter of 20] 8 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr. The EOL BQ for the 3rd quarter of 2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr. The EOL BQ for the 4th quarter of 2018 was <2.5 Mg and the projected TAB for 2018 was <10 Mg/yr. 2019: The EOL BQ for the 1st quarter of 2019 was <2.5 Mg and the projected TAB for 2019 was <10 Mg/yr. The EOL BQ for the 2nd quarter of 2019 was <2.5 Mg and the projected TAB for 2019 was <10 Mg/yr. I "Tl z :r- 0 0 0 0 0 (,) (,) Page 12 of 12 01 0) EPA Inspection Report - Page 1807 of 1969 t\TTACJ::IM~~ APPENDIX H SUMMARY REPORTS HFNA-000003357 EPA Inspection Report - Page 1808 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHl\tIENT 2 TO znd QUARTER2019 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT REPORTS, PLANS AND CERTIFICATIONS UNDERTHELDARENHANCEDPROGRAM PROVIS.IONS OF PARAGRAPH 23 OF THE CONSENT DECREE .IN UNITED STATES, ET AL. V. NAVAJO REF.IN.ING CO., ET AL. Name or Summary of the Report, Plan, or C.....e....r...t..i..f...i..c...a....t..i..o....n... CD Sub-1[ Nos. Rqd. ("R") v. Contingent ("C"} One-Time ("l ") v. Quarterly orw/ 63.654 Reports ("> l") DueDate 1 Status Written RefineryWideLDAR Program _,,,..,..,..,..,.., A- R ' O.i.a I Updated Refinery- A C WideLDAR Program l 1150D Prepared by 4/19/02 and Submitted I after I Lodging 5/13/02 .................................. ~~~~~~~~ 1 As LDA.R plan updated 11/19/2009, needed 01/05/2011, 04/28/2014 (approved 7/22/2014). Pagel of9 HFNA-000003358 EPA Inspection Report - Page 1809 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACH1\1ENT 2 TO 2nd QUARTER 2019 STATUS REPORT APPENDIX H STATUS SUI\/IMARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-if Nos. Rqd. ("R") v. Contingent {"C") w ...................................................................... .....................................................~~~~~~~~~ One-Time ("l ") v. Quarterly orw/ 63.654 Reports f"> l "} DueDate Status Report on training B.i; R fornewLDAR personnel O.ii- c(l) >1 In each Training addressed in 63.654 Report Section submitted 9/13/02, 3/15/03, 9/15/03, 63.654 3/15/04, 9i15/04, 3/14/05 (3/15/05 Report for Lovington), 9/13/05 (9/15/05 for Lovington), 3/17/06, 9/13/06 (9/6/06 for Lovington), 3/16/07, 09/14/07, 03/17/08, 09/12/08, 03/16/09, 08/27/09, 03/16/2010, 09/13/2010, 03/16/2011 06/08/2011, 07/l 0/2012, 09/10/12, 11/06/2012, 12/11/2012, 01/13/2013, 05/02/2013, 05/08/2013, 05/15/2013, 02/08/2013 03/09/2013 and 09/16/2014 (for Artesia and Lovington). New hire training was conducted 06/08/2011, 07/10/2012, 09/10/12, 11/06/2012, 12il 1/2012, 01/13/2013, 05/02/2013, 05/08/2013, 05/15/2013, 02/08/2013, 12/9/2013, 03/22/2014, 03/31/2014, 04/01/2014, 06/18/14, 06/19/14, and 06/20/2014. Annual LDAR Computer Based Training (CBT) implemented during the fourth quarter 2014. First training completed before 12/31/2014. Annual CBT for new personnel completed during 2015. Annual CBT completed in 2016; additional training on 4/28/2016, 05/11/2016. Annual CBT completed in 2017; additional training on 04/13/2017, 04/25/2017, 05/20/2017, 12/01/2017. Annual CBT completed during 2018, additional training on 01/2018, 02/2018, and 03/2018. 2019 training on 01/08/2019, 01/11/2019, 02/20/2019, 03/05/2019, and 03/22/2019. ccccccccccccc Page 2 of9 HFNA-000003359 EPA Inspection Report - Page 1810 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO zn<1 QUARTER 2019 STATUS REPORT APPENDIX H STATUS SUM1VIARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-,T Nos. I Report on annual B.ii; training for LDAR personnel O.ii- c(l) Rqd. ("R") v. Contingent ("C") R One-Time ("l'')v. Quarterly orw/ 63.654 Reports C'>l"} >1 .................... ........................................... ~ ~................... : _ , Due__Date .............. ~~~~~~~~~~~~~~~~~~ Status In each Section 63.654 Report Training addressed in 63.654 Report submitted 9/13/02, 3/15/03, 9/15/03, 3/15/04, 9/15/04, 3/14/05 (3/15/05 for Lovington), 9/13/05 (9/15/05 for Lovington), 3/17/06, 9/13/06 (9/6/06 for Lovington), 3/16/07, 09/14/07, 03/17/08, 09/12/08, 03/16/09, 08/27/09, 03/16/2010, 09/13/2010, (for Artesia and Lovington).Annual training was conducted on the following dates by the on-site LDAR contractor: 06/29/2011, 06/14/2012, 06/24/2013, 06/26/2013, 11/12 tol 1/14/20143, 01/12/2014, 01/16/2014, 01/20/2014, 01/21/2014, 02/08/2014, 02/10/2014, 6/18/2014, 6/19/2014, and 06/20/2014. Annual LDAR Computer Based Training (CBT) implemented during the fourth quarter 2014 for all refinery and contractor personnel. Annual CBT conducted during 2015. l\.nnual CBT in 2016; additional 2016 training on 1/3/2016, 1/6/2016, 1/14/2016, and 1/19/2016, 1/31/2016, 04/28/2016, 05/11/2016, 09/2016, 10/2016, 11/2016, and ! 12/2016. Annual CBT in 2017; j additional training on 04/13/2017, I 0412512011, 0512012011, 12m112011. I Annual CBT in 2018; additional j training on 01/2018, 02/2018, j 03/2018, 4/2019. I Page 3 of9 HFNA-000003360 EPA Inspection Report - Page 1811 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO 2"0 Q~RTER 2019 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT -~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ Name or Summary ofthe Report, Plan, or hertificatimi CD Sub-f Nos. Rqd. ("R") v. Contingent ("C") Report on LDAR B.iii; R training for refinery and operations O.iic(l) personnel who hold positions relevant to LDAR .......................... ~~~~~~~~~--~~~~~~~~~ ~~~~~~~~~~~~~~~ One-Time ("1") v. Quarterly orw/ 63.654 Reports ("> 1"} >l Due Date Status In each Section 63.654 Report ................................... : Initial training program implemented. Training addressed in 63.654 Report submitted 9/13/02, 3/15/03, 9/15/03, 3/15/04, 9/15/04, 3/14/05 (3/15/05 for Lovington), I 9/13/05 (9/15/05 for Lovington), I3117/06, 9/13/06 (9/6/06 for j Lovington), 3/16/07, 09/14/07, i 03/17/08, 09/12/08, 03/16/09, j 08/27/09, 03il6/2010, 09/13/2010, l 03/16/2011, 03/14/2012 and I 09/16/2013. Training was conducted i on the following dates for refinery j environmental personnel: I 11/06/2012, 08/13 - 08/15/2013, I 05119 - 512112014, s12112014, l 10/02/2014. Annual LDAR I Computer Based Training (CBT) I implemented during the fourth I~::::~t!~~~;~i~~;,e1:n;a~iBT l in 2015. Annual CBT in 2016; Iadditional training on 1/3/2016, 1 1/6/2016, 1/14/2016, and 1/19/2016, I 1131/2016, 04/28/2016, and ! 05/11/2016. Annual CBT in 2017; I additional training on 04/13/2017, 1 0412512011, 0512012011, 1210112011. Ii Annual CBT in 2018; additional I training on O1/2018, 02/2018, and 0312018. ' Page 4 of9 HFNA-000003361 EPA Inspection Report - Page 1812 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO 2m1 QUARTE~9 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT :t:I ::!,":,mary 1cn Plan, or ! Sub-,T i - Certification I Nos. LDARaudit reports and records of corrective actions. Audits are required every two years. D, O.ii-b. I Rqd. ("R") v. Contingent ("C") R One-Time ("1 ") v. Quarterly orw/ 63.654 Reports (''>1'] Due Date >l I1n the Quarterly Report for the 1st calendar Quarter of each year Status Included in the 1st Qtr 2003 report (submitted 04/17/2003) as Attachment 3. 3rd party audits for Artesia and Lovington were performed during December 2004, January 2007, January 2009, and January 2011. Included in the 1st Qtr 2012 report, a copy of the 01/201 I Audit Report and the corrective actions taken were included with the pt Quarter 2012 report as Attachment 5. The 2013 3rd party audit was conducted from 09/16 to 09/20/2013, after major refinery turnaround, and a complete quarter worth ofnormal operation data has been collected for comparative monitoring. A copy of the audit report and resolutions were presented in the 1st Quarter 2014 report. 3rd party audits for Artesia and Lovington were performed during the week of October 5th to 9th, 2015. A copy ofthe 2015 LDAR 3rd party audit report and resolutions are included in Attachment 5 of the 1st Quarter 2016 report. The 2017 LDAR 3rd party audit was conducted from 05/17 to 05/18/2017. A copy of the audit report was attached to the 3rd Quarter Consent Decree Progress Report. The audit resolutions were included as Attachment 5 to the 1st Quarter 2018 report. The 2019 LDAR 3rd party audit was conducted from 04/29 to 05/03/2019......... Page 5 of9 HFNA-000003362 EPA Inspection Report - Page 1813 of 1969 HoHyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTAC!!lVIENT 2 TO 2nd QUARTER 2019 S'I,ATUS REPORT APPENDIX H STATUS SUIVIMARY REPORT Name or Summary of the Report, Plan, or Certification CD Sub-,I Nos. Rqd. ("R") v. Contingent ("C") Certification of G, !' R implementation of O.iithe first attempt at a(l) repair program Operational I.ii.; R specifications for electronic LDA.R O.i-b data collection and transfer Certification of J R ' implementation of O.ii- QA/QC a(2) procedures for review ofdata generated by LDAR monitoring technicians One-Time i (" 1") v. I DueDate Quarterly Status I . orwi 63.654 Reports ( " > 1") .............. ~~~~~~~~~~~~ l In the Provided with Initial Quarterly first Qtrly Status Report submitted for 2nd report Quarter 2002 on July 30, 2002 due under the CD or the first Qtrly report in which the rqmt. becomes due 1 6mos. Submitted 06/19/2002 after Lodging for Navajo; 1 yr. after Lodging for Montana Refining 1 In the Provided with Initial Quarterly first Qtrly Status Report submitted for 2nd report Quarter 2002 on July 30, 2002. due under the CD or the first Qtrly report in which the rqmt. becomes due. ,.,..,..,..,..,..,..,..,..,.., ..............~.......................~~~~~ Page 6 of9 HFNA-000003363 EPA Inspection Report - Page 1814 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refmeries ATTACH1\1ENT 2 TO 2nd QUARTER 2019 S,IATUS REPORT APPENDIX H STATUS SUMMARY REPORT ~ . ...........................~~~~~--------~~~~ Name or Summary of the Report, Plan, or Certificatio:11 CD Sub-,T Nos. ,.,..,_.,..,..,_..,..,..,.., Identification of each Refinery's LDAR "point" person K', O.iia(3) Rqd. ("R") v. Contingent ("C") R One-Time ("l")v. Quarterly orw/ 63.654 Reports ("> 1") Due Date 1 \ In the I first Qtrly I report due under the CD or the first Qtrly report in which the rqmt. becomes due Status ...........................~~~~~~~ Provided with Initial Quarterly Status Report submitted for 2nd Quarter 2002 on July 30, 2002 Certification of the L" R ' development of a O.ii- tracking program a(4) for new valves and pumps l In the Provided with Initial Quarterly first Qtrly Status Report submitted for 2nd report Quarter 2002 on July 30, 2002 due under the CD or the frrst Qtrly report in which the rqmt. becomes due Page 7 of9 HFNA-000003364 EPA Inspection Report - Page 1815 of 1969 HollyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT t!9 2nd QUARTER 2019 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT 1 . Name or Summary CD Rqd. One-Time ofthe Report, Plan, or Certification Sub-,T Nos. ("R") v. Contingent ("C") ("l ") v. Quarterly orw/ Due.Date Status 63.654 I ("> 1") Reports ' Certification of !M; IR .......................................~~~~~~~~~ 1 In the Provided with Initial Quarterly implementation of O.ii- calibration drift a(5) assessment . first Qtrly report due under Status Report submitted for 2nd Quarter 2002 on July 30, 2002 procedures . the CD or the first Qtrly report in which the requirem ent becomes due ......................~~~" ~....................................................................... ......................~~~~~~~~~~~~~~~~ Certification of N, R l In the Provided with Initial Quarterly implementation of O.ii- the "delay of a(6) repair" procedures first Qtrly report due under Status Report submitted for 2nd Quarter 2002 on July 30, 2002 the CD or the frrst Qtrly report in which the requirem ent becomes due ,._.._.._....... ~~~~~ Page 8 of9 HFNA-000003365 EPA Inspection Report - Page 1816 of 1969 HoHyFrontier Navajo Refining LLC Artesia and Lovington Refineries ATTACHMENT 2 TO 2nd QUARTER 2019 STATUS REPORT APPENDIX H STATUS SUMMARY REPORT Name or Summary of the Report, Plan, or ~ertification CD Sub-'ff Nos. LDAR monitoring O report submitted ' withMACT O.ii- periodic reports c(2) Rqd. ("R") v. Contingent ("C") R One-Time ("l ") V. Quarterly orw/ 63.654 Reports ("'> 1") Due_Date ........................................................................" ~~~~~~~~~~~~~~~~~~~~~ >l In each Section 63.654 Report I I I I Status Provided in MACT 63.654 Reports submitted: 3/15/02, 9/13/02, 3/15/03, 9/15/03, 3/15/04, 9/15/04, 3/14/05 (3/15/05 for Lovington 9/13/05 (9/15/05 for Lovington), 3/17/06, 9/13/06 (9/6/06 for Lovington), 3/16/07, 09/14/07, 03/17/08, 09/12/08, 03/16/09, 08/27/09, 03/16/2010, 09/13/2010, 03/16/2011, 09/15/2011, 03/09/2012, 0/06/2012 (09/06/2012 for Lovington), and 03/15/2013, 09/16/2013, {Lovington and Artesia) 02/25/2014 (Artesia), 08/26/2014 (Lovington), and 02/26/2015 (Artesia and Lovington), 08/27/2015, 2/18/2016 (Artesia and Lovington), 08/29/2016 (Artesia and Lovington), 02/28/2017 (Artesia and Lovington), 08/29/2017 (Artesia and Lovington), 08/30/2018 (Artesia and Lovington), and 02/28/2019 (Artesia and Lovington) .............~~~~ Page 9 of9 HFNA-000003366 EPA Inspection Report - Page 1817 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 April 17, 2019 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling {EOL) Dear Gabriela, Work Order: HS19040619 ALS Environmental received 9 sample(s) on Apr 09, 2019 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed In 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, Generated By: JUMOKE.LAWAL Corey Grandits Project Manager Right Solutions Right Partner www.a!sg!obaL::om Page 1 of29 HFNA-000003367 EPA Inspection Report - Page 1818 of 1969 A.LS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19040619 Lab Samp ID HS19040619-01 HS 19040619-02 HS19040619-03 HS19040619-04 HS19040619-05 HS 19040619-06 HS19D40619-07 HS19040619-08 HS 19040619-09 Client Sample ID S-1 {API HC) S-3 (AP! Water) S-5 (T-40) S-6 (T-41) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Matrix Liquid Liquid Liquid Liquid Water Water Water Liquid Water Date: 17-Apr-19 SAMPLE SUMMARY TagNo Collection Date 08-Apr-2019 09:04 08-Apr-2019 09:15 08-Apr-2019 08:42 08-Apr-2019 08:47 08-Apr-2019 09:09 08-Apr-2019 09:45 08-Apr-2DHJ 09:45 08-Apr-2019 00:00 08-Apr-2019 00:00 Date Received 09-Apr-2019 12:54 09-Apr-2019 12:54 09-Apr-2019 12:54 09-Apr-2019 12:54 09-Apr-2019 12:54 09-Apr-2019 12:54 09-Apr-2019 12:54 09-Apr-2019 12:54 09-Apr-2019 12:54 Hold ::.:..............".::: ~ ~ ~ ::: :::................:.:: ::_.-..-.........:. :: ~ ::: ~ ::: ................::: ::_.-..-..-..-..-..::; ::: ::: ~ ::: ;::;.................:.:: ,:..,......, ~ ::: L..........J L........J. L......J D f""1 l...............% [~~] Page 2 of29 HFNA-000003368 EPA Inspection Report - Page 1819 of 1969 AlS Houston, US Date: 17-Apr-19 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOl) HS19040619 GCMS Volatiles by Method SWl3260 Batch ID: R.336593 Sample ID: S-6 (T-41) (HS19040619-04} CASE NARRATIVE Surrogate failure for HS19040619-04 due to sample matrix. Batch IIJ: R.336576 The test results meet requirements of the current NELAP standards, state requirements or programs where applicable. Batch ID: R.336631 The test results meet requirements of the current NELAP standards, state requirements or programs where applicable. Batch ID: R336662 Sample ID: HS19040747-02MS MS and MSD are for an unrelated sample. Page 3 of29 HFNA-000003369 EPA Inspection Report - Page 1820 of 1969 A.LS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (API HC) 08-Apr-2019 09:04 ANALYSES Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromof/uoromethane Surr: Toluene-dB RESULT QUAL MDL 35 103 98.6 95.2 101 Method:SWS2M 0.50 REPORT LIMIT 5.0 70-126 70-130 70-130 70-130 Date: 17-Apr-19 ANALYTICAL REPORT Work0rder:HS19040619 Lab lD:HS19040619-01 Matrix:Uquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg %REC %REC %REC %REC 1000 1000 1000 1000 1000 Analyst WLR 16-Apr-2019 15:46 16-Apr-2019 15:46 16-Apr-2019 15:46 16-Apr-2019 15:46 16-Apr-2019 15:46 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of29 HFNA-000003370 EPA Inspection Report - Page 1821 of 1969 AlS Houston, US Client: Project Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 {API Water) 08-Apr-2019 09:15 ANALYSES \l'OlATIU::'.S SWS260C Benzene Surr: 1,2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromof/uoromethane Surr: Toluene-dB RESULT QUAl MDL 2.0 86.1 96.4 90.1 100 Method:SW8260 0.030 REPORT I.IMIT 0.25 70-126 82-124 77-123 82-127 Date: 17-Apr-19 ANALYTICAl REPORT WorkOrder:HS 19040619 Lab ID:HS19040619-02 Matrix:Liquid UNITS DILUTION FACTOR DATE ANALYZED mg/L 50 %REC 50 %REC 50 %REC 50 %REC 50 Ahalyst: AK? 15-Apr-2019 23:37 15-Apr-2019 23:37 15-Apr-2019 23:37 15-Apr-2019 23:37 15-Apr-2019 23:37 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of29 HFNA-000003371 EPA Inspection Report - Page 1822 of 1969 A.LS Houston, US Date: 17-Apr-19 Client Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOl) S-5 (T-40) 08-Apr-2019 08:42 ANALYTICAL REPORT WorkOrder:HS 19040619 lab ID:HS19040619-03 Matrix:Uquid ANALYSES RESULT QUAL MDL REPORT LIMIT UNITS .. ,~~ ~~""""""""'"""""""""""""""""" ------------- ..........................,,,,,,,,,,,,,,,, Benzene Surr: 1,2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 0.30 107 99.9 71.9 106 0.024 0.24 70-126 70-130 70-130 70-130 mg/Kg %REC %REC %REC %REC DILUTION FACTOR DATE ANALYZED .......................,,......, , - Analyst: WLR 50 15-Apr-2019 19:59 50 15-Apr-2019 19:59 50 15-Apr-2019 19:59 50 15-Apr-2019 19:59 50 15-Apr-2019 19:59 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of29 HFNA-000003372 EPA Inspection Report - Page 1823 of 1969 ALS Houston, US Date: 17-Apr-19 Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-6 (T-41) 08-Apr-2019 08:47 ANALYilCAL REPORT WorkOrder: HS19040619 Lab ID:HS19040619-04 Matrix: Liquid ANALYSES RESULT QUAL MDL REPORT LIMIT UNITS DILUTION FACTOR - - - - - - - - - - - - - - - - - - - - " " " " " " " " " " " " " " " " " " , , s s , S s , - . - . .................- - - - - :VOi.ATILES BY SW8260C Benzene 0.36 0.024 0.24 mg/Kg 50 Surr: 1,2-Dichloroethane-d4 104 70-126 %REC 50 Surr: 4-Bromofluorobenzene Surr: Dibromoffuoromethane 96.6 68.2 s 70-130 70-130 %REC 50 %REC 50 Surr: Toluene-dB 102 70-130 %REC 50 DATE ANALVZED Analyst WLR 15-Apr-2019 20:24 15-Apr-2019 20:24 15-Apr-2019 20:24 15-Apr-2019 20:24 15-Apr-2019 20:24 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of29 HFNA-000003373 EPA Inspection Report - Page 1824 of 1969 ALS Houston, US Client Project Sample ID: Collection Date: Navajo Refining Company BWON Monthly SampHng (EOL) Field Blank 08-Apr-2019 09:09 ANALYSES iVOLATILES SWS260C Benzene Surr: 1,2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromof/uoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 88.3 95.9 93.1 97.1 Method:SWS260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 17-Apr-19 ANALYTICAL REPORT WorkOrder:HS 19040619 Lab ID:HS19040619-05 Matrix:Water UNITS DIUJT!ON FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC %REC Analyst: AKP 13-Apr-2019 17:28 13-Apr-2019 17:28 13-Apr-2019 17:28 13-Apr-2019 17:28 13-Apr-2019 17:28 Note: See Qualifiers Page for a !ist of qualifiers and their explanation. Page 8 of29 HFNA-00000337 4 EPA Inspection Report - Page 1825 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 1 08-Apr-2019 09:45 ANALYSES rlfOLATILES SW8260C Benzene Surr: 1, 2-Dich/oroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Tofuene..cJ8 RESULT QUAL MDL < 0.00060 89.0 95.0 91A 97.8 Method:SW8260 0.00060 REPORT UMIT 0.0050 70-126 82-124 77-123 82-127 Date: 17-Apr-19 ANALYTICAL REPORT WorkOrder:HS 19040619 Lab !D:HS19040619-06 Matrix:Water UNITS DILUTION FACTOR DATE ANALYZED mg/L 1 %REC 1 %REC 1 %REC 1 %REC 1 Analyst AKP 13-Apr-2019 17:53 13-Apr-2019 17:53 13-Apr-2019 17:53 13-Apr-2019 17:53 13-Apr-2019 17:53 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 9 of29 HFNA-000003375 EPA Inspection Report - Page 1826 of 1969 AlS Houston, US Date: 17-Apr-19 Client: Project Sample ID: CoHection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 2 08-Apr-2019 09:45 ANALYTICAL REPORT WorkOrder:HS 19040619 Lab ID:HS19040619-07 Matrix:Water ANALYSES RESULT QUAL MDL REPORT UMIT UNITS DH.UTION FACTOR DATE ANALYZED ------------------"~"'""~"""""""""""""""""""""""'"""""""'""'"""'"---------= VOLATILES SWS2.SOC Analyst: AKP Benzene < 0.00060 0.00060 0.0050 mg/L 13-Apr-2019 18:18 Surr: 1,2-Dichloroethane-d4 87.1 70-126 %REC 1 13-Apr-2019 18:18 Surr: 4-Bromofluorobenzene 96.7 82-124 %REC 1 13-Apr-2019 18:18 Surr: Dibromof/uoromethane 91.3 77-123 %REC 1 13-Apr-2019 18:18 Surr: Toluene-dB 98.5 82-127 %REC 1 13-Apr-2019 18:18 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 10 of29 HFNA-000003376 EPA Inspection Report - Page 1827 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Duplicate 08-Apr-2019 00:00 ANALYSES Benzene SW8200C Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromoffuoromethane Surr: Toluene-dB RESULT QUAL MDL 1.7 86.3 96.0 90.7 99.4 Method:SW82~0 0.030 REPORT LIMIT 0.25 70-126 82-124 77-123 82-127 Date: 17-Apr-19 ANALYTICAL REPORT Work0rder:HS19040619 lab !D:HS19040619-0B Matrix:Uquid UNITS DILUTION FACTOR DATE ANALYZED mg/L 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst AKP 16-Apr-2019 00:02 18-Apr-2019 00:02 16-Apr-2019 00:02 16-Apr-2019 00:02 16-Apr-2019 00:02 Note: See Qualifiers Page for a list of qualifiers and !heir explanation. Page 11 of29 HFNA-000003377 EPA Inspection Report - Page 1828 of 1969 A.LS Hcn.1ston, US Date: 17-Apr-19 Client: Project Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Trip Blank 08-Apr-2019 00:00 ANALYTICAL REPORT WorkOrder:HS 19040619 Lab ID:HS19040619-09 Matrix:Water ANALYSES ........................................................................... VOLAT!!..E$ SW8260C Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB _____________ RESULT QUAL MDL ... .,..................................... Method:SWS260 REPORT LIMIT UNITS .,,,,,,,,,,,,,..,,,,,,,,,,,__ < 0.00060 0.00060 0.0050 mg/L 88.0 70-126 %REC 95.8 82-124 %REC 93.0 77-123 %REC 98.8 82-127 %REC DILUTION FACTOR DATE ANALYZED ................,,,= Analyst: AKP 1 13-Apr-2019 18:43 1 13-Apr-2019 18:43 1 13-Apr-2019 18:43 1 13-Apr-2019 18:43 1 13-Apr-2019 18:43 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 12 of 29 HFNA-000003378 EPA Inspection Report - Page 1829 of 1969 ALS Houston, US Client: Navajo Refining Company Project: BWON Monthly Sampling (EOL) WorkOrder: HS19040619 Batch ID: 3015 SamplD HS19040619-01 HS19040619-03 HS 19040619-04 Method: VOLATILES BY SW8260C Container Sample WtNol 5.033 (g) 5.171 (g) 5.123 (g) Final Volume 5 (ml} 5 (ml} 5(mL) Weight Factor 0.99 0.97 0.98 Container Type Bulk (5030B) Bulk (5030B) Bulk (5030B) Date: 17-Apr-19 WEIGHT LOG Page 13 of29 HFNA-000003379 EPA Inspection Report - Page 1830 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19040619 Sample ID Client Samp ID Collection Date TCLP Date HS19040619-05 HS 19040619-06 HS19040619-07 HS 19040619-09 Field Blank EQ Blank Port 1 EQ Blank Port 2 Trip Blank 08 Apr 2019 09:09 08 Apr 2019 09:45 08 Apr 2019 09:45 08 Apr 2019 00:00 Batch ID R336593 Test Name: VOLATILES BY SW8260C HS19040619-03 HS 19040619-04 S-5 {T-40) S-6 (T-41 ) 08 Apr 2019 08:42 08 Apr 2019 08:47 .Satch ID R336631 Test Name: VOLATILES BY SW8260C HS19040619-01 S-1 (API HC) 08 Apr 2019 09:04 Batch IO R336662 Test Name: VOLATILES - SW8260C HS19040619-02 HS190406i9-08 S-3 {API Water) Duplicate 08Apr2019 09:15 08 Apr 2019 00:00 Date: 17-Apr-19 DATES REPORT Prep Date Analysis Date Matrix: Water 13 Apr 2019 17:28 13 Apr 2019 17:53 13 Apr 2019 18:18 13 Apr 2019 18:43 Matrix: Liquid 15 Apr 2019 19:59 15 Apr 2019 20:24 Matrix: Liquid 16 Apr 2019 15:46 Matrix: Liquid 15 Apr 2019 23:37 16 Apr 2019 00:02 DF 50 50 1000 50 50 Page 14 of29 HFNA-000003380 EPA Inspection Report - Page 1831 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL} HS19040619 Date: 17-Apr-19 QC BATCH REPORT NEW Batch ID: R.336576 ( 0} lnstnunent: VOA9 Method: VOLATILES SW8260C MBLK Client ID: Analyte Sample ID: Benzene 1, 2-Dich/oroethane-d4 Surr: 4-Bromofluorobenzene sur,.:01b,omoiluoromeiiiane Surr: Toluene-dB VBLKW-041219 Units: ug/L Analysis Date: 13-Apr-2019 14:09 Run ID: VOA.9_336576 SeqNo: 5035184 PrepOate: OF: 1 Result < 0.60 PQL 5.0 SPKVal SPK Ref Value %REC Control Limit RPD Ref RPD Value %RPD Limit Qual - ..............................................................~~~~ 44.32 48.5 0 50 0 97.0 82 115 45.96 0 50 0 91.9 73- 126 49.83 0 50 0 99.7 81 - 120 lCS Client ID: Analyte Sample ID: VLCSWi-190413 Units: ug/L Analysis Date: 13-Apr-2019 13:19 Run ID: VOA9_336576 SeqNo: 5035183 PrepDate: OF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPD Ref RPD Value %RPO Limit Qual Benzene Surr: 1, 2-Dich/oroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 20.08 5.0 44.3 0 49.82 0 48.17 0 49.48 0 20 0 100 74 - 120 50 0 88.6 70- 130 50 0 99.6 82- 115 o 50 96.3 73- 126 50 0 99.0 81- 120 MS Client ID: Analyte Sample ID: HS19040376-01 MS Units: ug/l Analysis Date: 13-Apr-2019 20:22 Run ID: VOA9_336576 SeqNo: 5035199 PrepDate: DF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPO Ref RPD Value %RPO Limit Qual Benzene 17.94 5.0 20 0 89.7 70 -127 Surr: 4-Bromofluorobenzene ---,~"" Surr: Dibromof/uoromethane Surr: Toluene-dB 49.48 47.55 49.63 0 50 0 50 0 50 0 99.0 82- 124 0 95.1 77 - 123 0 99.3 82- 127 Page 15 of 29 HFNA-000003381 EPA Inspection Report - Page 1832 of 1969 A.LS Houston, US Client: Project: Work:Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19040619 Date: 17-Apr-19 QC BATCH REPORT NEW Batch ID: R.336576 ( 0) MSO Client ID: Analyte Sample ID: HS1904037601MSD Units: ug/L Analysis Date: 13-Apr-2019 20:47 Run ID: VOA9_336576 SeqNo: 5035200 PrepDate: DF: 1 Result SPK Ref Control RPO Ref RPD PQL SPKVal Value %REC Limit Value %RPD Limit Qual Benzene Surr: 1, 2-Dichforoethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromof/uoromethane Surr: Toluene-d8 17.05 44.03 49.47 48.12 49.37 5.0 20 '''"'--------~"~"~" 0 50 0 50 0 50 0 50 The follol~ing samples were analyzed in this batch: )HS19040619-05 ~--" HS19040619-06 0 85.2 70 - 127 17.94 5.12 20 0 88. 1 70-126 43.48 1.28 20 0 98.9 82- 124 49.48 0.0222 20 0 96.2 77 - 123 .............. 47':55 1. 18 20 0 98.7 82 - 127 .. HS19040619-07 49.63 0.538 20 . ""''''''] Page 16 of 29 HFNA-000003382 EPA Inspection Report - Page 1833 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19040619 Dale: 17-Apr-19 QC BATCH REPORT NEW Batch ID: R.336593 ( 0) Instrument: Method: VOL.ATILES BY SW8260C MBLK Client ID: Analyte Sample ID: MBLKW1-041519 Units: ug/Kg Analysis Date: 15-Apr-201914:09 Run ID: VOA.8_336593 SeqNo: 5035772 PrepDate: DF: 50 Result PQL SPK Val SPK Ref Value %REC Control Limit RPD Ref RPO Value %RPD Limit Qual Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromof/uoromethane Surr: To/uene-d8 < 25 2348 2298 2340 2427 250 0 2500 0 2500 0 2500 0 2500 0 93.9 76- 125 0 91.9 80- 120 0 93.6 80 - 119 0 97.1 81 - 118 LCS Client ID: Analyte Sample ID: VLCSW1-041519 Units: ug/Kg Analysis Date: 15-Apr-2019 13:19 Run ID: VOA.8_336593 SeqNo: 5035771 PrepDate: DF: "I Result SPK Ref Control RPD Ref RPD PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1, 2-Dichforoethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 45.48 5.0 50 52.57 50.84 50.53 0 50 o 50 0 50 0 91.0 75 - 124 76 - 125 0 105 80-120 0 102 80-119 0 101 81 - 118 MS Client ID: Analyte Sample ID: HS19040330-01 MS Run ID: Result Units: VOA.8_336593 PQL SPK Val ug/Kg Analysis Date: 15-Apr-2019 16:14 SeqNo: 5036542 PrepDale: OF: 50000 SPK Ref Value %REC Control Limit RPD Ref RPD Value %RPO Limit Qua! Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromof/uoromethane Surr: Toluene-dB 1845000 2569000 2277000 2509000 2399000 240000 2.425e+006 0 76.1 70 - 130 0 2.425e+006 0 106 70- 126 0 2.425e+006 0 93.9 70- 130 0 2.425e+006 15 103 70-130 0 2.425e+006 0 98.9 70-130 Page 17 of29 HFNA-000003383 EPA Inspection Report - Page 1834 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19040619 Date: 17-Apr-19 QC BATCH REPORT NEW Batch ID: R336593 { 0 ) Instrument: VOA$ Method: VOL.ATILES BY SWS260C MSD Sample ID: HS19040330-01MSD Units: ug/Kg Analysis Date: 15-Apr-2019 16:39 Client ID: Analyte Run ID: VOA8_336593 Result PQL SPKVal SeqNo: 5036543 SPK Ref Value %REC PrepDate: Control Limit DF: 50000 RPO Ref RPD Value %RPO Limit Qual .................................................................~~~~~~~ _ j Benzene Surr: 1, 2-Dichloroethane-d4 21710()0 2539000 240000 2.425e+006 O 2.425e+006 0 89.5 70-130 1845000 16.2 30 0 105 70- 126 2569000 1.17 30 Surr: 4-Bromof/uorobenwne 2410000 0 2.425e+006 0 99.4 70 - 130 2277000 5.7 30 Surr: Dibromofluoromethane 2534000 O 2.425e+006 0 105 70-130 2509000 1.01 30 Surr: Toluene-dB 2363000 0 2.425e+006 0 97.4 70- 130 2399000 1.51 30 The following samples were analyzed in this batch: ~iST9040619~03 HsTo,foKf9=l)4....................................... --------- ---- ~-----------------------' Page 18 of29 HFNA-000003384 EPA Inspection Report - Page 1835 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19040619 Date: 17-Apr-19 QC BATCH REPORT NEW Batch 10: R.336631 ( O) Instrument: VOA8 Method: VOi.ATILES BY SW8280C MBLK Client ID: Analyte Sample ID: MBLK.W1-041619 Run ID: Result Units: VOA.8_336631 PQL SPK Val ug/Kg Analysis Date: 16-Apr-2019 09:31 SeqNo: 5036467 PrepDate: DF: 50 SPK Ref Value %REC Control limit RPD Ref RPD Value %RPO Limit Qual Benzene Surr: 1, 2-Dich/oroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB <25 2461 2378 2338 2511 250 0 2500 0 2500 0 2500 0 2500 0 98A 76- 125 0 95.1 80- 120 0 93.5 80 - 119 0 100 81 - 118 LCS Client ID: Analyte Sample ID: VLCSW1-041619 Units: ug/Kg Analysis Date: 16-Apr-2019 08:41 Run ID: VOA.8_336631 SeqNo: 5036466 PrepDate: OF: 1 Result SPK Ref Control RPO Ref RPD PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 43.8 5.0 50 51,57 0 50 49.59 0 50 50.04 0 50 50.39 0 50 0 87.6 75 - 124 0 103 76 - 125 0 99.2 B0-120 0 100 80-119 0 101 81 - 118 MS Client ID: Analyte Sample ID: HS19040609-01MS Units: ug/Kg Analysis Date: 16-Apr-201916:11 Run ID: VOA.8_336631 SeqNo: 5038071 PrepDate: DF: 50 Result SPK Ref Control RPD Ref RPO PQL SPKVal Value %REC Limit Value %RPD Limit Qual Benzene Surr: 1, 2-Dich!oroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 2017 2565 2428 2540 2506 250 2525 0 79.9 70 - 130 0 2525 0 102 70- 126 0 2525 0 96.2 70 - 130 rr 0 2525 101 70-130 0 2525 0 99.2 70-130 Page 19 of29 HFNA-000003385 EPA Inspection Report - Page 1836 of 1969 AlS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling {EOL) HS19040619 Date: 17-Apr-19 QC BATCH REPORT NEW Batch ID: R336631 ( 0) Instrument: VOAS Method: VOi.ATiLES BY SW8260C MSC! Sample ID: HS19040609-01MSD Units: ug/Kg Analysis Date: 16-Apr-201916:36 Client ID: Analyte Run ID: VOA.8_336631 Result PQL SPK Val ........ .....................................................................................~~~~~~~~~~ SeqNo: 5038072 SPK Ref Value %REC PrepDate: Control Limit OF: 50 RPD Ref RPD Value %RPD limit Qual Benzene Surr: 1, 2-Dich!oroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromof/uoromethane 2038 2522 2370 2536 250 2525 0 2525 0 2525 0 2525 0 80.7 70 - 130 ''''''''''''''''''''''''''''''''''''''''"""~" 0 99.9 70- 126 2017 2565 1.03 30 1.66 30 0 93.8 70 - 130 2428 2A3 30 0 100 70- 130 254() 0.166 30 Surr: Toluene-dB 2428 The follov.ing samples were analyzed in this batch: 0 2525 --------"~"" 0 96.2 70 - 130 2506 3.15 30 Page 20 of29 HFNA-000003386 EPA Inspection Report - Page 1837 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19040619 Date: 17-Apr-19 QC BATCH REPORT NEW Batch ID: R336662 ( 0) Instrument: VOA9 MBLK Client ID: Analyte Sample ID: VBLKW-190415 Units: ug/L Analysis Date: 15-Apr-201919:27 Run ID: VOA.9_336662 SeqNo: 5036958 PrepDate: DF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPD Ref RPD Value %RPD Limit Qual Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromof/uoromethane Surr: Toluene-dB < 0.60 5.0 43.89 0 50 48.12 0 50 46.65 0 50 49.09 0 50 0 87.8 70- 130 0 96.2 82 - 115 0 93.3 73- 126 0 98.2 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-190415 Units: ug/L Analysis Date: 15-Apr-2019 18:38 Run ID: VOA.9_336662 SeqNo:5036957 PrepDate: DF: 1 Result SPK Ref Control RPD Ref RPD PQL SPKVal Value %REC Limit Value %RPD Limit Qual Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 17.87 5.0 20 42.9 49.22 0 50 47.12 0 50 4R12 0 50 0 89.3 74 - 120 70 - 130 0 98.4 82- 115 0 94.2 73-126 0 98.2 81 - 120 MS Client ID: Analyte Sample ID: HS19040747-02MS Units: ug/L Analysis Date: 15-Apr-2019 22:23 Run ID: VOA.9_336662 SeqNo:5036965 PrepDate: DF: 1 Result SPK Ref Control RPD Ref RPD PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene Surr: 1, 2-Dich/oroethane-d4 Surr: 4-Bromof!uorobenzene Surr: Dibromof/uoromethane Surr: Toluene-dB 3331 5.0 38.82 47.38 0 46.92 0 45.78 0 20 2501 4150 70 - 127 ----- -- "~"---"~"-- 50 0 77.6 70- 126 50 0 94.8 82- 124 50 0 93.8 77 -123 50 0 91.6 82- 127 SEO Page 21 of29 HFNA-000003387 EPA Inspection Report - Page 1838 of 1969 AlS Houston, US Client Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19040619 Dale: 17-Apr-19 QC BATCH REPORT NEW Batch ID: R336!l62 ( 0 ) Instrument: Method: VOLATILES - SW8260C MSD Client ID: Analyte Sample ID: HS19040747-02MSD Run ID: Result Units: VOA9_336662 PQL SPKVal ug/l Analysis Date: 15-Apr-2019 22:48 SeqNo: 5036966 PrepDate: DF: 1 SPK Ref Value %REC Control limit RPD Ref RPD Value %RPO Limit Qual Benzene Surr: 1,2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene , .................. ,,,,,,,,,,,,,,,, ............. ~"~" Surr: Dibromofluoromethane Surr: Toluene-dB 2489 5.0 44.95 0 42.38 0 4921 0 49.48 0 The following samples were analyzed in this batch: rlS19040619-02 20 2501 50 0 50 0 50 0 50 0 HS 19040619-08,,,,,,,,,, -62.6 89.9 84.8 98.4 98.9 70 -127 70 126 82 - 124 77 - 123 82- 127 3331 38.82 47.38 46.92 45.78 28.9 20 SREO 14.6 20 11. 1 20 4.77 20 7.72 20 ccccccccccccccc-~l Page 22 of29 HFNA-000003388 EPA Inspection Report - Page 1839 of 1969 ALS Houston, US Client Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOl) HS19040619 Date: 17-Apr-19 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND 0 p R s u ..................D e s c r i p t i o n .. Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is > 4 times amount spiked Dual Column results percent difference > 40% RPD above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDUSDL Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SDL TRRP Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program UnitReported ... P~~cription mg/Kg Milligrams per Kilogram mg/L Milligrams per Liter Page 23 of29 HFNA-000003389 EPA Inspection Report - Page 1840 of 1969 ALS Houston, US Date: H-Apr-19 CERTIFICATIONS,ACCREDITATIONS & LICENSES Number T10470231-18-21 R193 2018-2019 004438 03087 L2231 123043 - 2018 30-Apr-2019 E-10352 2018-2019 31-Jul-2019 Oklahoma 2018-156 31-Aug-2019 North Carolina 624-2019 31-Dec-2019 California 2919, 2018-2019 30-Apr-2019 Maryland Arkansas 343, 2018-2019 30-Jun-2019 .... c c c c c c c c c c c c c c c - - - - - - - - - ~ - - - - - - - - - 19-028-0 .....................................................................................- - - - - ~ - - - - - - - - ~ Page 24 of29 HFNA-000003390 EPA Inspection Report - Page 1841 of 1969 A.LS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling {EOL) HS19040619 Lab Samp ID HS19040619-01 HS19040619-02 HS19040619-03 HS 19040619-04 HS 19040619-05 HS 19040619-06 HS19040619-07 HS 19040619-08 HS 19040619-09 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40} S-6 {T-41) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Action Login Login Login Login Login Login Login Login Login Date 4/10/2019 8:10:13 PM 4/10/2019 8:10:13 PM 4/10/2019 8:10:13 PM 4/10/2019 8:10:13 PM 4/10/2019 8:10:13 PM 4/10/2019 8:10:13 PM 4/10/2019 8:10:13 PM 4/10/2019 8:10:13 PM 4/10/2019 8:10:13 PM Person PMG PMG PMG PMG PMG PMG PMG PMG PMG Date: 17-Apr-19 SAMPLE TRACKING New location VOA160 VOA160 VOA160 VOA"l60 VOA160 VOA160 VOA160 VOA160 VOA160 Page 25 of29 HFNA-000003391 EPA Inspection Report - Page 1842 of 1969 AlS Houston, US Client Name: Work Order: Navajo Refining HS19040619 Datemme Received: Received by: Date: 17-Apr-19 Sample Receipt Checklist 09-AJ;,r-2019 12:54 PMG Checklist completed by: Paresh M. Giga eSignature Matrices: 10-Apr-2019 Date Reviewed by: Carrier name: Co rev,G r a n d i t s - - - , - - - T - 1 2 - A p r - 2 0 1 9 '" eSignature i Date Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? VOA/TX1005ITXi006 Solids in hermetically sealed vials? Chain of custody present? Chain of custody signed when relinquished and received? Samplers name present on COC? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Sufficient sample volume for indicated test? All samples received within holding time? Containerrremp Blank temperature in compliance? Temperature(s )IThermometer(s ): Cooler(s)/Kit(s): Datemme sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Login Notes: Client Contacted: Contacted By: Date Contacted: Regarding: Comments: Yes No Yes No Yes No Yes No Yes No Yes No Yes No Not Present Not Present Not Present Not Present 1 Page{s} COG 1Ds:None Yes No Yes No Yes No Yes No Yes No Yes No .?cl U/C !:IR11 Foam ........................................................................................""""""'"..............::,.......- ----.' /9/19 20:00 ~ ves@ No Yes No Yes No No VOA vials submitted N/A NIA Person Contacted: Corrective Action: Page 26 of29 HFNA-000003392 EPA Inspection Report - Page 1843 of 1969 Chain of Custody Form Page ...~..........?.!...... _.1_ ..J D Cincinnati, OH +I 513 7.'l:J 5336 D !~e~~1f;! 2600 D Fort Col/Ins, CO +19704901511 D +I 616 399 6070 Hol/ar,d,MI 0 +I 2815305656 Houston, TX D /11/iddlerowr,, PA +I 717944 5541 D Salt lake City, UT + 1 801 266 7700 D Spring City, l'A +16109484903 D York,PA +1717505 5280 ):::y:::)~~:~r:~:Rt:~~r! ,,.. ,,,,.. ,,.....,,,,,,,,,,,, ................- ...- i t l r i ~ :..- - ".,..""'""":~~,,,~ :.:.::.>.t.-a.i.ri.p.~.i.:i.:.v.:.N.o..o.n~,iNavajoRefiningCompa...n..y..._L..L_C__t J II' HS19040619 Navajo Refining Company Al BWON Monthly Sampling (EOL) 00;! Ea!f! Ma!n . ~- ;?" . ml 11111111111 }:/:\\:/:/:~# ...,.. .}~i~i~#i~~iifArtesia, NM 88211-0159 (575) 748-3311 -----+'-.,_,_.,....;,s;..,,,...,,;,,.,...-,-;"'-+-------------1 1111 II [f:;:;:~~~~;~1.~;~:i:1:;,;:~~~i~~,w.m ::~~;:1:::::\:i::(:::i:::::f ::;::::~#~#~~:~itriplklit - \\JS~1 {AP! HC} }i/lS-3 (API Water) ::>~:Js-s (T-40) \{JS-6 (T-41) /~\I Field Blank ______________.... _,-._,,,.,,. __ 04108/1 tCq.kY1C "'t""""'"1f'""""' !-L 1,,.t ;! t 1 d Turfu1.round Ttroe:.: D STD 10 Wk Days fl) 5 WDays OO!ller _ _ __ 0 2 Wk Days D 24 Hour "*' po. :r-I "Tl z 0 Note: Any changes must be made In writing once 1111mples and COC: Form have been submitted to Al$ Laboratory Group. i'. . 0..,1,J l ' "0 ~ .J;;9,PYri!I.ht 2009 by ALS Laboratory Group 0 Cti-u\M'"'I{ {;;) t.:)' ,~ ~(~Y~...../ 0 J- , Cl o 0 Page 27 of29 0 (,) (,) (!) (,) EPA Inspection Report - Page 1844 of 1969 ~ Us;e ofthlsi ltYstem eoi"l~itute! your sgreemerit to the service rondltkin:s lri the current ~dEl Ss!lrvltie Gu!d~f a\l'ail~ble on f~d~.tom. FedEx wlll not be res:pons;H,iefcr any da.im in el(.CeiE:i. of $100 pm pachge9 whi!thetthes re!S~dt of !os.s~ demsi:~... ~ deloy, non-delilrery, m!,dellvory, or mi,lnfurmlion, "nl"' you do<lare hlghor,ale, poy on oddltiooal tharge, dowment : ',OUf.&ct.uel lo~, end flle l:I timeJy de{m. Urnit:at!onsfou~d ii'l the. cllrr0nt f'edfx SaMiee Gllide apply, Vour rl@itt~ ~~cover from' t Fe<lf,forany loS&, indudlng intrinsic I"" otthe pe""'ge, losfol,ales, !noom,, lnte.,,st, profit, attomoy', ree,, ms, ond otha, forms of domoge whether di reel, incidents I, oonsequeotiI, 01,patlal I llmitad to the g1elr of $100 ortha outhorlIOd - dt=dar$1 ~alue. Reoo~rv tannot ~xceecl actY.al doctur~med loss. Ma:ii:imu.~for Items of 0.Xtr11offlinary wiue i:s $1,000, e.g.. jeW81,Y, predou melols, negotiable lnstrumoot aod <4ho, ttoms llsted in our Sonnee <iMcle. Wrtl:ten do!m, must be flied with!" strict time limit,, ,ee curreot l'edfx SeM<e Gulde, ~. :~:~ ~:~~~ Afterjiirln~;iath!~ffi.b!J!!I: CONSICN!t COPY O PLEASE PL/ICE IN FRONT 01' POUCH 1, !='dd th* ~n1'9cl psge l!l:kms the h.t1rlzcrn:&e !lru:!. ~ 2. Pio< i.ool in ~!pplo; po,h n<! lfm ~ to ioor ohlpmoni ~ m> ~1 I ir~~:r ~ Bj irn ~~ ~~ ~~- ~ I w i u,~---<,,L..~ !~ iiiil==~ ;::~-:-i1s~ . 4'\ ~ ] : UI i C) ~ ! i $! ii ~If = w -,, o i <.:JS 0 c ~I i;OS:t;,oo;:o ~ =r l;:c::: -1 0 m.l ?.:;,i::: lli!ii mm 00 -<.m).ll 1 ;;;;;.. -l z iJJ; X p .... ::::1::;; >llfg 'Tl l>; ;i;: - ~! ~0 ::t z~ OO~j\i: -~ ~ [ ::a ' - lij c:::, -0 ~ ; ;~ . ~ .. w iii!;! -I ~ . r' r- ;:::g'c ~_ 0 C: ;gm . :i .;. I ' !i iOi[ :~:jc$:<1;;j - .., ~ ... "" - ;1!1- ~~ ~ m "ti ! -a ;:a ;:a z ... > ~ :i,,, - G'l 0 i.:, ~z - ~ :c:~ 8 =i ~ ~ ~- I ~-,~ - :r-I "Tl z 0 0 w.:;Qs ll'i~nSl~ mu 0 - 0 Page 28 of29 0 (,) (,) (!) .i:,,. EPA Inspection Report - Page 1845 of 1969 SHIPPER'S llECLARATION FOR DANGEROUS GOODS Sll!pp.. I NAVAJO REFINING COMPANY C/0 AQUA MICROBICS I t 501 EMAIN ARTESIA NM88210 US j Ct'l~Blgnee t Corey Gramiits ALS 10450 Stancliff Sui!e210 HOUSTON TX 77099 US ~ r"" <omple!od snd.;g,,od oopii!S orn,is De<lam/on mum be mlll<ledw!l!oopemk>f HW./:WORT DETAILS Thi oh!pmont Is wlttllo Ills ~ !Imitations pmtcribe!.1 ftlr. {dmb> mm opp!lcoblo} Al!J)Oriof""",m"' ARTESIA (Provide at least thffle eopll!S to nlrllne.) AlrW.ybnl No. 709306590762 Pogo 1 cf 1 Pago(! 1.Shlpl"'f' R-"" lil""'bo' /opl1"m!IJ FX 18 Compliant Express CAFE3211 WARNING Failure to comply with all respects with the applicable Dangerous Goods Regulations may lie in breach of the appl!eable law ,subject to legal penalties. ! - "'W"I~ O..Un.Uoo: HOUSTON -,o-,,~-r ~ ==4 --- NATURE AND QUANTITY OF DANGEROUS GOODS UN Humbof or1m1mcouoo Numoor, P"'fJ'll "111pp/ng n..,o. a,.. or llMsl<>n (8"bs/illolydsli;I, l'J"e/<lng group (Ii l'llr/U/o!iG, aoo all oilier - ""!itlm<I mfomlo!ion. UN 3266, Corrosive liquid, basic, Inorganic, n.o.s.(Sodium Hydroxlde),B,111 - UN 1261!, Petroleum distillates, n.o.s.,3,11111 0.04 L/1366 t All Packed In One FIBREBOARD BOX Q=0.1 0.08 U/854 ttt~ t~~ l\ddffionai Handling lmcrma,Uon - 24-Hour Emsrgency Response- CHEMTREC 1"500-424-$300, CCN 201319 - ~ Illereby declan! ttlot !he oo..i,,m,, ol!Ills oMolgomont ro fully ond """ratoly <l<!aorib! a!Kwo llylbo P"'f"'nhlpplng oamo, ..d""' tlulffied, packaged1 maril:ed and labeilt.sdipllesrdedf and art lni 8.11 t mspee:t8 h'II pmpertood~ fottran:iap~rt ttecording to 1111ppiieib!& - !-,.,,., d No!l<>I OOYom.,,.oml Raguiotlooo. Id..1...11111t au oftha 8ppUubie air tmnap(lrt r&quirmminl& hav1111 bem mat. 16004249300 em.,v.. .y n , - N . . ,. . . . Neme/TiUe of Sfgnato1Y Brady Hubl>erolEmlronmenlal coom1M1or Plaoo and Paw Art~~.lJl, NM Mffl812tma Signature Brady Hullbon:I jlo,._,,lo;I...~ (J -t ~ z ------------~------~~-'-HNN-~-'---~-""" I r~ ~};n?::3A.C1'NE MAllE:RJAL ISHlABE~T .A.CCEPTABUS FOR fASSE11:1GR SURCIIUFr, TH! !Ul!PME!ffCOlfrAIHS RM!O.\Ctf~ MA.ru.f4 !HnNDED FOR USE !HOR INCi!JEl!T Ta RESl!!.ARCH, MmaCAL Cl.AG.MOW! OR TRE'1.nlreH'r. ADR ll!UROPEAN mA.N9PORT BTATEMEPO': CARRIAGE IN ACCORDANCE mffl 1.1'..U.1 "Tl :r- ~ 0 0 !.O\l(lS.~HYl!ilS:VifH 0 - 0 Page 29 of29 0 (,) (,) (!) 01 EPA Inspection Report - Page 1846 of 1969 10450 StancHff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 April 17, 2019 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling {EOL} Dear Gabriela, Work Order: HS19040623 ALS Environmental received 4 sample(s) on Apr 09, 2019 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, Generated Sy: JUMOKE.LAWAL Corey Grandits Project Manager Ri9ht Solutions Right Partner www,a!sgbbaLcom Page 1 of22 HFNA-000003396 EPA Inspection Report - Page 1847 of 1969 ALS Hcmston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19040623 Lab Samp ID HS19040623-01 HS19040623-02 HS19040623-03 HS19040S23-04 Client Sample ID S-1 (API HC} S-3 (API Water) S-5 (T-40) S-6 (T-41) Matrix Liquid Liquid Liquid Liquid Date: 17-Apr-19 SAMPLE SUMMARY TagNo Collection Date 08-Apr-2019 09:04 08-Apr-2019 09:15 08-Apr-2019 08:42 08-Apr-2019 08:47 Date Received 09-Apr-2019 12:54 09-Apr-2019 12:54 09-Apr-2019 12:54 09-Apr-2019 12:54 Hold :?.............~ . ::: ~ ::: ~ :::................~. :::..............:. :: ::: ::: ::: ::: :::.................~ :::--............:. :: ::: ::: L............J ~...............'x ::: ::: L..........J Page 2 of22 HFNA-000003397 EPA Inspection Report - Page 1848 of 1969 ALS Houston, US Date: 17-Apr-19 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19040623 Work: Order Comments CASE NARR.ATIVE The analysis for Specific Gravity was subcontracted to ALS Environmental in Holland, Ml. Final report attached. Page 3 of22 HFNA-000003398 EPA Inspection Report - Page 1849 of 1969 ALS Houston, US Date: 17-Apr-19 Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 {AP! HC) 08-Apr-2019 09:04 AN.AlYTICAL REPORT WorkOrder:HS 19040623 Lab ID:HS19040623-01 Matrix:Liquid ANALYSES RESULT SUBCONTRACTED ANALYSIS SPECIFIC - ~~yrry Subcontract Analysis See Attached QUAL MDL REPORT LIMIT UNITS DILUTION FACTOR DATE ANALYZED -----------------------------------------------------------------------------------~---------------- Method:NA Analyst: ~UB!iQ 0 NA 17-Apr-2019 10:14 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of22 HFNA-000003399 EPA Inspection Report - Page 1850 of 1969 ALS Houston, !JS Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (AP! Water) 08-Apr-2019 09:15 ANALYSES RESULT QI.JAL MDL ~UBCONTAACTED ANALYSIS SPECIFIC GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 17-Apr-19 ANALYTICAL REPORT WorkOrder: HS19040623 Lab !D:HS19040623-02 Matrix:Uquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst f3UB1-i0 17-Apr-2019 10:14 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of22 HFNA-000003400 EPA Inspection Report - Page 1851 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 08-Apr-2019 08:42 ANALYSES RESULT QUAL MDL $UBCONTRACTEl'J ANALYSIS SPECIFIC '.GRAVITY Subcontract Analysis See Attached Method:NA 0 REPORT LIMIT Date: 17-Apr-19 ANALYTICAL REPORT WorkOrder:HS 19040623 Lab 1D:HS19040623-03 Matrix: Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SU~HQ 17-Apr-2019 10:14 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of22 HFNA-000003401 EPA Inspection Report - Page 1852 of 1969 ALS Houston, US Client: Project Sample ID: Collection Date: ANALYSES Subcontract Analysis Navajo Refining Company BWON Monthly Sampling {EOL) S-6 (T-41) 08-Apr-2019 08:47 RESULT QUAL MDL See Attached 0 REPORT LIMIT Date: 17-Apr-19 ANALYilCAI.. REPORT WorkOrder: HS19040623 Lab 1D:HS19040623-04 Matrix:Uquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst SUBHO 17-Apr-2019 10:14 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of22 HFNA-000003402 EPA Inspection Report - Page 1853 of 1969 ALS Houston, US Date: 17-Apr-19 Client: Project: Work.Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19040623 DATES REPORT Sample ID Client Samp ID Collection Date TCLP Date Prep Date Analysis Date OF --------------------------------------------------- )::latch ID R.336733 Test Name: SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Matrix: Liquid HS 19040623-01 HS 19040623-02 HS 19040623-03 HS 19040623-04 S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) 08 Apr 2019 09:04 08 Apr 2019 09:15 08 Apr 2019 08:42 08 Apr 2019 08:47 17 Apr 2019 10:14 17 Apr 2019 10:14 17 Apr 2019 10:14 17 Apr 2019 10:14 Page 8 of22 HFNA-000003403 EPA Inspection Report - Page 1854 of 1969 ALS Houston, US Client: Project: Work:Order: Navajo Refining Company BWON Monthly Sampling (EOl) HS19040623 Date: 17-Apr-19 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND 0 p R s u Description Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is > 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDUSDL ~.C:.~?~Yl'!.I ...................... Description.. DCS Detectability Check Study DUP Method Duplicate LCS Laboratory Control Sample LCSD Laboratory Control Sample Duplicate MBLK Method Blank MDL Method Detection limit MQL Method Quantitation limit MS Matrix Spike MSD Matrix Spike Duplicate PDS Post Digestion Spike PQL Practical Quantitaion Limit SD Serial Dilution SDL Sample Detection limit TRRP Texas Risk Reduction Program Page 9 of22 HFNA-000003404 EPA Inspection Report - Page 1855 of 1969 A.LS Houston, US Agency Louisiana Dept of Defense Kentucky Kansas Oklahoma North Carolina California Maryland Arkansas Date: 17-Apr-19 CERTIFICA.TIONS,A.CCREIJITA TIONS & LICENSES 004438 03087 ANAB L2231 123043- 2018 0352 2018-2019 2018-156 624-2019 2919, 2018-2019 343, 2018-2019 19-028-0 Expire Date 30-Apr-2019 30-Apr-2019 29-Jun-2019 31-Dec-2019 30-Apr-2019 30-Jun-2019 27-Mar-2020 Page 10 of22 HFNA-000003405 EPA Inspection Report - Page 1856 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS 19040623 LabSamp ID HS19040623-01 HS 19040623-02 HS 19040623-03 HS 19040623-04 Client Sample ID S-1 (AP! HC) S-3 (API Water) S-5 (T-40} S-6 (T-41) Action Login Login Login Login Date 4/10/2019 8:43:16 PM 4/10/2019 8:43:16 PM 4/10/2019 8:43:16 PM 4/10/2019 8:43:16 PM Person PMG PMG PMG PMG Date: 17-Apr-19 SAMPLE TRACKING New Location Sub Sub Sub Sub Page 11 of22 HFNA-000003406 EPA Inspection Report - Page 1857 of 1969 ALS Houston, IJS Client Name: Work Order: Navajo Refining HS19040623 Dateffime Received: Received by: Date: 17-Apr-19 Sample Receipt Checklist 09-Mr-~1~ 12~fi4 PMG Checklist completed by: Paresh M Gi,.,a eSignature " Matrices: 10-Apr-2019 Date Reviewed by: Carrier name: ;~~:t~:tl!l~i~~ FedEx """""""I 12-A68~;019 Shipping container/cooler in good condition? Custody seals intact on shipping containerlcooler? Custody seals intact on sample bottles? VOAffX1005ffX1006 Solids in hermetically sealed vials? Chain of custody present? Chain of custody signed when relinquished and received? Samplers name present on COC? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Sufficient sample volume for indicated test? All samples received within holding time? Containerffemp Blank temperature in compliance? Temperature(s)ffhermometer(s): Cooler(s)/Kit(s): Date/Time sample(s) sent to storage: Waler - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: login Notes: Client Contacted: Contacted By: Date Contacted: Regarding: Comments: Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes~ 1(2.,7c/2.7c U/C Not Present Not Present Not Present Not Present 1 Page{s} COG 1Ds:None - LJ Yes D Yes L....J Yes sssssssssss"---- D No No VOA r:1 No NIA L....J No N/A vials submitted Person Contacted: Corrective Action: Page 12 of22 HFNA-000003407 EPA Inspection Report - Page 1858 of 1969 17-Apr-2019 Corey Grandits ALS Environmental 10450 Stancliff Rd Suite 210 Houston, TX 77099 Re: HS19040623 Dear Corey, Work Order: 1904851 ALS Environmental received 4 samples on 12-Apr-2019 09:30 AM for the analyses presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental - Holland and for only the analyses requested. Sample results are compliant with industry accepted practices and Quality Control results achieved laboratory specifications. Any exceptions are noted in the Case Narrative, or noted with qualifiers in the report or QC batch Information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained from ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. The total number of pages in this report is 10. If you have any questions regarding this report, please feel free to contact me: ADDRESS: 3352128th Avenue, Holland, Ml, USA PHONE: +1 (616) 399-6070 FAX: +1 (616) 399-6185 Sincerely, Chad Whelton Project Manager Report of Laboratory Analysis Certificate No: MN 026-999-449 HFNA-000003408 EPA Inspection Report - Page 1859 of 1969 ALS Group, USA Client: Project: Work Order: ALS Environmental HS19040623 1904851 !,ah Samp m Client Sample ID 1904851-01 HS19040623-0l l 904851-02 HS l 9040623-02 l 904851-03 HS19040623-03 1904851-04 HS 19040623-04 Date: 17-Apr-19 Matrix Liquid Liquid Liquid Liquid Work Order Sample Summary Tag Number S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Collection Date 4/8/2019 09:04 4/8/2019 09: 15 4/8/2019 08:42 4/8/2019 08:47 Date Receiveq 4/12/2019 09:30 4/12/2019 09:30 4/12/2019 09:30 4/12/2019 09:30 Hold r:J Page 14 of22 Sample Summary Page 1 of l HFNA-000003409 EPA Inspection Report - Page 1860 of 1969 ALS Group, USA Client: Project: WorkOrder: ALS Environmental HS19040623 1904851 Date: l 7-Apr-19 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H Hr J ND 0 p R s u X Description Value exceeds Regulatory Limit Estimated Value Analyte is non-accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside ofHolding Time BOD/CBOD Sample was reset outside Hold Time, value should be considered estimated. Analyte is present at an estimated concentration between the MDL and Report Limi! Not Detected at tbe Reporting Limit Sample amount is > 4 times amount spiked Dual Column results percent difference> 40% RPD above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDL Analyte was detected in the Method Blank bet,veen the MDL and Reporting Limit, sample results may exhibit background or reagem contamination at the observed level. Acrom,'m Description DUP Method Duplicate LCS Laboratory Control Sample LCSD Laboratory Comrol Sample Duplicate LOD Limit of Detection (see IvIDL) LOQ Limit ofQuantitation (see PQL) :tvIBLK Method Blank MDL Method Detection Limit MS Matrix Spike MSD Matrix Spike Duplicate PQL Practical Quantitation Limit RPD Relative Percent Difference TDL Target Detection Limit TNTC Too Numerous To Count A APHA Standard Methods D ASTM E EPA SW SW-846 Update III Units ReQorted none Description Page 15 of22 QFPage 1 ofl HFNA-000003410 EPA Inspection Report - Page 1861 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS19040623 HS 19040623-01 4/8/2019 09:04 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 17-Apr-19 Result Qual Report Limit Work Order: 1904851 Lab ID: 1904851-01 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.944 D5057-90 none Analyst: RZM 4/16/2019 04:10 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 16 of22 Analytical Results Page l of 4 HFNA-000003411 EPA Inspection Report - Page 1862 of 1969 ALS G:roup, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS19040623 HS 19040623-02 4/8/2019 09:15 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 17-Apr-l9 Result Qua] Report Limit Work Order: 1904851 Lab ID: 1904851-02 Matrix: LIQUID Units Dilution Factor Date Analyzed 0.998 D5057-90 none Analyst: RZM 4/16/2019 04:10 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 17 of22 Analytical Results Page 2 of 4 HFNA-000003412 EPA Inspection Report - Page 1863 of 1969 ALS Group, USA CJient: Project: Sample ID: Collection Date: ALS Environmental HS 19040623 HS19040623-03 4/8i2019 08:42 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: J7-Apr-19 Result QuaJ Report Limit Work Order: 1904851 Lab ID: 1904851-03 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.13 none Analyst RZM 4i16/2019 04:10 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 18 of22 Analytical Results Page 3 of 4 HFNA-000003413 EPA Inspection Report - Page 1864 of 1969 ALS G:roup, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS19040623 HS l 9040623-04 4/8/2019 08:47 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 17-Apr-19 Result Qual Report Limit Work Order: 1904851 Lab ID: 1904851-04 Matrix: LIQUID Units Dilution Factor Date Analyzed 1.14 none Analyst: RZl\/1 4/16/2019 04:10 PM Note: See Qualifiers page for a list of qualifiers and !heir definitions. Page 19 of22 Analytical Results Page 4 of 4 HFNA-000003414 EPA Inspection Report - Page 1865 of 1969 ALS Group, USA Client: ALS Environmental Work Order: 1904851 Project: HS19040623 Date: 17-Apr-19 QC BATCH REPORT Batch ID: R25S5S4 Instrument ID WETCHEM Method: 05057'-90 DUP Sample ID: 1904851-02A DUP Client ID: HS19040623.02 Run ID: WETCHEM_190416H Units: none SeqNo: 5609851 Analysis Date: 411612019 04:10 PM Prep Date: DF: 1 Analyte Result POL SPK Val SPKRef Value Control %REC Limit RPD Ref Value %RPD RPD Limit Qual Specific Gravity 0.9998 0 0 0 0 0-0 0.9978 0.2 20 The following samples were analyzed in this batch: i904851-01A 1904851-04A 1904851-02A 1904851-03A Note: See Qualifiers Page for a list of Qualifiers and their explanation. Page 20 of22 QC Page: 1 of 1 HFNA-000003415 EPA Inspection Report - Page 1866 of 1969 10450 Stancilff Rd, Ste 210 Houston, rx 77099 T: +l 281 530 56S6 IF; +1 281 530 5887 www.alsglobal.com Subcontract Chain of Custody COC ID: :U.109 ALS Group USA, Corp. 3352 ~ 128th Ave Hollancl, MI 494249263 CUSTOMER INFORMATION; Comp.tny: ALS Houston Contact: Corey Gram:ilts Address: 10450 Stancliff Rd, Ste 210 Phone: +1 281 530 5656 Email: Coray.Grand!ts@alsglobal.com Alternate Contact: Email! Phone: +1 i:i16 399 6070 INVOICE INIFOR.MATI:ON: COmp.tny: ALS Houston contact: Address: Accounts Payable 10450 Stancliff Rd, Ste 210 Phone: +1 281 530 S656 Reference: HS:19040523 TSR: Houston House Acct 1, HS19040623..01 S-1 (AP! HC) Sub Specific Gravity to ALS Holliii!nd 2, HS:19040623..02 S-3 (API Wa~r) Sub Spedflc Gravity to ALS Holland 3, HS1!HJ40li23..0:3 i!iHS f'f-40) Sub Spec!flc Gravity to ALS Holland 4. HS:1.9040623~04 S-6 (T,4:1.) Sub Specific: Gravity to ALS Holland Liquid Liquid Liquid Uquld OB Apr 2019 09:04 16 Apr 2019 08 Apr 2019 O!h 15 16 Apr 2019 08 Apr 2019 08:42 15 Apr 2019 08 Apr 2019 08:47 16 Apr 2019 comments: Please analyze for the analysis listed above. Send report to the emails shown above. QC Leveb STO (Laboratory Standard QC: method blank and LC$ required) Relinquished By; Received Sy: Coo!er ID(s): Date/Tlme; Date/Tlme; Temperature{s); Page 21 of 22 HFNA-000003416 EPA Inspection Report - Page 1867 of 1969 ALS Group, USA Sample Receipt Checklist Client Name: Work Order: A.LS HOUSTON 1904851 Checklist completed by .Jt,__ '--C,,,_, eSignature Matrices: Carrier name: Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler1 Custody seals intact on sample bottles? Chain of custody present? Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Sample(s) received on ice? Temperature(s)ffhermometer{s): Cooler{s)/Kit(s}: Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: 12-Apr-19 Date Date/Time Received: Received by: 12-Apr-1!Hl9:30 DS Reviewed by: c~.e )ckWt:.... eSignature Yes l~] Yes l~] Yes Yes iv'! Yes iv'! Yes !y'i Yes vi Yes ~ Yes ~ Yes ~ Yes ~ Yes ~ i3.6/3.6 C No Not Present No Not Present No Not Present ~ No No No No No No No No No SR2 4/12/2019 12:04:54 PM Yes No Yes No Yes No No VOA vials submitted [~J NIA ~ NIA ~ Login Notes: 12-Apr-19 Date Client Contacted: Contacted By: Comments: CorrectiveAction: Date Contacted: Regarding: Person Contacted: Page12of22 SRC Page 1 of 1 HFNA-000003417 EPA Inspection Report - Page 1868 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 May 17, 2019 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 laboratory Results for: BWON Monthly Sampling {EOL} Dear Gabriela, Work Order: HS190506134 ALS Environmental received 4 sample(s) on May 10, 2019 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, It should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to cal! me. Sincerely, Generated Sy: COREY.GRANDITS Corey Grandits Project Manager Ri9ht Solutions Ri9ht Partner www,ahgbhaLcnm Page 1 of23 HFNA-000003418 EPA Inspection Report - Page 1869 of 1969 A.LS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19050684 Lab Samp ID HS19050684-01 HS19050684-02 HS19050684-03 HS19050684-04 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) Matrix Liquid Liquid Liquid Liquid Date: 17-May-19 SAMPLE SUMMARY TagNo Collection Date 09-May-2019 09:28 09-May-2019 09:39 09-May-2019 09:06 09-May-2019 09:12 Date Received 10-May-2019 09:15 10-May-2019 09:15 10-May-2019 09:15 10-May-2019 09:15 Hold ,:.....,.....::; ~ ~ t..........J ,::-.,,,...~ ~ ~ L........J. L.w.1 ,:.-..-..-..-..-..-:;: ~ ~ t...............l 1...............1 Page 2 of23 HFNA-000003419 EPA Inspection Report - Page 1870 of 1969 AlS Houston, US Date: 17-May-19 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19050684 Work Order Comments CASE NARRATIVE The analysis for Specific Gravity was subcontracted lo ALS Environmental in Holland, Ml. Final report attached" Sample S-1 (API HC) had limited volume, ALS Holland was unable to perform analysis" Page 3 of23 HFNA-000003420 EPA Inspection Report - Page 1871 of 1969 AlS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 09-May-2019 09:39 ANALYSES RESULT QUAL MDL $0BCOlm:tACTED ANALYSIS SPECIFIC ~RA,V!TV Subcontract Analysis See Attached Methcd:NA 0 REPORT LIMIT Date: 17-May-19 ANALYTICAL REPORT Work0rder:HS19050684 lab ID:HS19050684-02 Matrix:liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst SUBHO 17-May-2019 13:07 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of23 HFNA-000003421 EPA Inspection Report - Page 1872 of 1969 ALS Houston, US Date: 17-May-19 Client Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 09-May-2019 09:06 ANALYTICAL REPORT WorkOrder:HS 19050684 lab ID:HS19050684-03 Matrix:Uquid ANALYSES RESULT QUAL MDL REPORT LIMIT UNITS DILUTION FACTOR DATE ANALYZED s=U""a""c""o=N=r=AA~C=re=o~A=NA""L~Y""'S"'"!S"'"S~P""'E"'C""!F""IC=---M-et-h-od_:_N_A--------------ss,ss-"----AF"n"'ai""ys"C"t:- ~~VffY Subcontract Analysis See Attached 0 SL1,3tiQ NA 17-May-2019 13:07 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of23 RIGHT SOUJTIONS j RIGHT PARTNER HFNA-000003422 EPA Inspection Report - Page 1873 of 1969 ALS Houston, US Client Project: Sample ID: Collection Date: ANALYSES Subcontract Analysis Navajo Refining Company BWON Monthly Sampling (EOL) S-6 {T-41) 09-May-2019 09:12 RESULT QUAL MDL See Attached 0 REPORT LIMIT Date: 17-May-19 ANALYTICAL REPORT WorkOrder: HS 19050684 Lab lD:HS19050684-04 Matrix:Uquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 17-May-2019 13:07 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of23 HFNA-000003423 EPA Inspection Report - Page 1874 of 1969 ALS Houston, US Date: 17-May-19 Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19050684 DATES REPORT Sample ID Client Samp ID Collection Date TCLP Date Prep Date Analysis Date DF Batch lD R338645 Test Name : SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY HS19050684-02 S-3 (API Water} 09 May 2019 09:39 HS19050684-03 S-5 (T-40) 09 May 2019 09:06 HS19050684-04 S-6 (T-41) 09 May 2019 09:12 Matrix: liquid 17 May 2019 13:07 17 May 2019 13:07 17 May 2019 13:07 Page 7 of23 HFNA-000003424 EPA Inspection Report - Page 1875 of 1969 ALS Houston, US Client: Project: Work:Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19050684 Date: 17-May-19 QUALIFIERS, ACRONYMS, UNITS Qualifier a B E H J M n ND 0 p R s u Descri~ Value exceeds Regulatory limit Not accredited Analy!e detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is > 4 times amount spiked Dual Column results percent difference > 40% RPO above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDUSDL DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SDL TRRP Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Page 8 of23 HFNA-000003425 EPA Inspection Report - Page 1876 of 1969 A.LS Houston, US Date: 17-May-19 CERTIFICATIONS,ACCREDITATIONS & LICENSES Agency Number Expire Date Illinois Louisiana 30-Jun-2019 Dept of Defense 20-Dec-2021 Kansas E-10352 2018-2019 31-Jul-2019 Oklahoma 2018-156 31-Aug-2019 North Carolina 624-2019 31-Dec-2019 343, 2018-2019 30-Jun-2019 19-028-0 27-Mar-2020 ............................................................. l--------~----''--'; TX104704231-19-23 30-Apr-2020 Page 9 of23 HFNA-000003426 EPA Inspection Report - Page 1877 of 1969 ALS Houston, I.JS Client Name: Work Order: Navajo Refining HS19050884 Daterrime Received: Received by: Dale: 17-May-19 Sample Receipt Checklist .~J90~:15 .I.BM Checklist completed by: Raegen Giga eSignature Matrices: water1on 19~MY~?919 Date Reviewed by: Carrier name: Corey Grandits eSignature Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? VONTX1005rrX1006 Solids in hermetically sealed vials? Chain of custody present? Chain of custody signed when relinquished and received? Samplers name present on COG? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Sufficient sample volume for indicated test? All samples received within holding time? Containerrremp Blank temperature in compliance? Temperature( s )i"Thermometer(s ): Cooler(s)iKit(s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Login Notes: Client Contacted: Contacted By: Date Contacted: Regarding: Comments: Not Present Not Present Not Present Not Present [1.2c Foam [!IR1f <-------JJ----- 05/10/2019..19:30 Yes Ltd Yes LJ Yes No VOA vials submitted NI A["?'""]' NIA Person Contacted: Corrective Action: Page 10 of23 HFNA-000003427 EPA Inspection Report - Page 1878 of 1969 Enulranment:al :?::::::::\:::::::::::::Cui:rto1Mt.fo'f0r.mi;foit:- > ... :::. :;:::/::::/:::::\::::::: Chain of Custody Form ~ e J of _j_ -u--::--:;;;;----z---~ __j__ D Ci11ci1111ati, OH +I 513 733 5336 D EYerett, WA +l 425 3S6 2600 D fort Collins, CO +1970490 1SII D +I 616 399 6070 Holland.Ml 0 +I 281 530 5656 Houston, TX D Middletown, PA ;.I 717 944 5541 D Salt Lake City, UT +I 80! 266 7700 D Spring Cl!V, PA +I 610 948 4903 D York.PA +I 717 505 5280 P.O.Box 159 ~-~ '"" """ ........ .. -...... HS19050684 Navajo Refining Company BWON Monthly Sampling (EOL) 1?:C:}?:~r!~~!~!JArtesia, NewMexicoinmo 7411-3311 1111111111 :::~~~~< .-iJ+~~~~/:\[:L)Lj!~E~J:~ ry;;;: ;:;~;;;;;~)Lij:::~:~:~:tMj<S7S}746-545~,- ............ ::::~::::::~~~~~~~~~~ Suzanne.l\9...yjJf!@.!lg\1Jirnntt~r.com -+~--._,_.,,.:~""'::=""\""('"":~""":::""":1""'?"")"",.)_,,:::,,,,::"'"'1::"'~""'/,,,..:.,,,:::.,,,it,,,.,.rn 05/09119 9:28AM ::::~):?{:!~~~::-- 05100119 9:39AM 05109/19 05/09119 j~t ...-.. '~MPlf~}:~:fifu~)~M(:$;$f{I~:: ;"::.:.:::"~11:(:~(~(~(i ~11;~~i'. !~:i:~:~:1:~::::::::::::'.0 . .-r 1 I - I !,--,,--,+< l :r-I "Tl z Note: Any changes must be made In writing once samples and COC Form have been 111.1bmlttoo to ALS l.ilboratory Group. 0 0 0 {Yl.t f c..,=-0,v 0 Page 11 of23 0 (,) .i:,,. N OJ EPA Inspection Report - Page 1879 of 1969 SHIPPER'S DECLARATION FOR DANGEROUS GOODS ~ Slllppor NAVAJO REFINING COMPANY CIO AQUA MICROBICS ~ ~ 501 EM/\IN ARTESIA NM88210 US Coolg,,.. ~ ~ Cor,ayGrandils /\LS 10450 Stanciiff Sui1e210 HOUSTON TX 77099 US ~ ~ n.o ocmpl,,!land1flne<I""P""' oflhhl O..IB,oll.,, 111""1 handito 1.h& op&'J3tQf TRANSl'ORT DETAILS Thi& shlpmem Is whh!n U!~ ~ ~ llmihl!l"" pn<tll>II fo,: (oololo ooo appllob!o) Alrp<>fl of l:!oportti"' AITTESIJ\ (Provide at least three coplee m airline.) All Woyi>ill No. 709308590773 Page 1 Ol 1 Page{s) Sbipper"a Refam.nee Numbef (Opll<>m!~ FX 18 Compliant WARNING e Express CAFE3211 Failure to comply with all respects with the applicable Dangerous Goods Regulations may be in bmach of the applicable law ,subject to legal penaltil!9. ~ ,s;:.,.1;3: I ~ ABSGRA 1 ~d-mm,pcl<:""11!) -~~-.-.-.~~-.-.-.-----------~~.v------------ --c-cccc cccc~i NATURE AND QUANTITY OF DANGEROUS GOODS 1 I.IN n .,..,. orldel!em..t1"" Number, pmpkohlpplog ""'"' Cl.. or OMolon (s-/a,y Bfs,l\i, ~ g (JtOl)p !If""lltoo'J, asda/1 olll<!r 1 - ""1l.lh1!d/0""""'1Jon. ! ~ UN 3266, Corrosive liquid, basic, inorganic, n.o.s.(Sodium Hydroxide),S,111 0.08 U/854 UN 1268, Petroleum distillates, n.o.s.,3,HII/ 0.04 U/366 ; ~ All Packed In One FIBREBOARD ~ox l I a-u, ~ I ~~ i ~~~ I --~~ I:::::~:::~:;1:.:..":'~:rrREC 1,BillJ.424-9300,CCN 2il1319--------------------------------------------------1 ~ ~I 1. C oC<i,/"">' ',db...,,.. , > . / " ' I horol>y doeloro lhal Ille ooiili!OIS ol lillo ia,,m..t ""' rully and Name/Tillo OI Si90111i:l,y .s.e-cumt&ly described abl.we Dj" the proper shtpplng n.ame, and nm Brady Hubbam/Envlronmeni.31 Coordinator i cl...liiGd, pacloi9ed, mollood d lollell<d/pilN:l!f!lod, &Id or In P '1 "'"pto In propo, ooodl!loo "'' !ranopcl! ae<Of!llng to oppll.,.blo Place and Cali& into,nalloMl ood 118!1<>nI G""mm111111 Rf1llo!l<>oo. Idoclom !Mt Me,la, NM DMl!il!llO . - !,,,---------------------<,.....__ ~ oil olll!e opp!l..blo olr!ronpofl"'qol..,..o!l!s havo l>o&o mot. Slgna!um Brody Hubbord 18004249300 Em~1WyT1111'pJt1:1MN.itmW ~ i~~ ~ z FOR RA!llOMllVE MA'fEl'llAI.SHll'MElrl' ACCEPTABLE R>R P"8l!EG&UIRCRAFT; '!liE 8HIPMENTOONTMl!ll "'"31o=E MA,...,,.._IOTalDEO !'CM< OSE IM !311 I IHC:H'J.l:HT ro RESEARCH, MEDICAL D~SIS OR nl:EA'JMENT. AOR. 16:IJROP!SAft mAtaSSPORTITTA'ii:MISNT: CMie!AGS ffi ACCORDAllllCEwrrtt 11.'JA.2.1 "Tl :r- ~ 0 0 1..IX.DS!1'1S.'!l'.I!; 11112 - 0 0 Page 12 of 23 0 (,) N.i:,,. ART~ (!) EPA Inspection Report - Page 1880 of 1969 SMIPPER'S DECLARATION FOR DANGEROUS GOODS rshlppor t t If NAVAJO REFINING COMPANY ! C/0 AQUA MICROBICS i 501 EMAIN I ARTESIA NM 88210 us i Cone!gnee ~ - ; Coray Grandi!s ALS - 10450 Slancliff Sutte210 TX 77099 US : : r... """'f>leled Md olg,,od copi.,, of Ibis Oi!darallon muot Ile hooded lo 11"3 operator AlrpOtl of o.p,rturo ~ ~ ARTESIA (Pmvlde at laait lhma copias lo airline.) Air!llayblll No. 709308590773 i'ag 1 of 1 Pago{! Slllpper Rofere11< Nu'"""' /op!/onal) FX 18 Compliant 1111 Express CAFE3211 WARNING l'allura to comply with all respects with the applicable Dangerous Goods Regulations may be in breach of the applicable law ,subject to legal penalties. CARGO AIRCRAFT ~~y_ ~ s~:;,~::&n - ~mO..U"m!om HOUSTON ABSGRA 1 ,d.,..,,...,.,1'1coblo/ t NATURE AND QUANTITY OF DANGEROUS GOODS !IN Numlleror- l'luml!m; prr,por s/Jlppm11- ClasswDMskm (~mlr!, ;,ocltlng gmup (If""Ifllted), d ail olhor - n,q,,/mdlnfMni!l.lon. UN 3266, Corrosive liquid, basic, inorganic, n.o.s.(Sodlum Hydroxlde),6,111 UN 1208, Petroleum distillates, n.o.6.,3,11111 0.04 U/366 ~ ~ All Packed in One FIBREBOARD BOX Q=0.1 0.08 lJ/854 !:t !---------------------------------- t~~ AddltlooolHandlinglnfarmalion ~ 24-Hou, Emlllt1!IOY Roponse- CHEMTREC f-H00-42!-e31JO, CCN 201319 ~ i='==========="'"""'-"""'"""" , . . I h....by ...iaro !!lot !ho eonlliolo of!Iilo lgnm..l ni Mly no [ Namem11& ol S!goatoey ...umo!y d...r!!>&d obovo by !ho proporoilippl/lg """"'""" "'" ; BrO!!y HubbarolErnl!ronmenlal Coor<llnalor ~ c!~fflH11 psk&ged, marked and l!BbellooipBsCJ!lrdad~ .&Rd B.rt In all J Mopo<!Js In P"'P"' condltfon lo, lrMpot1 acoordl"9 IO o;,pllcobla I f'Jae,i Md Dnliil liilo""'ti""l ond N!il!<>MI Go-,mmoOlill iloglllli!lo... I ,..,lam !l!ot f Artoolo. NM OSJ!lllt.0019 111 ofti\& opp!lcabl .i, 1ro,10porl ""lu!fflmon1'1 h"" boon mo!. : 1 -------11(,o..,........... 18004249300 Emo,;.,.,yT-N,mbor Slgnaiu"' p ~ Era<I!' Hubl>aro 1'7. "7/AA. /j l~ ~ FOO l'IAlllOMrmlE MA1'ERIAl. SlllPMEMT M:CEl'TAJ!LS FOR PASSENGER AIIWAAFT, TIIE SHIPIIIENT COOTMia RA!llOI\C!IVE MATl!Rl~lNTENOoO - UBt IN~ I lllaCl'DElllTTO AE!ilf!AACH,, IM!::DICAL DIAQHOSIS on 'fflEATM!N'T.ADR. EUROPEAN mANS?0KTSTA1EMEHT: CARRIAGE IN ACCOR.WCE wrrn i,u.u ~ ~ "Tl :zr-0 0 lO'OS!!~S:l'J!ili HilJ' - - 0 0 Page 13 of23 0 (,) .i:,,. (,) 0 EPA Inspection Report - Page 1881 of 1969 ; u~~ of thfa~m cionstitutet yoQ'.ir .1Jernema.nt to the seNla2 cond!Uon:!l: In the unrant FedEx Servi~ Ga.iidlS. a:v.allab!a on fad.,.wm. FedEx will mot be responsiblo fer nv claim io ~""' <>I $100 per package, whotiler'the res"ll of lo,i, dome,,, del(ly, no~eUverv. mls.deHwry, or milSiflformatton~ uni~$$ you d:esi::l~rie I! higher vnfue. p.siy afa addit!oneI ch.a.rge, documliSnt . Y""' otool lo,s and filer, timely <lalm. limitotioo round lo tho current FodE> Seivire Guld opply. Yoor rlg~l\o r,:i:cwerfrom ,. fedF.x fur ijrl'd' lo:i;s1 !nelud!ng lntrin$it v.s!ua tif the pacba;e; ros:!l: of s;.a!es~ lnoome lnter~l!:t1 profit) attomei/:sfieoo, casts., a.i:ld' othorforms o! damage whethrdlract, ineldon!al, con,equentlal, or,pecial i, limited to the graoterof$l00crthe eothorired det:!ared V3h,!e. Reto'lffiry ieE:Brmat Exre.ecl a!ctusl dotumt1nted los.:s, Ma!(imum for item! of extr.t'lordln!tiry V(ilh.iie ls $1;000: &.g, Jowalr;, ~ratlou, metals, eegotlable ln:s!rumeoto and oi\hor Items ll<tod in our Sen1lce Glde. W1ltten claims must bo filad wltM strict time limit,, see Wrraol ft;dExS<arvice G"ido: ' All<>, pm~ng ihls lobol: CONSIGNEE COl'Y, PLEASE Pl.ACE i~ F~Olli OF l'OUCH 'I. F~lt:I fu!'6 pri11~~t:a sga i!'elong the hortwnte! tlnit'!. 2. P!.8.~& m.bs:! li:1 rehlpp!ng pooi;:h w:,rJ effuf: ~ lr.i. ye~r ~h!!}m~rel co>;;cc~> ~i -.i emn fl!:~ = 41 C) ~ f 0 i} ~ ~ .-.; .--. -- -- - & ~ . . """' ii i! ~~~- ! ~ ;;;;;;;; 2Hl",_1;i:::i:;: ffl .o... >r 00d "z'"~" i; !J!O ~ fl; m ~ ~ "~"" llli m O !l:-1..., Cl) Q-< ~mgi: iii= 0 0 ~ ;o c~ ::z z > "'"" .... '.'""'I n z s=:, X F C ~ ::I "'ii =i = 0 "Tl fl) El! i RI ffl fi! ==,:I"' i !JM1] 3: "' ~ ...,,.., ~ .,,11 I f! ~~i 0 ;;a 0 ;itl - "' ~ii: ~ril N I ~ ''=', f ~~ ~~ o<>;:: ""' ---~~-~~----- 0 !is: m~.~::- "' iii ~ !!,!.,::"' -...i ;;a .... -- _....i :..:: "" )>O )l> i:5 i,;i, ,I I .tlD1~ :c~ 8 =i :{; 551C1i006Cl104C "Tl z :r- 0 0 0 0 Page 14 of23 0 (,) .i:,,. (,) ...... EPA Inspection Report - Page 1882 of 1969 17-May-2019 Corey Grandits ALS Environmental 10450 Stancliff Rd Suite 210 Houston, TX 77099 Re: HS19050684 Dear Corey, Work Order: 19050888 ALS Environmental received 4 samples on 14-May-2019 09:30 AM for the analyses presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental - Holland and for only the analyses requested. Sample results are compliant with industry accepted practices and Quality Control results achieved laboratory specifications. Any exceptions are noted in the Case Narrative, or noted with qualifiers in the report or QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained from ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. The total number of pages in this report is 9. If you have any questions regarding this report, please feel free to contact me: ADDRESS: 3352 128th Avenue, Holland, Ml, USA PHONE: +1 (616) 399-6070 FAX: +1 (616) 399-6185 Sincerely, Chad Whelton Project Manager Report of Lal::mratory Analysis Certificate No; MN 026-999-449 HFNA-000003432 EPA Inspection Report - Page 1883 of 1969 ALS Group, USA Client: Project: Work Order: ALS Environmental HS19050684 19050888 Lab Samp ID Client Sample :m 19050888-01 HS19050684-01 19050888-02 HS l 9050684-02 19050888-03 HS l 9050684-03 19050888-04 HS 19050684-04 Date: 17-May-19 Matrix Liquid Liquid Liquid Liquid Work Order Sample Summary Jag ~um~gr S-1 (.J\.Pl HC) S-3 (API Water) S-5 (T-40) S-6 (T-41) &;2IIection Date 5/9/2019 09:28 5/9/2019 09:39 5/9/2019 09:06 5/9/2019 09: 12 Date Received 5il4/2019 09:30 5il4/2019 09:30 5/14/2019 09:30 5/14/2019 09:30 Hold Page 16 of 23 Sample Summary Page l of l HFNA-000003433 EPA Inspection Report - Page 1884 of 1969 ALS Group, USA Client: Project: WorkOrder: ALS Environmental HS19050684 19050888 Date: 17-May-19 QUALIFIERS, ACRONYMS, UNITS Qualifier ** a B E H Hr J ND 0 p R s u X DescriJJtion Value exceeds Regulatory Limit Estimated Value Analyte is non-accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quantitation range Analyzed outside of Holding Time BODiCBOD - Sample was reset outside Hold Time, value should be considered estimated. Analyte is present at an estimated concentration between the .MDL and Report Limit Not Detected at the Reporting Limit Sample amount is > 4 times amonnt spiked Dual Column results percent difference> 40% RPD above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the l\,IDL Analyte was detected in the Method Blank between the MDL and Reporting Limit, sample results may exhibit background or reagent contamination at the observed level. Acronvm Description m.JP Method Duplicate LCS Laboratory Control Sample LCSD Laboratory Control Sample Duplicate LOD Limit of Detection (see MDL) LOQ Limit ofQuantitation (see PQL) IvlBLK Method Blank MDL Method Detection Limit MS Matrix Spike MSD Matrix Spike Duplicate PQL Practical Quantitation Limit RPD Relative Percenr Difl:erence TDL Target Detection Limit TNTC Too Numerous To Count A APHA Standard Methods D ASTM E EPA SW SW-846 Update m Units Reported none Description Page 17 of23 QF Page 1 of1 HFNA-000003434 EPA Inspection Report - Page 1885 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS19050684 HS 19050684-02 5/9/2019 09:39 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 17-May-19 Result Qual Report Limit Work Order: 19050888 Lab ID: 19050888-02 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.00 none Analyst: RZM 5/17/2019 08:35 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 18 of 23 Analytical Results Page l of 3 HFNA-000003435 EPA Inspection Report - Page 1886 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS19050684 HS 19050684-03 5/9/2019 09:06 A.iv!. Analyses SPECIFIC GRAVITY Specific Gravity Date: 17-May-19 Result Qual Report Limit \VorkOrder: 19050888 Lab ID: 19050888-03 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057-90 1.14 none Analyst: RZM 5/17/2019 08:35 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 19 of23 Analytical Results Page 2 of 3 HFNA-000003436 EPA Inspection Report - Page 1887 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS19050684 HS 19050684-04 5/9/2019 09: 12 Al\t1 Analyses SPECIFIC GRAVITY Specific Gravity Date: 17-May-19 Result Qual Report Limit Work Order: 19050888 Lah ID: 19050888-04 Matrix: LIQUID Units Dilution Factor Date Analyzed D5057~90 1.14 none Analyst: RZM 5/17/2019 08:35 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 20 of23 Analytical Results Page 3 of 3 HFNA-000003437 EPA Inspection Report - Page 1888 of 1969 ALS Group, USA Client: ALS Environmental Work Order: 19050888 Project: HS19050684 Date: l 7-May-19 QC BATCH REPORT Batch ID: R.260636 Instrument ID WETCHEM Method: D5057-90 DUP Sample ID: 19050888-02.A DUP Client ID: 1-1$19050684-02 Run ID: WETCHEM_190517A Units: none SeqNo: 5662483 Analysis Date: 5117/2019 08:35 PM Prep Date: DF: 1 Analyte Result PQL SPK Val SPKRef Value Control %REC Limit RPO Ref Value %RPD RPO Limit Qua/ Specific Gravity 1.007 0 0 0 0 0-0 1.004 0.318 20 The following samples were analyzed in this batch: i905088802A 1905088803A 19050!l!l!l04A Note: See Qualifiers Page for a list of Qualifiers and their explanation. Page 21 of23 QC Page: 1 of 1 HFNA-000003438 EPA Inspection Report - Page 1889 of 1969 \ 9 o s r r : ~ i z l'll."<ll~~~.'>'l$><'\-"'~~1'4<:I>:!:.:.;:~:-:,,:' ,:-:-:,:,,,:-:.:~~ 10450 stanel!ff Rd, Ste 210 Houston, TX 77099 T: +1 281 530 S656 F: +l 28'1 530 5887 www.alsglobal.com ALS Group USA, Corp. 3352 - 128th Ave. Holland, Ml 494249253 CUSTOMER INFORMATION: company: ALS Houston contact: Corey Grandlts Addren: Phone: 10450 Stancliff Rd, Ste 210 +l 281 530 5656 EmaU: Alternate contact: Email: Corey.Gram:lits@alsgiobal,com Jumoke M. Lawal jumoke.lawal@a!sg!obai.com Phone: +:I. 616 399 6070 INVOICE INFORMATI01'1i: ALS Houston Accounts Payable Address: 10450 Stancliff Rel, Ste 210 Phone: Reference: TSR: +1 281 530 5656 HS19050684 Danielle Winnings 1. HS190506S4--(U. S-1 (A.PI HC) Sub Specmc Gravity to ALS Holland 2.. HS190506S4-02 S-3 (API Water) Sub Specific Gravity to ALS Hol!an<I 3. HS190506~3 SwS {T"'40} Sub Specific Gravity to ALS Holland 4. HS190506M--04 S"'6 rr--41) Sub Specific Gravity to ALS Holland Uquld Uquid Liquid l.iqulli 09 May 2019 09:2.S 17 May 2019 09 May 21>19 09:39 17 May 2019 09 May 2019 O!:t.Of:i 17 May 2019 09 Mny 20H 09:12 17 May 2019 comments: Please analyze for the analysis fisted above. Send report to the emaf!s shown above, QC: Level: STD (Lllboratory Standard QC: method blank and LCS required) Relinquished By: Received Sy: cooler lD{s): Date/Time: Date/Time: Page 22 of23 HFNA-000003439 EPA Inspection Report - Page 1890 of 1969 ALS Group, USA Client Name: Work Order: A!,,$ - HOUSTON 19050888 Sample Receipt Checklist Datemme Received: Received by: 14-MaJ;19J)9:30 DS Checklist completed by _JI-.,....,, ,S'L eSignature Matrices: Carrier name: Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Chain of custody present? Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Sufficient sample volume for indicated test? All samples received within holding time? Container!Temp Blank temperature in compliance? Sample(s) received on ice? Temperature( s)/Thermometer(s ): Cooler(s )/Kit(s): Date!Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Login Notes: 14-May-19 Date Reviewed by: C~,t' JcJi?~-- eS!gnature Yes Ell No Not Present Yes :il No Not Present Yes Yes :;;,] No Not Present ~ No Yes :;.;] No Yes is{J No Yes ~ No Yes ~ No Yes ~ No Yes ~ No Yes ~ No Yes ~ No /3.2/3.2 C SR2 !14/2019 11 ;25;i;J,;;_AM Yes No Yes No Yes No 1- No VOA vials submitted ~ NIA [ii{] NIA fil{I 14-May-19 Date Client Contacted: Contacted By: Comments: CorrectiveAction: Date Contacted: Regarding: Person Contacted: Page n of23 SRC Page 1 of 1 HFNA-000003440 EPA Inspection Report - Page 1891 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 May 17, 2019 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling (EOl) Dear Gabriela, Work Order: HS19050685 ALS Environmental received 9 sample(s) on May 10, 2019 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, Generated By; JUMOKE.LAWAL Corey Grand!ts Project Manager Right Solutions Ri9ht Partner www.aisg1obaLcom Pagel of27 HFNA-000003441 EPA Inspection Report - Page 1892 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS 19050685 LabSamp ID HS19050685-01 HS19050685-02 HS 19050685-03 HS 19050685-04 HS19050685-05 HS19050685-06 HS19050685-07 HS19050685-08 HS 19050685-09 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 {T-40) S-6 (T-41} Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Matrix Liquid Liquid Liquid Liquid Water Waler Water Liquid Water Date: 1Hv1ay-19 SAMPLE SUMMARY TagNo Collection Date 09-May-2019 09:28 09-May-2019 09:39 09-May-2019 09:06 09-May-2019 09:12 09-May-2019 09:30 09-May-2019 10:03 09-May-2019 10:03 09-May-2019 00:00 09-May-2019 00:00 Date Received 10-May-2019 09:15 10-May-2019 09:15 10-May-2019 09:15 10-May-2019 09:15 10-May-2019 09:15 10-May-2019 09:15 10-May-201909:15 10-May-2019 09:15 10-May-2019 09:15 Hold ,;...._.._.._v.; ~ ::: ~n) ~ ,.._.._..,\ ~ ~) c::J [:] ,:..............~ . ~ ~ L....,J r............1. 1...............1 f...............l L.......J t..............r. l...........J. r...............~ L.....J. Page 2 of27 HFNA-000003442 EPA Inspection Report - Page 1893 of 1969 AlS Houston, US Date: 17-May-19 Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling {EOL) HS19050685 GCMS Volatiles by Method SW8260 Batch m: R.338330 Sample ID: S-5 (T-40 S-6 {T-41)) (HS19050685-03, 04) CASE NARR.ATIVE Surrogates failure for HS19050685-03, 04 due to sample matrix. Batch m: R338280,R338610 The test results meet requirements of the current NELAP standards, state requirements or programs where applicable. Page 3 of27 HFNA-000003443 EPA Inspection Report - Page 1894 of 1969 A.LS Houston, US Client Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (API HC) 09-May-2019 09:28 ANALYSES VOLATILES BY SWS260C Benzene Surr: 1, 2-Dichforoethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 220 94.4 95.1 92.9 97.6 Method:SWS260 2.4 REPORT LIMIT 24 70-1213 70-130 70-130 70-130 Date: 17-May-19 ANALYTICAl REPORT WorkOrder: HS19050685 Lab !D:HS19050685-01 Matrix:Uquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg %REC %REC %REC %REC 5000 5000 5000 5000 5000 Analyst: WLR 14-May-2019 11 :56 14-May-2019 11:58 14-May-2019 11:58 14-May-2019 11:56 14-May-2019 11:56 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of27 HFNA-000003444 EPA Inspection Report - Page 1895 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling {EOl) S-3 (AP! Water) 09-May-2019 09:39 ANALYSES i'ifOLATILES SW8260C Benzene Surr: 1,2-Dichforoethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 1.3 84.6 97.5 87.2 106 Method:SWS260 0.030 REPORT LIMIT 0.25 70-126 82-124 77-123 82-127 Date: 17-May-19 ANALYTICAL REPORT WorkOrder:HS 19050685 lab !D:HS19050685-02 Matrix:Liquid UNITS mg/L %REC %REC %REC %REC DILUTION FACTOR DATE ANALYZED ................................ Analyst: PC 50 17-May-2019 07:19 50 17-May-2019 07:19 50 17-May-2019 07:19 50 17-May-2019 07:19 50 17-May-2019 07:19 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of27 HFNA-000003445 EPA Inspection Report - Page 1896 of 1969 ALS Houston, US Client Project: Sample !D: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 09-May-2019 09:06 ANALYSES ,VOLATILES BY SWS260C Benzene Surr: 1, 2-Dichforoethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.26 96.4 105 66.2 99.3 Method:SW8260 0.025 s REPORT LIMIT 0.25 70-1215 70-130 70-130 70-130 Date: 17-May-19 ANALYTICAL REPORT WorkOrder:HS 19050685 Lab ID:HS19050685-03 Matrix:Uquid UNITS DILUTION FACTOR DATE ANALYZED ssss------ Analyst: WLR mg/Kg 50 14-May-2019 10:41 %REC 50 14-May-2019 10:41 %REC 50 14-May-2019 10:41 %REC 50 14-May-2019 10:41 %REC 50 14-May-2019 10:41 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of27 HFNA-000003446 EPA Inspection Report - Page 1897 of 1969 A.LS Houston, US Client Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-6 (T-41) 09-May-2019 09:12 ANALYSES :vrn.ATllES BY SW8260C Benzene Surr: 1, 2-Dich!oroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.024 96.1 101 69.5 98.1 Method:SW8260 0.024 s REPORT LIMIT 0.24 70-126 70-130 70-130 70-130 Date: 17-May-19 ANALYTICAL REPORT WorkOrder:HS 19050685 Lab ID:HS19050685-04 Matrix:Uquid UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 14-May-2019 11 :06 14-May-2019 11:06 14-May-2019 11:06 14-May-2019 11:06 14-May-2019 11:06 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of27 HFNA-00000344 7 EPA Inspection Report - Page 1898 of 1969 A.LS Houston, US Client Project: Sample ID: CoHection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Field Blank: 09-May-2019 09:30 ANALYSES VOLATILES $WS2GOC Benzene Surr: 1, 2-Dich!oroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 96.4 96.4 97.7 105 l\liethod:SW3260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 17-May-19 ANALYTICAL REPORT WorkOrder: HS19050685 Lab !D:HS19050685-05 Matrix:Water UNITS DILUTION FACTOR DATE ANALYZED mg/L %REC 1 %REC 1 %REC %REC 1 Analyst: PC 12-May-2019 22:46 12-May-2019 22:46 12-May-2019 22:46 12-May-2019 22:46 12-May-2019 22:46 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 8 of27 HFNA-000003448 EPA Inspection Report - Page 1899 of 1969 A.LS Hcn.1stcm, IJS CHent: Project Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 1 09-May-2019 10:03 ANALYSES :VCII.ATILES SWl.!250C Benzene Surr: 1, 2-Dich/oroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromof/uoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 95.0 99.8 94.8 104 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 17-May-19 ANALYTICAL REPORT WorkOrder:HS 19050685 Lab ID:HS19050685-06 Matrix:Water UNITS mg/L %REC %REC %REC %REC DILUTION FACTOR DATE ANALYZED ss,ssssssssss,ss Analyst: PC 12-May-2019 23:10 1 12-May-2019 23:10 1 12-May-2019 23:10 1 12-May-2019 23:10 1 12-May-2019 23:10 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 9 of27 HFNA-000003449 EPA Inspection Report - Page 1900 of 1969 ALS Houston, US Date: 17-May-19 Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 2 09-May-2019 10:03 ANALYTICAL REPORT WorkOrder:HS 19050685 Lab ID:HS 19050685-07 Matrix:Water ANALYSES RESULT QUAL MDL REPORT LIMIT UNITS DILUTION FACTOR -~------------------------------------- :VoLATILES - SW8260C Method:SW8260 Benzene < 0.00060 0.00060 0.0050 mg/L DATE ANALYZED Analyst: PC 12-May-2019 23:34 Surr: 1,2-Dichloroethane-d4 97.8 70-126 %REC 1 12-May-2019 23:34 Surr: 4-Bromofluorobenzene 101 82-124 %REC 1 12-May-2019 23:34 Surr: Dibromofluoromethane 98, 1 77-123 %REC 1 12-May-2019 23:34 Surr: Toluene-dB 101 82-127 %REC 1 12-May-2019 23:34 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 10 of27 HFNA-000003450 EPA Inspection Report - Page 1901 of 1969 ALS Houston, US Date: 17-May-19 Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) Duplicate 09-May-2019 00:00 ANALYTICAL REPORT WorkOrder: HS 19050685 lab ID:HS19050685-08 Matrix:liquid ANALYSES RESULT QUAL -----------"""""""""""" VOLATILES - SWS260C Benzene 1.4 Surr: 1, 2-Dichloroethane-d4 84.6 Surr: 4-Bromofluorobenzene 100 Surr: Dibromofluoromethane 87.3 Surr: Toluene-dB 103 MDL REPORT LIMIT UNITS DILUTION FACTOR DATE ANALYZED ~------------~ssssssss Analyst: PC 0.030 0.25 mg/L 50 17-May-2019 07:43 70-126 %REC 50 17-May-2019 07:43 82-124 %REC 50 17-May-2019 07:43 77-123 %REC 50 17-May-2019 07:43 82-127 %REC 50 17-May-2019 07:43 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 11 of27 HFNA-000003451 EPA Inspection Report - Page 1902 of 1969 ALS Houston, US Date: 17-May-19 Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOl) Trip Blank 09-May-2019 00:00 ANALYTICAL REPORT WorkOrder:HS 19050685 Lab ID:HS19050685-09 Matrix:Water ANALYSES MOL.ATILES SW8260C Benzene RESULT QUAL MOL REPORT LIMIT UNITS DILUTION DATE FACTOR ANALYZED --------------------------------------------------------------------"-"""------------------- Method:SWS260 ssssssss Analyst; PC < 0.00060 0.00060 0.0050 mg/L 1 12-May-2019 22:21 Surr: 1,2-Dichforoethane-d4 96.3 70-126 %REC 1 12-May-2019 22:21 Surr: 4-Bromofluorobenzene 99.5 82-124 %REC 1 12-May-2019 22:21 Surr: Dibromof/uoromethane 97.6 77-123 %REC 1 12-May-2019 22:21 Surr: Toluene-dB 99.8 82-127 %REC 1 12-May-2019 22:21 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 12 of27 HFNA-000003452 EPA Inspection Report - Page 1903 of 1969 AlS Houston, US Client: Navajo Refining Company Project: BWON Monthly Sampling (EOL) WorkOrder: HS19050685 - -- Batch ID: 3060 --- Method: VOLATILES BY SW8260C SamplD HS 19050685-01 HS 19050685-03 HS 19050685-04 Container Sample WtNol 5.267 (g} 4.973 (g) 5.115 (g) Final Volume 5(mL) 5 (ml) 5 (ml) Weight Factor 0.95 i .01 0.98 Container Type Bulk (5030B) Bulk (5030B) Bulk (5030B) Date: 17-May-19 WEIGHT LOG . ..,py.,,,,. :......................,...w... Page 13 of27 HFNA-000003453 EPA Inspection Report - Page 1904 of 1969 ALS Houston, US Client: Project: WorkOrc!er: Navajo Refining Company BWON Monthly Sampling (EOL) HS19050685 Sample ID Client Samp ID Collection Date TCLP Date - - - - - - " " " ' " " " " " ' " ' " ' " " ' ,~.. ~ss.....,.,.,.,.,.,.,.,_,~~"" $atch ID R.338280 Test Name: VOLATILES SW8260C HS19050685-05 HS19050685-06 HS19050685-07 HS19050685-09 Field Blank EQ Blank Port 1 EQ Blank Port 2 Trip Blank 09 May 2019 09:30 09 May 2019 10:03 09 May 2019 10:03 09 May 2019 00:00 Sate!"! IO R.338330 Test Name : VOLJ.TILES BY SW8260C HS19050685-01 HS19050685-03 HS 19050685-04 S-1 (API HC} S-5 (T-40) S-6 (T-41 ) 09 May 2019 09:28 09 May 2019 09:06 09 May 2019 09:12 Batch ID R338610 Test Name; VOLATILES- SW8260C HS19050685-02 HS 19050685-08 S-3 (AP! Water) Duplicate 09 May 2019 09:39 09 May 2019 00:00 Dale: 17-May-19 DATES REPORT Prep Date Analysis Date DF .. ,,,,,,,,,,,,v ...... Matrix: Water --.~~~~~~~~-~~~~~~- 12 May 2019 22:46 12 May 2019 23:10 12 May 2019 23:34 12 May 2019 22:21 Matrix: Liquid 14 May 2019 11 :56 14 May 2019 10:41 14 May 2019 11:06 5000 50 50 Matrix: Liquid 17 May 2019 07:19 50 17 May 2019 07:43 50 Page 14 of27 HFNA-000003454 EPA Inspection Report - Page 1905 of 1969 A.LS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19050685 Date: 17-May-19 QC BATCH REPORT Batch U): R,338280 ( O) fnstru ment: VOA6 Method: VOLATILES SW8260C MBLK Client ID: Analyte Sample ID: VBLKW-190512 Units: ug/L Analysis Date: 12-May-2019 14:39 Run ID: VOA6_338280 SeqNo: 5071924 PrepDate: DF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPD Ref RPD Value %RPO Limit Qual Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 48.02 0 50 49.22 0 50 48.48 0 50 49.76 0 50 0 96.0 70- 130 0 98.4 82 - 115 0 97.0 73 - 126 () 99.5 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-190512 Units: ug/L Analysis Date: 12-May-2019 13:51 Run ID: VOA6_338280 SeqNo:5071923 PrepDale: DF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPD Ref RPD Value %RPD limit Qual Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB I \ MS l Client ID: IAnalyte l Sample ID: Benzene 17.76 5.0 20 48.89 0 50 49.57 0 50 48.89 0 50 51.61 0 50 0 88.8 74 - 120 () 97.8 70 - 130 0 99.1 82- 115 () 97.8 73 126 0 103 81 - 120 HS19!l50571-01 MS Units: ug/L Analysis Date: 12-May-2019 15:52 Run ID: VOA6_338280 SeqNo: 5071927 PrepDale: DF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPD Ref RPD Value %RPD Limit Qual 21.7 5.0 20 0 108 70 - 127 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 49.32 49.2 50.74 0 50 0 50 0 50 0 98.6 82- 124 --~--"'"~''"''' 98.4 77 - 123 0 101 82- 127 Page 15 of27 HFNA-000003455 EPA Inspection Report - Page 1906 of 1969 A.LS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19050685 Date: 17-May-19 QC BATCH REPORT Batch II); R33S2S0 ( 0 ) Instrument: VOA6 Method: VOLATILES SW8260C MSD Client ID: Analyte Sample ID: HS19050571-01MSD Units: ug/L Analysis Date: 12-May-2019 16:16 Run ID: VOA.6_338280 SeqNo: 5071928 PrepDate: DF: 1 Result SPK Ref Control RPD Ref RPD PQL SPK Val Value %REC Limit Value %RPD limit Qual Benzene Surr: 1,2-Dich/oroethane-d4 19.95 5.0 20 50.56 0 50 0 99.8 70 - 127 ........................ '"-----"---"" 0 101 70- 126 21.7 49.23 8.39 20 2.66 20 Surr: 4-Bromofluorobenzene 50.63 0 50 0 101 82- 124 49.32 2.62 20 Surr: Dibromofluoromethane 49.94 0 50 0 99.9 77 - 123 49.2 1.48 20 Surr: Toluene-dB 50.87 0 50 0 102 82- 127 50.74 0.251 20 The following samples were analyzed in thi.s batch; rlS190506.~5.~.5. ..................~~.1.9...5.?.~.8.5..~..~....................1.~~~-9(1=--~~-5.=--7--- ~===-=~-6-~==-9 ................................. "I Page 16 of27 HFNA-000003456 EPA Inspection Report - Page 1907 of 1969 AUS Houston, US Client: Project: Work:Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19050685 Date: 17-May-19 QC BATCH REPORT Method: VOLATILES BY SW8260C MBLK Client ID: Analyte Sample ID: MBLKW1-051419 Units: ug/Kg Analysis Date: 14-May-2019 09:51 Run ID: VOAS_33S330 SeqNo: 5073455 PrepDate: OF: SO Result SPK Ref Control RPO Ref RPD PQL SPK Val Value %REC Limit Value %RPO Limit Qual Benzene <25 250 Surr: 1, 2-Dichloroethane-d4 _______ ------------------------------------------l Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethene Surr: Toluene-dB "" . LCS Sample ID: 2340 2228 2444 VLCSW1-051419 0 2500 0 2500 0 25{){) 0 93.6 80-120 ...................................................................................- ..- - - - 0 mu 8a - 119 0 97.8 81 - 118 Units: ug/Kg Analysis Date: 14-May-2019 09:01 Client ID: Analyte Run ID: VOA8_338330 Result PQL SPK Val SeqNo: 5073454 SPK Ref Value %REC PrepDate: Control Limit I DF: 1 RPD Ref RPD , . Value %RPD Limit ~ Benzene Surr: 1,2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromof/uoromelhane Surr: Toluene-dB 49.05 5.0 50 51.09 0 5{) 51.86 0 50 52.3 51.53 0 50 0 98.1 75- 124 0 102 76 - 125 0 104 80-120 0 103 81-118 MS Client ID: Analyte Sample ID: HS19050546-02MS Units: ug/Kg Analysis Date: 14-May-2019 13:11 Run ID: VOA8_338330 SeqNo: 5074002 PrepDate: OF: 500 Result SPK Ref Control RPD Ref RPO PQL SPK Val Value %REC Limit Value %RPD Limit Qual Benzene Surr: 1,2-Dich/oroethane-d4 Surr: 4-Bromofluorobenz:ene Surr: Dibromofluoromethane Surr: Toluene-dB 26660 23380 23430 23660 23760 2400 0 0 0 0 24000 24000 24000 2400{) 24000 0 111 70 -130 0 97.4 70-126 0 97.6 70- 130 0 98.6 70- 130 0 99.0 70- 130 Page 17 of27 HFNA-000003457 EPA Inspection Report - Page 1908 of 1969 AlS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19050685 Date: 17-May-19 QC BATCH REPORT Batch ID: R338330 ( 0 ) Instrument: Method: VOLATILES BY SWS260C MSD Client ID: Analyte Sample ID: HS19050S4602MSD Units: ug!Kg Analysis Date: 14-May-2019 13:37 Run ID: VOA8_338330 SeqNo: 5074003 PrepDate: DF: 500 Result PQL SPKVal SPKRef Value %REC Control Limit RPO Ref RPD Value %RPD limit Qual Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 23660 24040 24130 24250 24110 2400 0 0 0 0 24000 .......... 24000 24000 24000 24000 0 98.6 70 - 130 i:i 100 70- 126 0 101 70- 130 "--"--- 0 101 70 - 130 0 100 70- 130 26660 23380 23430 23660 23760 11.9 30 2.77 30 2.94 30 2AfJ 30 1.45 30 The following samples were analyzed in this batch: ?IS19050685-0l HS 19050685-03""""" HS J9050685-04 cccccccccc _ _ _ _ _ _ _ _ _ _ _ _,,,,,,,, - - """"""""""""'""' Page 18 of27 HFNA-000003458 EPA Inspection Report - Page 1909 of 1969 AlS Houston, US Client: Project: Work:Order: Navajo Refining Company BWON Monthly Sampling {EOL) HS19050685 Date: 17-May-19 QC BATCH REPORT Batch ID: R338610 ( 0 ) Instrument: VOA.6 Method: VOLATILES SW8260C MBLK Client lD: Analyte Sample ID: VBLKW-190516 Units: ug/l Analysis Date: 16-May-2019 22:53 Run ID: VOA.6_338610 SeqNo: 5078851 PrepDate: DF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPD Ref RPD Value %RPO Limit Qual Benzene Surr: 1, 2-Dich/oroethane-d4 Surr: 4-Bromof/uorobenzene < 0.60 5.0 42.12 0 50 50.32 0 50 0 84.2 70- 130 0 101 82-115 Surr: Toluene-dB 52.26 0 50 D 105 81 .. 120 lCS Client ID: Analyte Sample ID: VLCSW-190516 Units: ug/l Analysis Date: 16-May-2019 22:05 Run ID: VOA6_338610 SeqNo: 5078850 PrepDate: DF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPD Ref RPD Value %RPO Limit Qual Benzene surr:1:2}jfcii1oroeifiane~it4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB IMS I Client ID: Sample ID: I Analyte ! Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromof/uoromethane Surr: Toluene-dB 19.29 5.0 20 50.8 0 50 52.72 0 50 51.71 0 50 49.9 0 50 0 96.5 74 120 0 102 70-130 0 105 82 - 115 0 103 0 99.8 81 - 120 HS19050590-02MS Run ID: Result Units: VOA.6_338610 PQL SPKVal ug/l Analysis Date: 17-May-2019 02:06 SeqNo: 5078853 PrepDate: DF: 1 SPK Ref Value %REC Control Limit RPO Ref RPD Value %RPD Limit Qual 16.6 5.0 43.32 0 20 0 83.0 70 - 127 o 50 86.6 70- 126 50.55 0 50 0 101 82- 124 90.8 77- 123 52.03 0 50 0 104 82- 127 Page 19 of27 HFNA-000003459 EPA Inspection Report - Page 1910 of 1969 A.LS Houston, US Client: Project: Work:Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19050685 Date: 17-May-19 QC BATCH REPORT Batch ID: R338610 ( 0) Instrument: VOA6 Method: VOLATILE$ SW8260C MSD Client ID: Analyte Sample ID: HS1905059002MSD Units: ug/l Analysis Date: 17-May-2019 02:30 Run ID: VOA.6_338610 SeqNo: 5078854 PrepDate: DF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPD Ref RPD Value %RPO Limit Qual Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromoffuoromethane Surr: Toluene-dB 16.45 5.0 43.24 0 49.41 0 44.68 0 51.67 0 The following samples were analyzed in this batch: }JS19050685-02 1............................................. 2D 50 50 50 HS 19050685-08 0 82.3 70 - 127 16.6 0.864 20 0 86.5 70-126 43.32 0.172 20 0 98.8 82- 124 50.55 2.27 20 89.4 77- 123 45.38 1.56 20 0 103 82- 127 52.03 0.7 20 .......................................... - - - - - - - - - - - Page 20 of27 HFNA-000003460 EPA Inspection Report - Page 1911 of 1969 ALS Houston, LIS Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19050685 Date: 17-May-19 QUALIFIERS, ACRONYMS, UNITS Qualifier ........................Description.. Value exceeds Regulatory Limit a Not accredited B Analyte detected in the associated Method Blank above the Reporting limit E Value above quantitation range H Analyzed outside of Holding Time J Analyte detected below quantitation limit M Manually integrated, see raw data for justification n Not offered for accreditation ND Not Detected at the Reporting limit 0 Sample amount is > 4 times amount spiked P Dual Column results percent difference > 40% R RPD above laboratory control limit S Spike Recovery outside laboratory control limits U Analyzed but not detected above the MDUSDL Acronym DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL SD SDL TRRP Description Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program Unit Reported mg/Kg mg/L Description Milligrams per Kilogram Milligrams per Liter Page 2I of27 HFNA-000003461 EPA Inspection Report - Page 1912 of 1969 AlS Houston, US Date: 17-May-19 CERTIFICATIONS,ACCREDITATIONS & LICENSES Agency Number Expire Date I'""'"'"'"'"'-+---------+----- Illinois 004438 29-Jun-2019 ....................................; 03087 , 30-Jun-2019 Oklahoma i20-Dec-2021 "'-~-------""~"''""""' E-10352 2018-2019 31-Jul-2019 cccccccc+ccccccc _ _ _ _ _ _ __ 20'!8-156 131-Aug-2019 cf-ccccc-------- North Carolina 6242019 : 31-Dec-2019 --------- . { = c c c c c c c_ _ _ _ _ __ _ , Maryland 343, 2018-2019 i 30-Jun-2019 -.-------~-----;~~~~~!~~~~~-=:.:=2-.3-__ _ j ssssss---- Arkansas 1 .....................................:::::::::::::::::::::::::::::::::::::::::::::::::::::::..-.-.-.. 19-028-0 i { 27-Mar-2020 :::::::::::::]~o=A;;;~2020:::::::::::::::::::::::: ... Page 22 of27 HFNA-000003462 EPA Inspection Report - Page 1913 of 1969 ALS Houston, US Client Name: Work Order: Navajo Refining HS19050685 Date/Time Received: Received by: Date: 17-May-19 Sample Receipt Checklist 10-l\/lat-2019 09:1@ .!BM Checklist completed by: Raegen_ Giga _______________________,,____,,__ ~-O-Mav-2019 eSignature Date Matrices: Reviewed by: Carrier name: Corey Grandits eSignature 13-Mav-2019 -- Date Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? VONTX1005/TX1006 Solids in hermetically sealed vials? Chain of custody present? Chain of custody signed when relinquished and received? Samplers name present on COC? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Temperature(s)/Thermometer(s): Cooler(s)/Kit(s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water pH acceptable upon receipt? pH adjusted? pH adjusted by: login Notes: Client Contacted: Contacted By: Date Contacted: Regarding: Comments: Yes Yes Yes Yes T..........ll ~ i :;:.-..-..........'-: ::................-:: ~.................l.:i 1 ~ ::.................::: r........1. ............J Yes Yes Yes Yes Yes Yes Yes Yes Yes ['i::] 1.2c Foam i::i5/10/2019 19:30 No D No[] Not Present Not Present Not Present Not Present IR11 r _______)i............~~~~~~~~~~~~~~- ~ --------------------------4 No VOA vials submitted N/A NIA r"1 ................~. r"1 ~..............-.:: Person Contacted: Corrective Action: Page 23 of27 HFNA-000003463 EPA Inspection Report - Page 1914 of 1969 Enulronmentat Chain of Custody Form Page _1_ of --1_ 0 CincinMti, OH +I 513 733 5335 o fverBtt, WA +1 425 3S6 2600 0 Fort Col/Ins, CO +I 970 49/J 1511 D + I 616 399 5070 Holland, Ml 0 Hou,ton, TX +12815305656 D Middletown, PA +I 717 944 5S41 O Salt Lake City, UT + I 801 256 '1700 D Spring Oty, PA +I f.i!O 948 4903 D York.PA +I 717 505 5280 @ill~~~:~1t;!7;:.aw~~.~~-"= HS19050685 , ~-P.-O.Box-159,- lll~lt~it~~~....... 1:1 BNWavOaNjoMoRnethfilnyinSagmCploinmgp(EaOnLy) ~r!-e_s_!a-,N-M-8-82_1_1_-0_1_59-----;:~{~)-i}~tf~i~ifi~ Artesia, New Mexico 88210 " :1; 1111111111 ..#J1 ! %~~8:::~:~~: 0- =............~("1ij7~31. - ---i+""'*--------- -:-:-~.;,:-r.,. .. ,,. ..., HC) ------------- ~:~~::~::::~~:~::}:::q?)jf[_ 1 ,:/~f)Sc7!i (cT-40t) ----.---------- <~\1S6 (T-41) 1 nk \ f::[EQ Blank Port 1 1 X 1 X /i::<:!EC Blank PorU X ~:--. -;*';: rv-,.0.:- : : ] / ! Duplicate X :]/ Trip Blank :rr:1:t?,,rrm~ }i~i: Temperature Blank :-:-:-:,:-:-:-:-:,:-,.........., 05/09119 05/09119 8,1 2 X quired Turnaround Time: STD 10 Wk Days l"2J 5 Wk Days 0241-!our Reilnqulsood II: Std QC + Raw Data - ~ I V: SW846 CLP-Like "Tl z :r- Note: Any changes mm.t be made In writing once samples and cm:; form hW.'& tmmi l!l\ll)mltredtu AL"!i L.iJlrofl<twy Gmup. Copyright 2009 lly ALS Laboratory Group 0 0 /vt.. / 1 c.r-, o,o 0 0 Page 24 of 27 0 (,) .i:,,. 0) .i:,,. EPA Inspection Report - Page 1915 of 1969 U oHM system oons!ltot.. you1 agreemont to the ,efllice mdltion In tho current fed El< SOBvl< Gold, 111>1 on redeicrom. FedElr will not bo ,e,pon,lble for anv claim in""""" of $100 po, ;,aokoll'!, whethorth =It of la,., dom&f"', delay, ooo-dollvory, ml,dolivery, " ' mllnft>rmatloo, onle,so you deelore higher value, poy M odditlooal ci>o,10, docomeot you, actual lo" and file !lmcly clalm. limltatioosfoood In th" corroot fodEx Se1i<o Golde apply. You, rightto mcovor!rom Ffldb; far if:NV ian, indudlng lntfir'IS:ic v,1ah,1e of thi, peiitkaae, !os:s of &a!ess:, income !ntem,t~ profit~ attame:y'!S festii, costs, euirl othe1wrm, of damage wh"'1ho1 direct, lntldootol, ronsoquentlol, "' ,peclol ls limited to tho w,,oterof $100 or the omhorlred ded:sirad wlue. H.ecovery c:am,ot exr:0~d adusl doc:umentad !ws. M8!1~l!'rmm fur it~mi t'lf imctraon.ilru11rv v~!ue !:s $1.000~ B,j. Jewelry, pre<:lou metal, n~ioblo laot'"mot, ad o!h.,, items 11.ted In""' Service G!do, Written elaim, must be filed within '1:1ltt time llmltia, <"rr,,m fl,dExSer11loo Gulde, Aft ~MQ !h! lllol: CO~!IGltel! COPY Pl.EASE PUICE IN FRONT a~ l'OUClt 1. Fclt:I ~ofd. ~tifflfdd ~Sil"~k'<N; Uw hotirtln't$t!m&. 2, ?lace l!IDQ! !n ~hlpptrig pOO(h l':sri!.i 8fibi. ~ eo ywr $hlp,m,iM11. fijj > -.,, a1i~ el.. m lo I ij i\ en Cl> ,,;;;,,,4G> m oL!~ ~ li ~ ~ 00.1... 8 !I!!!! r;,~:::c j!!: ~ ;;; t:iO 5 oo :;g, i!i - "'C:: -I 11'11 ... ;;;;;; Im m00 -<: rn~ ~ ~~-I Qj lij., !"!"!"!' , .z.... 0):z,, ; i .~ ;~;.;;.;1.;i,, :0;:;!I w :'pT;;l =i (II) .f.l. ::! ~ ' Ii . I ii I s~~ E! :i!: ~ "1:1 : ~I , Sil 2!:! ,,:~ ii 2!' i ~ ~Isl = 1 "=?' :J ~ I ,~ u:::, i ii: ~ .... m>-..<.,,, ..., ~_ ei l' l ,, I , ),o~i!; ~ ii :::Cw c, .;;;i ;il,i :r-zI l ll8'11'lmlllllw 5'.i1CliOOlC1104C "Tl 0 0 0 0 Page 25 of27 0 (,) .i:,,. 0) 01 EPA Inspection Report - Page 1916 of 1969 SHIPPER'S DECLARATION FOR DANGEROUS GOOPS Sl>lppor NAVAJO REFINING COMPANY C/0 AOU/1 MICROBICS ~ t 501 EMAIN ARTESIA NM88210 US c....1g. . . ~ - CoreyGrarsdils ALS - 10450 S!!!m;iiff Sul!e.210 HOUSTON TX 77099 US - ~ ~ CO#Dplll!lfb1d andslg.naf.l copl'&S ii,frhls DeeJm116'ioo must be ham:lt to the ope.mtOr ~ TAA~Sl'ORT DETAILS Thl:!li .shipment!:& within thu ~ llmltalloos P'""rlbod for. !do!ot oppl!o>ble) All)'ort of Dopa,turo ARTESIA {Provide ot leaot throe cople$ b:i airline.) Air Wybl llo. 709308590773 Pall$ 1 of 1 Page{SI Shipp.,... Rofereo"' Nomlmr foptlonal) FX 18 Compliant Express CAFE3211 WARNING Failure to comply with all respects with tile applicable Dangerous Goods Regulations may be in breach ofthe applicable law ,subject to legal penalties. ~ ~ Al'J>O'l ol llostlntion: HOUSTON P:E!SGRA ~ NATURE AND QUANTITY OF DANGEROUS GOODS ur; llmbnnldMffllcol/001\1111111>,.,; P"'l""sll/pp/119 "'""' Cl..., orllMofon {bsi...-Yrlsi\l, p..lrJltfJ-(/f"1qlll,od,), doll othor "1qll/ra,//nfonmal/M. ~ UN 3266, Corrosive liquid, basic, inorganic, n.o.s,(Sodium Hydrnxide),8,111 - UN 1268, Petroleum distillates, n.g.s.,3,11111 0.04 L/1366 All Pac:ked In One FIBREBOARD BOX Q = 0.1 0.08 lJ/854 -~~-~' --------------------------------------------------------------------_J ~tt~ Addillorral HaNdl!ng lnfom,a!lan 24-Hoor Ernergor,oy R..pooso- CHEMTREC 1-000424-9300, CCN 201319 ~ ~ Ihorooy d..loM thol ll!o ooolomo ofilllo ..,,..1gnmen! ro fully ond INome/Tillo of Slg~alo!)I =ra!o!y d..e,11,00 l>ov by Ill pmp oh!pplog aome, ood ""' IBrody Hubl>Jm/Em.ironmenlal Cooro!notor ~ 1 ~ ~1;,":":r'!::':':r!':'i!'ni:~~=::":P::~h: IPlace and Date anmmauonm and Natkmal Gcvt1mmental Reg&.1!Qtlons. I dechrim ttiat !Mesta, NM 051091.2019 Iii ofthe appficaabl& air tramspDrt naqul'mmenti& hwa tffl!lln ml:t J $ ~ : rSignohlm Brody Hul>bard '"1_00_04_2_"9_30_0_______""'-._--,-y-r.,..-.-.-.H.-m-bo-,"'"'i ,....,..~-~ ~ ~ I ~!De~Tm Rle:SEARCH,~Dl!CAi. Pm.Gli0$!$ QR TRS:AtMENT. ADR. EUROP&Al!ll Tit!Ui1SPOR'tSTA11fMSf:ffr: CQIIUM3E IN AtCCRDAMi:'=WE'ffl 1.u.a:.1 ro~ R.IWSOACTNE MA'rl!RIAP.. SHlfflENT ACCBSPTABI.! FOR PMSEtdGEra ruRCMFr, THE SHIPN!!Nt OONTAU11$ R.AOIMC'mf5 MA'fi:fflALIHffl9UHED mR ua:e: BN OR - "Tl -- : :zr-0 0 LICl>!.iJ~!'t!:in~s iuu: 0 0 Page 26 of27 0 (,) .i:,,. 0) 0) EPA Inspection Report - Page 1917 of 1969 SHIPPER'S DECLARATIO!\I FOR DANGEROUS GOODS Shlppor NAVAJO REFINING COMPANY C/0 AQUA MICROBiCS ~ ~ 501 EMAIN ARTESIA NM88210 US Co,,ofgo. . ~ ~ CoreyGrnndlts ALS 1Q450Smns:liff Suilo210 HOUSTON TX noog us ~ - 1Wl!!l .co.mpleusd ands(.Qn&d mples offir~ Dm:lamfion must iOO handed to tho ope!1Slor - TRANSPORT DETAILS Toils: &hlpmBnt 1, within ths ~ ~ llml!.1tl<>ns P""'Orlbod for: (dololo non pplloablo) Affport of Dapartum ARTESIA !Pmvid<> at least three copies lo airline.I j lllrW"Yhlllllo. 709308590773 1Page 1 of 1 Page{s) {Shlppef"s: RaferancQ Number (OJ!l/aQ FX 18 Compliant WARNING Express CAFE3211 Failure to comply witll all respects with tho applleab!e Dangerous Goods Regulatlona may be in breach of tho applicable law ,subject to legal penalties. CMGO AIMM!'T Q~LY - ~ .<"i,<>. ofD"linotloo: HOUSTON ABSGRA ~ NATURE AND QUANTITY OF DANGEROUS GOODS UN Number or ldontlflcafll>n /lumber, pmJl<!'sl!lpp/ng .,.,.,, Class or DM.slon /sul,"1dkily rlol\l, io,,<'M1!11 group (If._""'1), Md all <>!Ir&' - 1'.'qUlmo'lnfomR1ffon. UN 3266, Corrosive liquid, basic, iJ)organic, n.o.s.(Sodlum Hydroxlde),8,11/ UN 1268, Petroleum dilllillates, n.o.s.,3,11111 0.04 U/366 ~ ~ All Packed In One FIBREBOARD BOX Q.=0.1 0.08 IJ/854 ~~~ --~~ Addltlanol HondllngInformation - - 24-Hoor E'""'ll"'Y Rosf'lll<>- CHEMTREC HO!l-424-0000, CCN 201$19 [Y'.o, .,,,,,,.,,,,,. --{'.'.'.''"cc --C'.''%".y C'.''."'.''."0%<"'.'.'" """"""''" ,.,,................,.,,, ..., ,,,,,,,~... ~ ~ I h.,.l!y detl!!m lilattoo oontonls of!hill cons!gnmont am lilliJf and act1.um:eiy described QOOye by the proper shlppl'.ng mrme~ and lillH& olo!!olllod, pool111god, ml'l!od d lallollildJpi"""rdod, d am In oil raopm:ill In propo, oondltlon lor imllOporl =rdlog to opplloobl lntematlcnl!t! and Natlonal Governmental ~latlons.. I dedam that au of th applicolllo olr lnnport n,qulmmenili have l>i!en met. ~ ~ 18004249300 .fmi1R1'6FQMyT.s.l,phMI~ Namo!Tftlo of Slgn""'ry Brody Hut>ilon!/En,romnenla! Coorolnatm Place and Daw MMle,NM 0~19 Sigmdure ill,idyHbbard .. r,;::7.,,., An. IJ (> . . . . . . . . . . . . . . .) i~~ ~ : zI INCIDEMT'TO RESEAAe!i, ME.l'JiCAL OIAGNOS:IS Ori: nmATMEMT. MIil EURillPEAIII 1M811SPOR'Ti!BTATEMENT: e.MruA.Ge IH ACCORDAIIJC!! WITH 1.1.U.1 Fem R.MOOA.tWE MATEfWU.. S:HIPM!!lrf ACCEPTABLE FOR PAV.hllllG.ER. .NR.CRAPT, THE SHIPMSST CONTAINS AADIOAC"nVE l!'i'AAil!RlAL!PITI:NDEl.l FOR US! R9 OR "Tl :r-0 0 W(;.OS $tS)';t~'J ~rn:.o - - 0 0 Page 27 of27 0 (,) .i:,,. 0) -..,J EPA Inspection Report - Page 1918 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 June 14, 2019 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling {EOL) Dear Gabriela, Work Order: HS19060420 ALS Environmental received 3 sample(s) on Jun 07, 2019 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, Generated By: DAYNA.FISHER Corey Grandits Project Manager Right Solutions Right Partner www.ahgk4:iaLrnrn Page 1 of25 HFNA-000003468 EPA Inspection Report - Page 1919 of 1969 AlS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19060420 LabSamp ID HS19060420-01 HS19060420-02 HS19060420-03 Client Sample ID S-1 {API HC) S-3 (API Water) S-5 {T-40} Matrix Liquid Liquid Liquid Date: 14-jun-19 SAMPLE SUMMARY TagNo Collection Date 06-Jun-2019 09: 19 06-Jun-2019 09:33 06-Jun-2019 08:51 Date Received 07-Jun-2019 09:00 07-Jun-2019 09:00 07-Jun-2019 09:00 Hold L.wJ ,:.-............~ . ~ ~ f...............l L............J [::] Page 2 of25 HFNA-000003469 EPA Inspection Report - Page 1920 of 1969 ALS Houston, US Date: 14-Jun-19 ==============----=-"==~-===-----==============-=---=-,,:,:,:,:.~=~~=,: Client: Project: Navajo Refining Company BWON Monthly Sampling (EOL) CASE NARR.ATIVE Work Order: HS19060420 Work Order Comments The analysis for Specific Gravity was subcontracted to ALS Environmental in Holland, Ml. Final report attached. Page 3 of25 HFNA-0000034 70 EPA Inspection Report - Page 1921 of 1969 AUS Houston, US Date: 14-Jun-19 Client Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-1 (AP! HC) 06-Jun-2019 09:19 ANALYTICAL REPORT WorkOrder:HS 19060420 lab 1D:HS19060420-01 Matrix:Llquid ANALYSES RESULT $1.JBCONTAACTED ANALYSIS SPECIFIC: ~~VJIT Subcontract Analysis See Attached REPORT Dill.JTION DATE QUAl MDL LIMIT UNITS FACTOR ANALVZED M~t-ho~diNPi~""""""""""""""""""""""""'"""""'" ------- Analyst: SUBHO 0 NA 14-Jun-2019 08:46 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of25 RIGHT SOLUTIONS 1RIGHT PARTNER. HFNA-000003471 EPA Inspection Report - Page 1922 of 1969 ALS Houston, US C!ient Project: Sample ID: Collection Date: ANALYSES Sul:Jcontrac! Analysis Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 06-Jun-2019 09:33 RESULT QUAL MDL See Attached 0 REPORT LIMIT Date: 14-Jun-19 ANALYTICAl REPORT WorkOrder:HS 19060420 lab lD:HS19060420-02 Matrix:Liquid UNITS NA DILUTION FACTOR DATE ANALYZED Analyst: SUBHO 14-Jun-2019 08:46 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of25 HFNA-0000034 72 EPA Inspection Report - Page 1923 of 1969 A.LS Houston, US Client Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 06-Jun-2019 08:51 ANALYSES RESULT QUAL MDL REPORT LIMIT SUBCONTRACTED),NALYSIS SPECIFIC - _____M_e_t-ho-a-:N-A----------------------- 'GRAVITV Subcontract Analysis See Attached 0 Date: 14-Jun-19 ANALYTICAL REPORT WorkOrder: HS 19060420 Lab ID:HS19060420-03 Matrix:Liquid UNITS NA DILUTION FACTOR DATE ANALYZED --------,--,,---Analyst SUBHO 14-Jun-2019 08:46 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of25 HFNA-0000034 73 EPA Inspection Report - Page 1924 of 1969 ALS Houston, US Date: 14-Jun-19 Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19060420 DATES REPORT Sample ID Client Samp ID Collection Date TCLP Date Prep Date Analysis Date DF ~---------------~"""""""""'"""""' -.........................- -..~..-.... .Batch ID R340484 Test Name: SUBCONTRACTED ANALYSIS SPECIFIC GRAVITY Matrix: Liquid HS19060420-01 HS19060420-02 HS19060420-03 S-1 (API HC) S-3 (API Water) S-5 (T-40) 06 Jun 2019 09:19 06 Jun 2019 09:33 06 Jun 2019 08:51 14 Jun 2019 08:46 14 Jun 2019 08:46 14 Jun 2019 08:46 Page 7 of25 HFNA-0000034 7 4 EPA Inspection Report - Page 1925 of 1969 ALS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19060420 Date: 14-Jun-19 QUALIFIERS, ACRONYMS, UNITS Qualifier ........................Description.. Value exceeds Regulatory Limit a Not accredited B Analyte detected in !he associated Method Blank above the Reporting Limit E Value above quantitation range H Analyzed outside of Holding Time J Analyte detected below quantitation limit M Manually integrated, see raw data for justification n Not offered for accreditation ND No! Detected at the Reporting Limit 0 Sample amount is > 4 times amount spiked p Dual Column results percent difference > 40% R RPD above laboratory control limit s Spike Recovery outside laboratory control limits u Analyzed but not detected above the MDUSDL Acrcmym______--_D_e_s_c_r~ip~t_io_n_ DCS Detectability Check Study DUP Method Duplicate LCS Laboratory Control Sample LCSD Laboratory Control Sample Duplicate MBLK Method Blank MDL Method Detection Limit MQL Method Quantitation Limit MS Matrix Spike MSD Matrix Spike Duplicate PDS Post Digestion Spike PQL Practical Quantitaion Limit SD Serial Dilution SOL Sample Detection Limit TRRP Texas Risk Reduction Program Page 8 of25 HFNA-000003475 EPA Inspection Report - Page 1926 of 1969 AlS Houston, US Agency Illinois Louisiana Dept of Defense Kansas Oklahoma North Carolina Maryland Arkansas Texas Date: 14-Jun-19 CERTIFICATIONS,ACCREIJITATIONS & UCENSES Number 004438 03087 019 2018-156 624-2019 343, 2018-2019 Expire Date 29-Jun-2019 30-Jun-2019 20-Dec-2021 31-Jul-2019 31-Aug-2019 31-Dec-2019 30-Jun-2019 Page 9 of25 HFNA-0000034 76 EPA Inspection Report - Page 1927 of 1969 AlS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling {EOL) HS 19060420 Lab Samp ID HS 19060420-01 HS 19060420-02 HS19060420-03 Client Sample ID S-1 (API HC} S-3 (API Water} S-5 (T-40) Action Login Login Login Date 08/06/2019 14:47:22 08/06/2019 14:47:22 08/06/2019 14:47:22 Date: 14-jun-19 Person PMG PMG PMG New Location Sub Sub Sub Page 10 of25 HFNA-0000034 77 EPA Inspection Report - Page 1928 of 1969 AlS Houston, US Client Name: Work Order: Navajo Refining HS19060420 Date/Time Received: Received by: Date: 14-Jun-19 Sample Receipt Checklist QI::JJ!rt:l.Q.1.!Hl!tft!l NDR Checklist completed by: Paresh M Giga eSignature ' Matrices: 8-Jun-2019 I Date Reviewed by: Carrier name: Corey Grandits eSignature -- 10-Jun-2019 Date Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? VOA!TX1005/TX1006 Solids in hermetically sealed vials? Chain of custody present? Chain of custody signed when relinquished and received? Samplers name present on COG? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Sufficient sample volume for indicated test? All samples received within holding lime? Container/Temp Blank temperature in compliance? T e m p e r a t u r e ( s )!Thermometer( s ): Cooler(s)/Kit(s): Date/Time sample{s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Login Notes: Client Contacted: Date Contacted: Contacted By: Regarding: Comments: Not Present Not Present Not Present Not Present 1 Page(s) COG 1Ds:None 1.5c U/c HazmatPak $/7/19 20:00 Yes [ ] Yes Yes r"l~..............:.:: No D No L~~...J..~ No LJ -N~; VOA vials submitted E::]f0l NIA ::.................~ NIA Person Contacted: Corrective Action: Page 11 of25 HFNA-0000034 78 EPA Inspection Report - Page 1929 of 1969 Chain of Custody Form HS19060420 IV, UT 7700 Page _1_ of __j_ J BWON Monthly Sampling (EOLJ 4903 Navajo Refining Company PA Enuironmantal ~:/M~~,J~:~c::~ .....------~ ::::::::::::::;:;:::::;:;:::::::cusitomer-:lnfotmadijtr. . '.G."r,ko..i.c...1-.:e.r'}.,l :){~~~f~,~::: Navajo Refining Company LLC /:{~~~~\~~~f T)'lrTumer Ga1>1comils _ _,_:i_\_1:-:::_\_)-~-#-~i-.#-~-)~~~:[Susie Aguilar 11111111111111 11 5280 .. k.:y>:/::::::::::::::~r~~~~r:~~tiQr,j:~$q~~~:~r.:~JY:~i.$::::::::::::::::=:::::::::::: :~:;specific Gravity }}/\}/{~~;*: (}/{{:}::;~rf{ Eait Main >. -;:-:.OOOO.0.''"0'0<00 <" SO.< 0 00 0 ,w,w,-.-.-. --.- ~-:-::~:::::;:;:;:.-.---::-~:;:::~.-;:~.-:-:?;-~;:-i-- P.O. Box 159 501 ;~.:;.>c:;;: '.,'.;:;:::;:::;:;:;;;'. - .,, ______,,,,....,>..c>:,,..,:_:-_:,;"-,:"-.:,c;,;..,,..,;~.;:w>~:::~:::~::~:<...,:, - - - - - - - - - - - - - - - - i - . - 4 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ):/:}~/fyf.~~t~?t( Artesia, NM 88211-0159 ... , .......... , , ... ,,' :.::.::.:.::.::.:.::.i:./.::.::.:.::.:~..ij,j,.~.~(575) 748-3311 -.--,-,.-,,-;-,.-;..-,-,.- :-.:,-:.-:.-:.,:.,:..:,.:..:,.:,:.:,.:-.:.-,:.-:....,,,;...;.li1t'1,"...7""'17.'".,",.."..".."..1 ..,..-..,.,,..- /{JS-1 (API HC) :;:jf;:ls-3 (AP! Water) } } ) S-5 (T-40) ::::it< } i , : . ; , ; . ; ; , i - , -.. ,_,,h,, 06/06119 06/06119 9:33AM 8:51 AM I Liquid Liquid aI 1 11 1 1 ..+! ..-Xt-- .......,,,.. .,,,,....,,,,,.,.,......... '<' :-.-.f-y C ... ::;, ;; . . -~- . . .- .-- ~~~ -~-1"0:> Required Turnaround Time: D STD 10 Wk Days 0 S Wk Days (tl (jf er I "Tl z :r- Note: Any changes must be mad& in writing once samples and COC Form have been submitted to ALS laboratory Group. 0 0 0 0 Page 12 of25 0 (,) Co~t/~$1.aboratory Group .i:,,. -..,J (!) EPA Inspection Report - Page 1930 of 1969 u.,, of thiuystom oonstitut yooragroomentto the ,eNice condition, In ti,e ,u,raot fedE, Servioe Gulde, avallablo "" feclex.<om. Fed~will oat be ra,,>onsibleforony clolm in exre,..:lf$100 par poci<&a!!", whtherthe re,ult of los;,domogo, deley, flOi'!-deii1.11MY, mlii:cle!hl'ery, ot n;;hsfriforrnatlori, urdffl you ded~re PJ higher veiu~, pisy an sdd!tf.ona! ch.srge1 do~~ment y<3ur actual I"' ond file timely <loim. Limtt.etiondound In tho cumsnt FedESNlce Gulde opply. Your right to re,o,,.,,!rom FedEx for r:inv k1~J in!'.:.'.!uding intrlnsl-c vaful!9 of the p,!!itk:age~ losg; of sales, ln,ome inMr&sti roflt, ,gittarney'ife.est com-11 ;f'lld "" othorrorm, of domoge whether dime!, Incidental, ,on.,,quentlol, or P<il 1, llmlted to tho graoter of $100 or the outhorlrod deelo""d value. Roc.-,very <rinot',,.ceed actual documeoted los,. M3"1mum for Item, of ...:troordlnaf\l 11l"a 1, $1,000, e.g. jewelry, predou:s metals, ne"goti21183:le fnstmm0;rrrn and other item!S f~ed in ourSe:n,J(;e Guide. Written d~ims must bf.! fllead within strict. timll! limits~ ,ee cune'.iat FedEx Servka' Guidf!:. A.fmr prini.iri; l!'ii!ll- l!!ibt!: COIISIGNe COPY' Pl!ASE p,.;,,;:;e Ill MOffTO~ POUCH 1. ::oit:B thi pri~tis<l Pfl9* ~en:g u~ hOM'.r.mmi ~t!8. 2, !"lste tsba! lri shtpp~ ~cJJi;;h tl':d i&m~ lt fu ~tJt !ll-h!~!71'll ."'""" .. > fiilii el~ ---,m '"-I ~ .. '" (n w ii C) i: \j g ii .. 0 g. ._;;a .c..oa 1,1,1 ..-:-:> ~ II~[ I -g 2!! 'Tl ,13 0 :::oi ::11:1 - , ~ii:::i .;;: -< -.i' ~ 0 <..! ... 5i Aiiii ... -"""""' i!. !"? >g~ ~ ~- ::c (D G') -1 >; ir~a~~~~ I ;::: f c: =i ui 00 ~ $;. ;;;,;, 1jl(l')ITl0 ffl- ~i! iii! d ~ ~ -< ffii!! iiii5! z Cl>),," G'J, lij;;; ~\\ ~ii ...;;j ~-,i C~ z ;";";". 'j .g..a ,, "Tl . -g I ~ i ;;:i JtO . w' =i i =I I m,~ ' >~ !--- . ! ~I! < i ~ ~,.. ~ !:!!iii'& ' ~- ~o!s ~6~ '1 ;1.i .) :r-z -11:Sh~iw iio1C1,!l210~04C I "Tl 0 0 0 0 Page 13 of25 0 (,) .i:,,. OJ 0 EPA Inspection Report - Page 1931 of 1969 Sti!PPER'S DECLARATION FOR DANGEROUS GOODS Shipper NAVAJO REFINING COMPANY - C/0 AQUA MICROS!CS t 501 EMAIN ARTESIA NMS!l210 US ~ ContJgnfffl' ~ COi"!!'/ Grandi!& ALS 10450 Sll!neliff t ~ Sulte210 HOUSTON TX 77099 US l'liR> oomplo!od ami &/gnM ropios of this Declitmllo mu.t b h"""'1dll>lh0Dpoi1IIM t - This ~lpmenl lo wffllln lh ~ llmlla!U<>M pre..ribod for. ! d - """ ppli..blI AJrpo<toli:lopmu"' ARTESIA (i'mvld !!I lt !hmo coplO!I to irlloo,l Air Wsybm No. 709308590784 Roforn...,N<!mbor (Opl/<>M~ FX 18 Compliant WARNING Express CAFE3211 Fa!lum to comply with all respects with the applicable Dangerous Goods Regulations may be in breach of tile applicable law ,subject to legal penalties. ~ CAIIOO MIWIWT t OIIU..'f A!.\SGRA t NATURE AND QUANTITY !;)F DANGEROUS GOODS UN Number"' ldonlil1r:olhm llumb01, fJ"11'"' 511/pplng ,..,,.,, Class"' DMslon f-..:V115.111, pa<ltlng gn,up (IfraqulnK!I, mi all offlot ,-lrod lilformoliol!. ~ lJN 3266, Corrosive liquid, basic, Inorganic. n.o.s.(Sodium Hydroidde),8,111 UN 1268, Petroleum dlstillales, n.o.s.,3,llll/ 0.04 lJ/366 ~ All Packed In One FIBREBOARD BOX Q "0.1 0.04 lJ/854 Itt -~t~ -----------------------------------------------------------------------------------------------J Addltlorna! Handllnu Information I ~ 24.iiourEme,gencyRol!-CHEIIITAEC 1,SOM:14-aOOO, CCN201319 j t ! l hmby !l<!olore !bot !ho oorllnto of lhlo ,,.lgnmm ""'ful!lf d ...urallly dolSCribod ol>ovo by Ill p-oblpplng name, nd oro - clanlllod, p,okagl!d, mBrill!d lllld labolll!dlplacordl!d, and ... in ml t ropocts In pmpor oondl!lon far lrl!noporl aooorolng oo appiloallle lnli!rmrt!onol ond Nlllonol Governmamal Regull!!lo!IS. l doclSIO lhlrt Namemtm cf S1gB1lllory Brady Hulll>omlJE"""'nmemal Coorolno!cr Plaai and Datil Me>la, NM C!!/0012019 ff ofttm ppllooblo air iraRoport n,qulremonto hov,, l>ooo Old. t ISlgna!uro ---,. ] dfflw,m>,g- ;';, , ,r_..._. ~ I 18004249300 E.,,..,, ... ~~ t ! ~ zI : INCIOfNTTO ~ll!AIWH. M!DJCA!.. WAGNOBIS OR l'REATM1:1NT. MR fUROP!!AH TAANSPORTSTATEMEHT: CAR'RRAG5 JN N:-Coo.DARCE WITH 1.u.u 1 FOR ~ffi/'E MATERW..SHffilW!N'f ACeut,run..e FORPAS~E~AmCMFi, ffl!:B'HIPMl!!:NTOOHTA1N1S RAl.'lroACiWE NATe:R.W..!NT!Nl)S) FOR US!~ OR "Tl i-=.uuuu.- ----~-----~-~-u.-.-.-.-.w~=~--n~NNNNNNN N~N. ~ ~~~~----~-~--~-~---NN~~ N .J :r- ~ ~ 0 0 loom 1Msn!ll!'f Hml 0 0 Page 14 of25 0 (,) .i:,,. .O...J.. SOLUTiO\S EPA Inspection Report - Page 1932 of 1969 SHIPPER'S DECLARATION FOR DANGEROUS GOODS ~ ShlPI'"' NAVAJO REFINING COMPANY C/0 AQUA MICROSICS ~ 501 EMAIN - ARTESIA NM88210 US Consignee ~ ~ Cfflll' Grandits ALS 10>45DSt.sncillf Suile210 HOUSTON TX nD99 US ~ """'" ~ Two oomp/ol"o<IdOfgm,d hond&d to th opomo, oflhls l.le<lmtlo """'1 bo 'fAAl>iSl'ORT llETAILS l'illls hipmonl I - I n Illa ~ lim-ns pm..tlood for: t ! -rum spplltohlo) lllrpo,t <ii Copamiro ARTES1fi (l'ro.-!!le at least lllrt!E> coplaa to olrlloe.j AlrWaybm No. 709308590784 Pg 1 cl 1 Poge(I Shlppera Rofere"" NM!ber /pll<>Q FX 18 Compliant Iii Express CAFE3211 WARNING Failure to comply with all respects with the applicable Dangerous Goods Regulations may be in breach of tile applicable law ,subject to legal penalties. ~ ~ ~'ll*'*..rll<mloa!loo: HOUSTON NATURE AND QUANTITY IJN Numbot "'l<fM!ffl'.al/on Numbor, p,,,po, shipping .,.., Claso or llwl:llf<m /-""1>$/dlolyrislr/, ptdlng group /!f""l"lrod/, MIi a/1 othor - ~ ""'"''""mlormB!Jli>o. UN 3266, Corrosive !!quid, basic, inorganic, n.o.s.(Sodium Hydndde),6,1// 0.04 U/654 UN 1266, Petroleum distillates, n.o.s.,3,1111/ D.04 U/366 ~ All Paci>ced In One FIBREBOARD BOX Q=0.1 t-~~ ~~~~ [ Adil!tlonal Handlinglrm>...,..ticn ' ; 24-Hoo, Eni"'l!ency R..PtlflS"" CHBi,!TREC H!00-424-9300, CCII 201319 - ~ I h.,..l,y o..i.ro 1rnit111o...1e""' <>f!hlo oo~lgomoo!.,. lolly ~tcu~ d ~ atlwe .bytrMt pmpersbipplng n1m1&1 Rnd sre - ~ clalffled, pooi<lg..S, mool<..S and bbt!il..Slplocott!..S, oil!!""' ln oll rntpe<ll 1 propereom!ijk:m f<>, lmlloportoeeor<llng lo opplloitblo lnlo"'11i!lonal ond l>lertlonol GO'llfflffionlol Rogubllooo. l doolma tho! all ilftl!i& l!lppllcabils air tmmpcrt requ$R'Sments hdw& been met. Name/TIii& of Sl!IIIO!o,y Brady H"1lbon:IJrn,l,.nmonml Coamlnotcr Place and Date Mo~a. NM 00/001201 ~ t 18004249300 E~oo1T111dt.rQIP1 NwnM.r ~ ~ z FOR !l.A!llOMffilE Ml\l'l!RIAJ. SHIPl.!Ellf ACOEPTJWU! ro -CE Al!!C!WT, '!HE SHll'MEII'! COl!l'AIIIB IWl!OACmlE l\!Al'l!RW. !IITEHD!D !'fflt USE DI o I ffleffleH'f TO IWSEAR.CH, M!DICA:LD1AG~O!JS CR 'mlYt..TM!NT. Aim EUROPEAN iAAMSPl!JRTSTAffMENT: ~ ne ACCCIRDANC! Wl'rK 1,1A.%.'S "Tl ~U~---~U c~u :r- ~ ~ 0 0 I.CGOS.,'U31.:!l'S Wll 0 0 Page 15 of 25 0 (,) .i:,,. OJ N EPA Inspection Report - Page 1933 of 1969 SHIPPER'S DECLARATION FOR DANGEROUS GOODS Shippo, NAVAJO REFINING COMPANY C/0 AQUA M!CRQBICS ~ ~ 501 EMAIN ARTESIA NMBS210 l.lS Con1lgno - ~ CoreyGmndils AlS ~ 104SO Sta11cliff Su~e210 ~ l'wi> COOIPleM<todo/gnI ""P""' orth1" Del:/8ratlon meot be hMrded t~ the ep&mtor ~ TRANSPORT DETAILS This shlpment bl: wilhln th'ltl ~ llmli>!IOIIO pn,..ri!," I<,,: i<!olelo """ pplioollll Alrportomopmu"' ARTESIA (Provide !ti l&a&I !hra& copies 10 irilne.} l\lr Waybill No. 709308590784 Poge 1 of 1 i'ag<Jisl , Rlll:fsmn~ Number (opliamil/ FX 18 Compliant WARNING Exoress CAFE3211 Failure to comply with 11!1 respects with the appl!cabl111 Dangerous Goods Regulations may be ln breach of the applicable law ,subject to legal penalties. ~ ~ SGRA :&~M&: ..J'<l<lmm.,"ff!)<<>aieJ .~ NATURE AND QUANTITY OF DANGEROUS GOODS IIN-Oforlo'Mtffl- tlssmbe<, propo,"1s!pplog ..,.., a... orDM!!!oo (s-,yl'l<I(), pS<klng lJI00.0 (/1 -11"<t1, ao<f a/lotller MqU!rlid/n-/on. : UN 3266, Corrosive liquid, basic, inorganic, n.o.s.(Sodlum Hydroxide),8,!/1 UN 1268, Petroleum distillates, n.o.s.,3,111/1 0.04 U/366 ~ ~ AH Packed In One FIBREBOARD 110X Q ~0.1 0.04 U/854 ~~~~ ~~~~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 1 IAddllionol llaod!lng lnf111ma!ion I 24-Ho"r E1110rgO!lO)I ROSpoi1so- CHB\ITREC i-BOll4:M-9300, CCN :001319 I ~ - lIh"'1>!1J/ d..1..., 111!11!ho """"'f!!O ollllio 0<>ooignmont on, fully n<I fKtufflt&'1 descrtbQd abov,e Iii~ the proprar 1hJppin9 nema1 ol'!nt.1.&Je Nomo/Tllln af Slgnlory Bradt Hubberu/En~roomGf!tal COOl'dlootof ~ ;==:;:,~,~~==f~~==::.i~:'~~~:b:i Place and Dale l""3ml!llonl nd Nm!o""i Gt>vommoi11al Rogula!iol1o. i dol8<0 fflt MI. NM OW00/2019 a!l llif Rhi!!' appl~ble nrrtmnspmt n,qulremS8m':9 hav1111 b&en mat. ~ S!gnalurn BOlldyHabllal<i ! - - - - - - - - - - - - - - . - - - - - - - i (... ""11/n-) 18004249300 m~yTef8fphQl'l1-Ntm1"bilr u .... u I _ .... _____ ., ~ J 3 ~ ~ z n'.10 ..,,.)'"'""" '8A11!...L sm,.....A<:<:!!!'1'ABL FOR MSSENG !IIRCRAFT, TIIE SHIPM!!NT CCIIT!IIN9 AAl)IQIWllVE MA11!RIAI. INT!i111)!,D FOR UBE IN Oil I l"'3IOf<Tm a.ARCH, MDl<W. DIAGliOOIS OR TREA'IMENT.,,R EUROPEAli 'llWISPaT STAm!ENT: CAAA!AGE IN ACOORIWIOE Wini 1.1il1 "Tl :r- ~ 0 0 WGO~ ~1~~$$ 11,111 - 0 0 Page 16 of25 0 (,) .i:,,. OJ (,) EPA Inspection Report - Page 1934 of 1969 14-Jun-2019 Corey Grandits ALS Environmental 10450 Stancliff Rd Suite 210 Houston, TX 77099 Re: HS19060420 Dear Corey, Work Order: 19060672 ALS Environmental received 3 samples on 11-Jun-2019 09:30 AM for the analyses presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental - Holland and for only the analyses requested. Sample results are compliant with industry accepted practices and Quality Control results achieved laboratory specifications. Any exceptions are noted in the Case Narrative, or noted with qualifiers in the report or QC batch information. Should this laboratory report need to be reproduced, it should be reproduced in full unless written approval has been obtained from ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. The total number of pages in this report is 9. If you have any questions regarding this report, please feel free to contact me: ADDRESS: 3352 128th Avenue, Holland, Ml, USA PHONE: +1 {616) 399-6070 FAX: +1 {616) 399-6185 Sincerely, Chad Whelton Project Manager Report of Laboratory Analysis Certificate No: MN 026-999-449 HFNA-000003484 EPA Inspection Report - Page 1935 of 1969 ALS Group, USA Client: Project: Work Order: ALS Environmental HS 19060420 19060672 Lab Samp ID Client Sample ID 19060672-0l HSI 9060420-01 19060672-02 HS19060420-02 19060672-03 HS 19060420-03 Date: 14-Jun-19 Matrix Liquid Liquid Liquid W o:rk O:rde:r Sample Summary Tagli!umber S-1 (API HC) S-3 (API Water) S-5 (T-40) CoJlection Date 6/6/2019 09:19 6/6/2019 09:33 6/6/2019 08:51 Date Received 6/11/2019 09:30 6/11/2019 09:30 6/11/2019 09:30 Hold in____J - Page 18 of 25 Sample Sunm1ary Page 1 of 1 HFNA-000003485 EPA Inspection Report - Page 1936 of 1969 ALS Group, USA Client: Project:: WorkOrder: ALS Environmental HS19060420 19060672 Date: 14-Jun-19 QUALIFIERS, ACRONYMS, UNITS Description * Value exceeds Regulatory Limit ** Estimated Value a Analyte is non-accredited B Analyte detected in the associated Meihod Blank above tbe Reporting Limit E Value above quantitation range H Analyzed outside ofHolding Time Hr BOD/CBOD - Sample was reset outside Hold Time, value should be considered estimated. Analyte is present at an estimated concentraiion between the MDL and Report Limit ND Not Detected at the Reporting Lim.it 0 Sample amount is> 4 times amount spiked P Dual Column results percent difference> 40% R RPD above laboratory control limit S Spike Recovery outside laboratory control limits U Analyzed but not detected above the MDL X Analyte was detected in the Method Blank between the MDL and Reporting Limit, sample results may exhibit background or reagent contamination at the observed level. Acronvm Description DUP Meihod Duplicate LCS Laboratory Coniml Sample LCSD Laboratory Control Sample Duplicate LOD Limit of Detection (see MDL) LOQ Limit o:fQuantitation (see PQL) MBLK Method Blank MDL Method Detection Limit MS Matrix Spike MSD Matrix Spike Duplicate PQL Praclical Quantitation Lim.it RPD Relative Percent Difference 1TIL Targei Deieclion Lirnit TNTC Too Numerous To Count A APHA Standard Methods D ASTM E EPA SW SW-846 Update III Units Reported none Description Page 19 of25 QF Pagel of1 HFNA-000003486 EPA Inspection Report - Page 1937 of 1969 ALS Group, USA Client: Pro.Ject: Sample ID: Collection Date: ALS Environmental HS19060420 HS 19060420-0 I 6/6/2019 09:19 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Jun-19 Result Qua] Report Limit VVorkOrder: 19060672 Lab ID: 19060672-01 Matrh:: LIQUID Units Dilution Factor Date Analyzed 0.844 D5057-90 none Analyst: RZM 6/13/2019 02:15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 20 of25 Analytical Results Page 1 of 3 HFNA-000003487 EPA Inspection Report - Page 1938 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS19060420 HS19060420-02 6/6/2019 09:33 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Jun-19 Result Qual Report Limit Work Order: 19060672 Lab ID: 19060672-02 Matrix: LIQUID Units Dilution Factor Date Analyzed 1.00 none Analyst: RZM 6/13/2019 02:15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 21 of25 Analytical Results Page 2 of 3 HFNA-000003488 EPA Inspection Report - Page 1939 of 1969 ALS Group, USA Client: Project: Sample ID: Collection Date: ALS Environmental HS19060420 HS l 9060420-03 6/6i2019 08:51 AM Analyses SPECIFIC GRAVITY Specific Gravity Date: 14-Jun-19 Result Qual Report Limit Work Order: 19060672 Lab ID: 19060672-03 Matrix: LIQlTID Units Dilution Factor Date Analyzed D5057-90 1.17 none Analyst: RZM 6i13/2019 02:15 PM Note: See Qualifiers page for a list of qualifiers and their definitions. Page 22 of25 Analytical Results Page 3 of 3 HFNA-000003489 EPA Inspection Report - Page 1940 of 1969 ALS Group, USA Client: ALS Environmental Work Order: 19060672 Project: HS19060420 Date: 14-Jun- l 9 QC BATCH REPORT Batch ID: R.262578 Instrument ID WETCHEM Method: D5!l57-90 DI.JP Sample ID: 19060672-02A DUP Client ID: HS19060420-02 Run ID: WETCHEM_190613M Units: none SeqNo: 5712799 Analysis Date: 6/13/2019 02:15 PM Prep Date: DF: 1 Analyte Result POL SPK Val SPK Ref Value Control %REC Limit RPO Ref Value %RPO RPD Limit Qual Specific Gravity 1.003 The following samples were analyzed in this batch: 0 0 i906067201A 0 0 1906067202A 0-0 0.9996 1906067203A 0.3 20 Note: See Qualifiers Page for a list of Qualifiers and their explanation. Page 23 of25 QC Page: 1 of 1 HFNA-000003490 EPA Inspection Report - Page 1941 of 1969 ., iL,_,.,J,>><<'sr ''"""~ Subcontrad: Chain of Custody 10450 Stancliff Rd, Ste 210 Houston, TX 17099 T; +1 281 530 5656 I": +l ZBl 530 S887 www.alsglobal.com A.LS Group USA, Corp. 3352 128th Ave Holland, Ml 494249253 CUSTOMER INFORMATION: Company: C:1:mtaict: Address: Phone: Al.S Houston Corey Grand!ts 10450 Stancllff Rd, Ste 210 +1 281 530 5656 Email: Corey.Gram:!tt:s@atsg!oba!.com Altemate Contact: Email: INVOICE INIFORMATIONI: Company: ALS Houston Contact: Accounts Payable Address: 10450 Standlff Rd, Ste 210 Phone: +1 281 530 5656 Reference: HS19060420 TSR: Danielle wrnnlngs 1, HS19060420-01 !iM. (API HC:} Sub Specific Gravity to Al.S Holland 2. HS1906M20..02 Sw:3 (API Water} Sub Specific Gravity to Al.S Holland 3. HS1H6l>42003 SwS (T-40) Sub Specific Gravity to Al.S Holland Uquld Liquid Liquid 06 Jun 2019 O!ih19 14 Jun 2019 06 lun 2019 D!!il:33 14 Jun 2019 06 Jun 2019 08:51 14 Jun 2019 Comments: Please analyze for the analysis listed above. Send report to the emails shown above. ,-'~elsAi1tted'i~idt, QC Level; STD (!..aboratory Standard QC: method blank and LCS required} Relinquished By: Received Ely: CoQler ID(s): Date/Time: Date/Time: Temperature(s): Page 24 of25 @ HFNA-000003491 EPA Inspection Report - Page 1942 of 1969 ALS Group, USA Client Name: Work Order: ALS-!iOUSTON 19060672 Sample Receipt Checldist Date/Time Received: Received by: '!1.Jun-19_ 09:30 BNF Checklist completed by ~ (;:?.;:."''"'" eS;gna!ure Matrices: Carrier name: Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? Chain of custody present? Chain of custody signed when relinquished and received? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Sufficient sample volume for indicated test? All samples received within holding time? Container/Temp Blank temperature in compliance? Sample(s) received on ice? Temperature(s}/Thermometer(s ): Cooler(s)/Kit(s): Date/Time sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Login Notes: 11-Jun-19 Date Reviewed by: eSignature Yes '>/'! No Not Present Yes !>/'! Yes Yes ~ Yes ~ Yes ~ Yes ~ Yes l~J Yes lv'l Yes ~ Yes [;i'l No Not Present No Not Present li] No No No No No No No No Yes iv'[ No 15.8/5.8 C 1 6/1_1/2019_3:50:53.PM Yes No Yes i>I'! No SR2 No VOA vials submitted r~J NIA Yes No[.;ii NIA 11-Jun-19 Date Client Contacted: Contacted By: Comments: CorrectiveAction: Date Contacted: Regarding: Person Contacted: Page 25 of25 SRC Page 1 of 1 HFNA-000003492 EPA Inspection Report - Page 1943 of 1969 10450 Stancliff Rd. Suite 210 Houston, TX 77099 T: +1 281 530 5656 F: +1 281 530 5887 June 20, 2019 Gabriela Combs Navajo Refining Company PO Box 1490 Artesia, NM 88211-1490 Laboratory Results for: BWON Monthly Sampling (EOL) Dear Gabriela, Work Order: HS19060423 ALS Environmental received 8 sample(s) on Jun 07, 2019 for the analysis presented in the following report. The analytical data provided relates directly to the samples received by ALS Environmental and for only the analyses requested. Results are expressed as "as received" unless otherwise noted. QC sample results for this data met EPA or laboratory specifications except as noted in the Case Narrative or as noted with qualifiers in the QC batch information. Should this laboratory report need to be reproduced, it should be reproduced In full unless written approval has been obtained by ALS Environmental. Samples will be disposed in 30 days unless storage arrangements are made. If you have any questions regarding this report, please feel free to call me. Sincerely, Generated Sy: JUMOKE.LAWAL Corey Grandits Project Manager Right Solutions Right Partner wwwA.isgb!:w.isom Pagel of27 HFNA-000003493 EPA Inspection Report - Page 1944 of 1969 ALS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19060423 Lab Samp ID HS 19060423-01 HS 19060423-02 HS 19060423-03 HS 19060423-04 HS19060423-05 HS 19060423-06 HS 19060423-07 HS 19060423-08 Client Sample ID S-1 (API HC) S-3 {API Water) S-5 {T-40) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Matrix Oil Liquid Oil Water Water Water Liquid Water Date: 20-jun-19 SAMPLE SUMMARY TagNo Collection Date 06-Jun-2019 09:19 06-Jun-2019 09:33 06-Jun-2019 08:51 06-Jun-2019 09:37 06-Jun-2019 09:50 06-Jun-2019 09:50 06-Jun-2019 00:00 C&G101618-97 06-Jun-2019 00:00 Date Received 07-Jun-2019 09:00 07-Jun-2019 09:00 07.Jun-2019 09:00 07-Jun-2019 09:00 07-Jun-2019 09:00 07-Jun-2019 09:DO 07-Jun-2019 09:00 07-Jun-2019 09:00 Hold t:1 D D L,J f''l1::..............:.:: 1.:.............:.:: ~ ::: ~ ::: t_..............:.:: D C........1. :::.................~. Page 2 of27 HFNA-000003494 EPA Inspection Report - Page 1945 of 1969 A.LS Houston, US Date: 20-Jun-19 = = = = = = = = = = = = = = = = = = = = = = - - - - = = = = = = = = = = = = = = "-.."=........................... Client: Project: Navajo Refining Company BWON Monthly Sampling (EOL) CASE NARR.ATIVE Work Order: HS19060423 GCMS Volatiles by Method SW826Cl Batch ID: R340490,R340496,R340871 The test results meet requirements of the current NELAP standards, state requirements or programs where applicable. Batch ID: R:340284 Sample ID: S-5 {T-40) (HS19060423-03) Lowest practical dilution for HS19060423-03 due to sample matrix. Surrogate failure due to matrix. Page 3 of27 HFNA-000003495 EPA Inspection Report - Page 1946 of 1969 ALS Houston, US Date: 20-Jun-19 Client Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling {EOL) S-1 (AP! HC) 06-Jun-2019 09:19 ANALYTICAL REPORT WorkOrder: HS 19060423 Lab ID:HS19060423-01 Matrix:Oil ANALYSES RESULT QUAL MDL REPORT UNITS LIMIT -----------------------------------------------.-.---------- -------------------"""""------------ ....,...................... ..............,........,........,,....,.,, Benzene 46 0.24 Surr: 1,2-Dich!oroethane-d4 91.8 Surr: 4-Bromof!uorobenzene 95.5 Surr: Dibramof/uoromethane 87.8 Surr: Toluene-dB 99.9 2.4 70-126 70-130 70-130 70-130 mg/Kg %REC %REC %REC %REC DILUTION DATE FACTOR ANALYZED ...................................... Analyst: WLR 500 12-Jun-2019 01 :35 500 12-Jun-2019 01:35 500 12-Jun-2019 01:35 500 12-Jun-2019 01:35 500 12-Jun-2019 01:35 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 4 of27 HFNA-000003496 EPA Inspection Report - Page 1947 of 1969 ALS Houston, US Client: Project Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-3 (API Water) 06-Jun-2019 09:33 ANALYSES .................................... VOi.ATiLES SW8260C Benzene Surr: 1, 2-Dich/oroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL 0.59 92.3 95.1 98.5 100 Method:SW8260 0.030 Date: 20-Jun-19 ANALYTICAL REPORT WorkOrder:HS 19060423 Lab ID:HS19060423-02 Matrix:Uquld REPORT LIMIT UNITS """""""""""' ss,,sss,.......,.,.,... 0.25 70-126 82-124 77-123 82-127 mg/L %REC %REC %REC %REC DILUTION FACTOR 50 DATE ANALYZED ............................................. Analyst: PC 19-Jun-2019 22:56 50 19-Jun-2019 22:56 50 19-Jun-2019 22:56 50 19-Jun-2019 22:56 50 19.Jun-2019 22:56 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 5 of27 HFNA-000003497 EPA Inspection Report - Page 1948 of 1969 ALS Houston, US Client Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOL) S-5 (T-40) 06-Jun-2019 08:51 ANALYSES VOLATILES BY SWS260C Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.024 93.2 96.4 66.3 96.7 Method:SWS2&0 0.024 s REPORT LIMIT 0.24 70-126 70-130 70-130 70-130 Date: 20-Jun-19 ANALYTICAL REPORT WorkOrder: HS19060423 Lab ID:HS19060423-03 Matrix:Oi! UNITS DILUTION FACTOR DATE ANALYZED mg/Kg 50 %REC 50 %REC 50 %REC 50 %REC 50 Analyst: WLR 12-Jun-2019 01:10 12-Jun-2019 01:10 12-Jun-2019 01:10 12-Jun-2019 01:10 12-Jun-2019 01:10 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 6 of27 HFNA-000003498 EPA Inspection Report - Page 1949 of 1969 ALS Houston, LIS Client: Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling (EOl) Field Blank 06-Jun-2019 09:37 ANALYSES RESULT QUAL MDL .----------""'"'"""""""'"- :VOL.ATU.ES SWS260C Methcd:SWS.260 Benzene < 0.00060 0.00060 Surr: 1,2-Dichloroethane-d4 97.6 Surr: 4-Bromof/uorobenzene 98.4 Surr: Dibromof/uoromethane 104 Surr: Toluene-dB 101 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 20.Jun-19 ANALYTICAl REPORT WorkOrder: HS 19060423 lab !D:HS19060423-04 Matrix:Water UNITS mg/L %REC %REC %REC %REC DILUTION FACTOR DATE ANALVZED .." " " " " " " " " " " " " Analyst: PC 14-Jun-2019 05:58 14-Jun-2019 05:58 1 14-Jun-2019 05:58 1 14-Jun-2019 05:58 1 14-Jun-2019 05:58 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 7 of27 HFNA-000003499 EPA Inspection Report - Page 1950 of 1969 A.LS Houston, US Client: Project: Sample ID: Collection Date: ANALYSES 1VC>L.ATILES SW8260C Benzene Surr: 1,2-Dichforoethane-d4 Surr: 4-Bromof/uorobenzene Surr: Dibromof/uoromethane Surr: Toluene-dB Date: 20-Jun-19 Navajo Refining Company BWON Monthly Sampling (EOL) EQ Blank Port 1 06-Jun-2019 09:50 ANALYTICAL REPORT WorkOrder: HS 19060423 Lab ID:HS19060423-05 Matrix:Water RESULT < 0.00060 102 93.0 99.2 103 QUAL MDL REPORT LIMIT UNITS DILUTION FACTOR DATE ANALYZED ----------~------------ """"'""""'",ss"""'""_ _ _ Method:SW8260 Analyst: PC 0.00060 0.0050 mgiL 14-Jun-2019 06:23 70-126 %REC 1 14-Jun-2019 06:23 82-124 %REC 14-Jun-2019 06:23 77-123 %REC 14-Jun-2019 06:23 82-127 %REC 1 14-Jun-2019 06:23 Note: See Qualifiers Page for a list of qualifiers and !heir explanation. Page 8 of27 HFNA-000003500 EPA Inspection Report - Page 1951 of 1969 ALS Houston, US Date: 20-Jun-19 Client Project: Sample ID: Collection Date: Navajo Refining Company BWON Monthly Sampling {EOl) EQ Blank Port 2 06-Jun-2019 09:50 ANALYTICAL REPORT WorkOrder: HS19060423 Lab ID:HS19060423-06 Matrix:Water ANALYSES VOi.ATILES SW82MC Benzene RESULT Qi.JAL MDL REPORT LIMIT """"""""""'"-"~--------------Method:SW8260 < 0.00060 0.00060 0.0050 Surr: 1,2-Dichloroethane-d4 96.7 70-126 Surr: 4-Bromofluorobenzene 92.8 82-124 Surr: Dibromof/uaromethane 101 77-123 Surr: Toluene-dB 102 82-127 UNITS DILUTION FACTOR DATE ANALYZED ---------Analyst: PC mg/L 14-Jun-2019 06:48 %REC 1 14-Jun-2019 06:48 %REC 1 14-Jun-2019 06:48 %REC 1 14-Jun-2019 06:48 %REC 1 14-Jun-2019 06:48 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 9 of27 HFNA-000003501 EPA Inspection Report - Page 1952 of 1969 ALS Houston, US Client: Project: Sample ID: Collection Date: ANALYSES :VOLATILES SWS260C Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB Date: 20-Jun-19 Navajo Refining Company BWON Monthly Sampling (EOL) Duplicate 06-Jun-2019 00:00 ANALYTICAl REPORT WorkOrder:HS 19060423 Lab !D:HS19060423-07 Matrix:Uquid RESULT 0.62 QUAL MDL REPORT UNITS LIMIT ................,,..,..., , , , , , , , - - - - - - - - - - - l\llethod:SWS260 o.o:m 0.25 mg/L 93.9 70-126 %REC 95.7 82-124 %REC 95.2 77-123 %REC 100 82-127 %REC DILUTION FACTOR DATE ANALVZED ..............,,,,,,,,,,,,,,,,,,,,,,,, Analyst: PC 50 19-Jun-2019 23:21 50 19-Jun-2019 23:21 50 19-Jun-2019 23:21 50 19-Jun-2019 23:21 50 19-Jun-2019 23:21 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 10 of27 HFNA-000003502 EPA Inspection Report - Page 1953 of 1969 A.LS Houston, US Client Project: Sample !D: CoHection Date: Navajo Refining Company BWON Monthly Sampling {EOL) Trip Blank 06-Jun-2019 00:00 ANALYSES VOLATILES SW8260C Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB RESULT QUAL MDL < 0.00060 105 104 101 106 Method:SW8260 0.00060 REPORT LIMIT 0.0050 70-126 82-124 77-123 82-127 Date: 20-Jun-19 ANALYTICAL REPORT WorkOrder:HS 19060423 Lab ID:HS19060423-08 Matrix:Water UNITS mg/L %REC %REC %REC %REC DILUTION FACTOR DATE ANALYZED .............-~~~~~~~--. Analyst; PC 1 13-Jun-2019 14:56 1 13-Jun-2019 14:56 1 13-Jun-2019 14:56 1 13-Jun-2019 14:56 13-Jun-2019 14:56 Note: See Qualifiers Page for a list of qualifiers and their explanation. Page 11 of27 HFNA-000003503 EPA Inspection Report - Page 1954 of 1969 ALS Houston, US Client: Navajo Refining Company Project: BWON Monthly Sampling (EOL) WorkOrder: HS19060423 Batch 10: 3146 SamplD HS19D60423-01 HS19D60423-03 Method: VOLATILES BY SW8260C Container Sample WWol 5.138 (g) 5.118 (g) Final Volume 5 (mL) 5 (ml) Weight Factor 0.97 0.98 Container Type Bulk (50308) Bulk (50308) Date: 20-Jun-19 WEIGHT LOG Page 12 of27 HFNA-000003504 EPA Inspection Report - Page 1955 of 1969 ALS Houston, US Date: 20-jun-19 Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19060423 DATES REPORT Sample ID Client Samp ID Collection Date TCLP Date Prep Date Analysis Date DF - - - - - - - - - " " " " " ' = " > " = , s s s s - - - - - - - - - - - ............................................................------- Batch ID R340284 Test Name: VOLATILES BY SWS260C Matrix: Oil HS19060423-01 HS19060423-03 S-1 (API HC) S-5 (T-40) 06 Jun 2019 09:19 06 Jun 2019 08:51 12 Jun 2019 01:35 500 12 Jun 2019 01 :10 50 j3atch ID R340490 Test Name: VOLATILES-SW8260C Matrix: Water HS19060423-04 HS19060423-05 HS19060423-06 Field Blank EQ Blank Port 1 EQ Blank Port 2 06 Jun 2019 09:37 06 Jun 2019 09:50 06 Jun 2019 09:50 14 Jun 2019 05:58 14 Jun 2019 06:23 14 Jun 2019 06:48 Batch ID R340496 Test Name: VOLATILES - SW8260C Matrix: Water HS19060423-08 Trip Blank 06 Jun 2019 00:00 13 Jun 2019 14:56 ~atch ID R340871 Test Name : VOLATILES - SWB260C Matrix: Liquid HS19060423-02 HS19060423-07 S-3 (API Water} Duplicate 06 Jun 2019 09:33 06 Jun 2019 00:00 19 Jun 2019 22:56 50 19 Jun 2019 23:21 50 Page 13 of27 HFNA-000003505 EPA Inspection Report - Page 1956 of 1969 A.LS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19060423 Date: 20-Jun-19 QC BATCH REPORT Instrument: Method: VOLATILES BY SW8260C MBLK Client ID: Analyte Sample ID: MBLKW2-llS1119 Units: ug/Kg Analysis Date: 11.Jun-2019 23:30 Run ID: VOA.8_340284 SeqNo: 5117424 PrepDate: DF: 50 Result SPK Ref Control RPD Ref RPD PQL SPKVal Value %REC Limit Value %RPD Limit Qual Benzene """""""""-"" Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromof!uorobenzene Surr: Dibromof/uoromethane Surr: Toluene-dB < 25 2315 2341 2149 2405 250 0 0 2500 0 2500 0 2500 0 93.6 80- 120 0 86.0 80-119 0 96.2 81 - 118 LCS Client ID: Analyte Sample ID: VLCSW2-061119 Run ID: Result Units: VOA.8_340284 PQL SPK Val ug/Kg Analysis Date: 11-Jun-2019 22:40 SeqNo: 5117423 PrepDate: DF: 1 SPK Ref Value %REC Control Limit RPD Ref RPD Value %RPO Limit Qual Benzene ''''""~--- Surr: 1,2-Dich/oroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 45.77 5.0 50 46.38 0 50 48.92 0 50 44.17 0 50 48.51 0 50 0 91.5 75- 124 0 92.8 76- 125 0 97.8 80-120 0 88.3 80- 119 0 97.0 81 - 118 MS Client ID: Analyte Sample ID: HS19060030-06MS Units: ug/Kg Analysis Date: 12.Jun-2019 00:20 Run ID: VOA8~340284 SeqNo:5117426 PrepDate: DF: 1000 Result SPK Ref Control RPD Ref RPD PQL SPKVal Value %REC Limit Value %RPD Limit Qual Benzene Surr: 1, 2-Dich!oroethane-d4 Surr: 4-Bromof/uorobenzene Surr: Dibromotluoromethane Surr: Toluene-dB 113000 38100 40110 36690 42180 4200 0 0 0 0 42500 42500 42500 42500 42500 69320 0 0 0 0 103 70 -130 89,6 70-126 94.4 70 130 86.3 70-130 99.3 70-130 Page 14 of27 HFNA-000003506 EPA Inspection Report - Page 1957 of 1969 AlS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19060423 Date: 20-Jun-19 QC BATCH REPORT Batch ID: R340284 { 0 ) lnstrument VOAS Method: VOLATILE:$ BY SW8260C MSD Client ID: Analyte Sample ID: HS19060030-06MSD Run ID: Result Units: VOA8_340284 PQL SPKVal ug/Kg Analysis Date: 12-Jun-2019 00:45 SeqNo: 5117427 PrepDate: DF: 1000 SPK Ref Value %REC Control Limit RPD Ref RPD Value %RPO Limit Qual Benzene Surr: 1, 2-Dich/oraethane-d4 Surr: 4-Bromof/uorobenzene Surr: Dibromof/uoromethane Surr: Toluene-dB 116700 40750 43070 38830 43940 4200 0 0 0 0 The following samples were analyzed in thls hatch: ps19060423-0l 42500 42500 69320 112 70 130 '""""""---"~'"" 0 95.9 70 - 126 113000 38100 3.27 30 6.73 30 42500 42500 0 101 70- 130 0 91.4 70-130 40110 Jiiaso 7.12 30 5.67 30 42500 0 103 70- 130 42180 4.08 30 HS19060423-03 --~--------------~ Page 15 of27 HFNA-000003507 EPA Inspection Report - Page 1958 of 1969 ALS Houston, I.JS Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19060423 Date: 20-Jun-19 QC BATCH REPORT Batch ID: R.340490 ( 0 ) Instrument: Method: VOLATILES SW8260C MBLK Client ID: Analyte Sample ID: VBLKW-190613 Units: ug/L Analysis Date: 13.Jun-2019 23:48 Run ID: VOA.9_340490 SeqNo: 5122208 PrepDa!e: DF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPD Ref RPD Value %RPD Limit Qual Benzene Surr: 1,2-Dichforoethane-d4 Surr: 4-Bromof!uorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 """""""'~"" 48.22 5.0 0 47.32 0 49.54 0 50.27 0 50 o 50 0 50 0 50 0 96.4 70- 130 94.6 82- 115 99.1 73- 126 101 81 - 120 LCS Client ID: Analyte Sample ID: VLCSW-190613 Units: ug/L Analysis Date: 13.Jun-2019 22:58 Run ID: VOA9_340490 SeqNo: 5122207 PrepDate: DF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPD Ref RPO Value %RPO Limit Qual Benzene 1,2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene """'""""""'--~ Surr: Dibromof!uoromethane Surr: Toluene-dB 19.34 5.0 46.43 0 48.58 0 50.69 0 49.2 0 20 0 96.7 74 - 120 50 0 97.2 82 115 50 o 101 73-126 50 0 98.4 81 120 MS Client ID: Analyte Sample ID: HS19060352-01MS Units: ug/l Analysis Date: 14-Jun-2019 01:02 Run ID: VOA.9_340490 SeqNo: 5122211 PrepDate: DF: 500 Result PQL SPKVal SPK Ref Value %REC Control Limit RPO Ref RPD Value %RPD Limit Qual Benzene sui,:t:2=oichioroeThane~d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 47560 23820 24480 25650 25090 2500 10000 0 25000 0 25000 0 25000 0 25000 """""""""""""'"~- 35900 117 70 127 ........................................................ ,,,,,,,,,,,,,,,,,,,,, .. " ' " ' - - - " " 0 95.3 70-126 0 97.9 82- 124 0 103 77-123 0 100 82- 127 Page 16 of27 HFNA-000003508 EPA Inspection Report - Page 1959 of 1969 AUS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling {EOL) HS19060423 Date: 20-Jun-19 QC BATCH REPORT Instrument: Method: VOLATILES SW8260C MSD Client ID: Analyte Sample ID: HS19060352-01MSD Run ID: Units: VOA9_340490 Result PQL .................................... ~~~~~~~~~~~~~ SPKVal ug/L Analysis Date: 14.Jun-2019 01:27 SeqNo:5122212 SPK Ref Value %REC PrepDate: Control Limit DF: 500 RPD Ref RPD Value %RPD Limit Qual Benzene Surr: 1, 2-Dich!oroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 43240 23930 23720 25310 24390 2500 {) 0 {) 0 The following samples were analyzed in this batch; :HS19060423-04 10000 35900 73.4 70 - 127 47560 9.51 20 250{)0 {) 95] 70 -126 23820 0.442 20 25000 0 94.9 82 - 124 24480 3.16 20 25000 0 101 77 - 123 25650 1.33 20 25000 0 97.6 82-127 25090 2.85 20 -~~=1=~~~423-05 -- -HS19060423-06 - ........................................................................ --1 Page 17 of27 HFNA-000003509 EPA Inspection Report - Page 1960 of 1969 A.LS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19060423 Date: 20-Jun-19 QC BATCH REPORT Batch 10: R.340496 { 0 ) Instrument: VOAS Method: VOLATILES - SWS260C: MBLK Client ID: Analyte Sample ID: VBLKW-190613 Units: ug/L Analysis Date: 13..Ji.m-201911:20 Run ID: VOA.6_340496 SeqNo:5122301 PrepDate: DF: 1 Result SPK Ref Control RPD Ref RPD PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene surr.:f2=b1ch1oroethane~d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB < 0.60 5.0 51.79 0 50 52.14 0 50 49.75 0 50 53.84 0 50 0 104 70- 130 0 104 82- 115 0 99.5 73- 126 0 108 81- 120 LCS Client ID: Analyte Sample ID: VLC:SW-190613 Units: ug/L Analysis Date: 13.Jun-201910:31 Run ID: VOA6_340496 SeqNo: 5122300 PrepDate: DF: 1 Result SPK Ref Control RPD Ref RPD PQL SPKVal Value %REC Limit Value %RPO Limit Qual Benzene '''''"""""'~"'-'" '""'"""~ Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene su,,.:oiii,omoiluo,ameiiiane Surr: Toluene-dB 22.06 5.0 20 54.14 0 50 51.65 0 50 54.16 0 50 44.72 0 50 0 110 74 -120 0 108 70- 130 0 103 82 - 115 0 108 73 - 126 0 89.4 81 - 120 MS Client ID: Analyte Sample ID: HS19060512-01 MS Units: ug/L Analysis Date: 13.Jun-201913:44 Run ID: VOA6_340496 SeqNo: 5122307 PrepDate: OF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPD Ref RPO Value %RPD Limit Qual Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 17.99 5.0 20 52.63 0 50 53.28 0 50 50.85 0 50 52.89 0 50 0 90.0 70-127 ''''''''''''''''''''''''''''''''""""'""~------ 0 105 70- 126 0 107 82- 124 0 102 77 - 123 0 106 82- 127 R.!GHT Page 18 of27 HFNA-000003510 EPA Inspection Report - Page 1961 of 1969 AlS Houston, IJS Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling {EOL) HS19060423 Dale: 20-Jun-19 QC BATCH REPORT Batch II); R340496 { 0 ) Instrument: VOA& Method: VOLATILES SWS2SOC MSD Client ID: Analyte Sample ID: HS19060512.01MSD Units: ug!L Analysis Date: 13-Jun-201914:08 Run ID: VOA.6_340496 SeqNo: 5122308 PrepDate: DF: 1 Result SPK Ref Control RPD Ref RPD PQL SPKVal Value %REC Limit Value %RPO Limit Qua! Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-d8 18.13 5.0 20 51.82 0 50 52.15 0 50 50.74 0 50 52.35 0 50 The following samples were imalyzed in this batch: ~tS19060423-08 L,-----------ssss--nn...,nn 0 90.6 70 -127 17.99 0.73 20 ................. ?}ii; 0 104 70- 126 1.54 20 0 104 82- 124 53.28 2.16 20 0 101 77 - 123 50.85 0.221 20 0 105 82- 127 52.89 1.03 20 ............................. 'cccccccccc-------- Page 19 of27 HFNA-000003511 EPA Inspection Report - Page 1962 of 1969 ALS Houston, US Client: Project: Work:Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19060423 Date: 20-.Jun-19 QC BATCH REPORT Batch ID: R340871 { 0) Instrument: Method: VOLATILES SW8280C MBLK Client ID: Analyte Sample ID: VBLKV\f.190619 Units: ug/L Analysis Date: 19-Jun-2019 13:51 Run ID: VOA9_34087'1 SeqNo: 5131259 PrepDate: DF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPD Ref RPO Value %RPO Limit Qual Benzene < 0.60 5.0 Surr: 1, 2-Dich/oroethane-d4 44.62 0 50 Surr: 4-Bromofluorobenzene 46.99 0 50 ''''''''''""""""""""""""""~,------- Surr: Dibromofluoromethane 47.95 0 50 Surr: Toluene-dB 50.54 0 50 '''"""""""""""-----"" 0 8fi_2 70- 130 0 94.0 82- 115 0 95.9 73- 126 0 101 81 - 120 lCS Client ID: Analyte Sample ID: VlCSW-190619 Units: ug/1. Analysis Date: 19-Jun-2019 13:01 Run ID: VOA9_340S71 SeqNo:5131258 PrepOate: DF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPO Ref RPO Value %RPO Limit Qual Benzene surr:1,2~bichioroethane~d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 18.01 5.0 20 43.39 0 50 49.35 0 50 49.22 0 50 51.8 0 50 0 90.1 74 - 120 0 86.8 70 - 130 0 98.7 82 - 115 ................,"""'.. """""--------~ 0 98.4 73- 126 0 104 81 - 120 MS Client ID: Analyte Sample ID: HS19060847-01MS Units: ug/L Analysis Date: 19-Jun-2019 15:05 Run ID: VOA.9_340871 SeqNo: 5131261 PrepDate: OF: 1 Result PQL SPKVal SPK Ref Value %REC Control Limit RPD Ref RPO Value %RPO Limit Qual Benzene Surr: 1, 2-Dichforoethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromof/uoromethane Surr: Toluene-dB 22.46 5.0 20 43.58 0 50 48.41 0 50 51.75 0 50 0 112 70 - 127 0 87.2 70- 126 0 96.8 82- 124 77-123 0 104 82 - 127 Page 20 of27 HFNA-000003512 EPA Inspection Report - Page 1963 of 1969 AlS Houston, US Client: Project: WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19060423 Date: 20-Jun-19 QC BATCH REPORT Batch ID: R.340871 ( 0 ) Instrument: Method: VOLATILES SW8260C MSD Client ID: Analyte Sample ID: " HS19060S47-01MSD Run ID: Result ..................... ~~~~~ Units: VOA9_340S71 PQL SPKVal ug/L Analysis Date: 19.Jun-201915:30 SeqNo: 5131262 PrepDate: DF: 1 SPKRef Value %REC Control Limit RPD Ref RPD Value %RPD Limit Qual Benzene Surr: 1, 2-Dichloroethane-d4 Surr: 4-Bromofluorobenzene Surr: Dibromofluoromethane Surr: Toluene-dB 19.95 44.56 47.62 48.61 50.17 5.0 20 ""~---- 0 50 0 50 0 50 0 50 0 99.7 70 - 127 0 89.1 70 - 126 0 95.2 82- 124 0 97.2 f1~123 0 100 82- 127 22.46 :fsa 48.41 48.93 51.75 11.9 20 2.22 20 1.64 20 0.652 20 3.11 20 The following samples were analyzed in this batch: /tS19060423-02 HS19060423-07 ssss----1, Page 21 of27 HFNA-000003513 EPA Inspection Report - Page 1964 of 1969 .AlS Houston, !JS Client: Project WorkOrder: Navajo Refining Company BWON Monthly Sampling (EOL) HS19060423 Date: 20-Jun-19 QUALIFIERS, .ACRONYMS, UNITS Qualifier a B E H j M n ND 0 p R s u Descriptio1_1 Value exceeds Regulatory Limit Not accredited Analyte detected in the associated Method Blank above the Reporting Limit Value above quanlitation range Analyzed outside of Holding Time Analyte detected below quantitation limit Manually integrated, see raw data for justification Not offered for accreditation Not Detected at the Reporting Limit Sample amount is > 4 times amount spiked Dual Column results percent difference > 40% RPD above laboratory control limit Spike Recovery outside laboratory control limits Analyzed but not detected above the MDUSDL ~1::.r.?.~Y.~ DCS DUP LCS LCSD MBLK MDL MQL MS MSD PDS PQL so SDL TRRP ........Descripfton Detectability Check Study Method Duplicate Laboratory Control Sample Laboratory Control Sample Duplicate Method Blank Method Detection Limit Method Quantitation Limit Matrix Spike Matrix Spike Duplicate Post Digestion Spike Practical Quantitaion Limit Serial Dilution Sample Detection Limit Texas Risk Reduction Program !Jnit Report~~ .......Descri.ption_ mg/Kg Milligrams per Kilogram mg/L Milligrams per Liter Page 22 of27 HFNA-000003514 EPA Inspection Report - Page 1965 of 1969 AlS Houston, US Agency Arkansas Dept of Defense Illinois Kansas Louisiana Maryland North Carolina Oklahoma Date: 20-Jun-19 CERTIFICATIONS,ACCREDiiATIONS & LICENSES Number 19-028-0 343, 2018-2019 624-2019 Expire Date 27-Mar-2020 20-Dec-2021 29-Jun-2019 31-Jul-2019 30-Jun-2019 30-Jun-2019 31-Dec-2019 Page 23 of 27 HFNA-000003515 EPA Inspection Report - Page 1966 of 1969 AlS Houston, US Client: Project: Work Order: Navajo Refining Company BWON Monthly Sampling (EOL) HS19060423 Lab Samp ID HS19060423-01 HS 19060423-02 HS 19060423-03 HS 19060423-04 HS19060423-05 HS 19060423-06 HS 19060423-07 HS 19060423-08 Client Sample ID S-1 (API HC) S-3 (API Water) S-5 (T-40) Field Blank EQ Blank Port 1 EQ Blank Port 2 Duplicate Trip Blank Action Login Login Login Login Login Login Login Login Date 08/06/2019 15:04:48 08/06/2019 15:04:48 08/06/2019 15:04:48 08/06/2019 15:04:48 08/06/2019 15:04:48 08/06/2019 15:04:48 08/06/2019 15:04:48 08/06/2019 15:04:48 Date: 20-jun-19 SAMPLE TRACKING Person PMG PMG PMG PMG PMG PMG PMG PMG New Location VOA254 VOA254 VOA254 VOA254 VOA254 VOA254 VOA254 VOA254 Page 24 of27 WWW HFNA-000003516 EPA Inspection Report - Page 1967 of 1969 AlS Houston, US Client Name: Work Order: Navajo Refining HS19060423 Date/Time Received: Received by: Date: 20-Jun-19 Sample Receipt Checklist Q7-Jun-20t~Jli;.ll!l NDR Checklist completed by: Paresh }vf Giga es,griature" " Matrices: 8-Jun-2019 -i Date Reviewed by: Carrier name: Corer Grandits 10-Jun-2019 eSign.ature.,;,,,,;,;,,,,.;;,___ _ _ __.:.:::.__: Date Shipping container/cooler in good condition? Custody seals intact on shipping container/cooler? Custody seals intact on sample bottles? VOA/TX1005/TX1006 Solids in hermetically sealed vials? Chain of custody present? Chain of custody signed when relinquished and received? Samplers name present on COC? Chain of custody agrees with sample labels? Samples in proper container/bottle? Sample containers intact? Sufficient sample volume for indicated test? All samples received within holding time? Containerrremp Blank temperature in compliance? T e m p e r a t u r e ( s)!Thermome!er(s ): C o o l e r ( s )/Kit(s ): Dateffime sample(s) sent to storage: Water - VOA vials have zero headspace? Water - pH acceptable upon receipt? pH adjusted? pH adjusted by: Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes f;;]::..................::: r............ll~~..............~. e:..................:.:: f'...........1. ..._,._.....-...) [;;) :-.................:.:: f;.?l::..................::: h.~il,, ::..................~. ;;: ~"~~ t~~*1l::........................::: ~41::.................-::: f;?l~.................:.:: No L......J No Cl Not Present Not Present Not Present Not Present i Page(s) COC 1Ds:none ~----------~ .5c U/c azmatPak 7/19 20:00 ' ~...~. :-...~. ~::: Yes hff~ ~...................:.:: ~-fl Yes :;......................:;: Yes No VOA vials submitted N/A NIA 1""'1 L...~. ~J Login Notes: Client Contacted: Contacted By: Date Contacted: Regarding: Person Contacted: Comments: Corrective Action: Page 25 of27 HFNA-000003517 EPA Inspection Report - Page 1968 of 1969 ::::I::::::~:::::::::::::::1r.l.#~~~~~:1~r~!t~~~::::: ::::<:f(~!$~5ij .. ;;;f\;;t;~;.:~~~:: Navajo Refining Company LLC ~~~tii~ ;11 ~~~ Tyler Turner Gabl Comoo P.O~~ 159 BWiiliiiiilll _c:,, Chain of Custody Form HS19060423 y,UT ?70() I Page of _L_ Navajo Rennin~ Company 'A1!103 ;zaa . .. . me~~~~~~;~;~;;::~;~;~~~~:rw1-1~~~:t:~f.:M~Jy~1.$:::::::_:;:::):?::;::::: :i): ~AF,;,,:. . ... : . : .. :.; ! _ ............ .. :l?.:1 . : : : : : : ::::: :01 ,'., ~ :""'..'""'.. -'-..'""'.""::c:.:c..:::..:.:-'"':::.;.:""'::. .: , . . , : : - ~ - ){ 501 tast Main ~ .t 1;1a;~~ ....... ~-~~~ntte,.- /?\}~(.~r~~~~Artesia,NM88211-0159 :t: -:ti -.------------+~----.---. 1 t:~;~~:~~-~#~~ > <j !!:~t ;;f;'~ /:f: r-3 (API Water) :t~~:~~l:i::,~;::k-..-....-.:. :::________ {~} EQ Blank Port _1 .-~-,....:::<.;-<-,: tL. i 06/06119 :,~tf[, 1:~1 L--------,.._.;.,. :::::;;:::: EQ Blank Port 2 ...~;'~>'' ~---w--------- /ft ) ( } Du~_li~~-te--------- Trip~!~~~-------- 06/06119 1 l )( 2 : )( .............- - j - - - - 1 1 :)( Temperature Blank ,ftt~fN7tr:ins~=:i: ~~:!~:::~:~:~~:~:'.:::1::::::::::~::;:~ 00!her _ _ _ 0 2 Wk Day.; 0 24 Houri P-Chec!dist I /!LP (( c!'~i-9: I "Tl z N0:m, A11y cn~n~ltl rmtM oo nMt'k In writing once Hmp!es and cqc row have been submittlild to AUi laboratory Group. :r- 0 0 0 0 Page 26 of27 0 (,) :o,:right 2~0-9 by. ALS laboratory Group .0...1.. OJ EPA Inspection Report - Page 1969 of 1969 IJ "fthl..y<tem """stltute, yowrogreom,,otto tho ,enrice """dltlon, '" tho omront fedfxSeNIOO G"lde, ovollobl "" fodei<.eam. fedE wlll not be respon,lbl for ony dolm in'""""" o! $100 per pa<lmlJ'!, whether the ,e,ult of I=, dorMge, delay, non-<lellw,y, mi<dellwry, <>r '(,liloformotlon, ""!"" you deolare hlghor,mlue, pay on addltlonol ,hOl&Q, de<Ymoot youractuol lo,. and file tlmolyclolm. Limimtlooo fuuod lo the curront fodlo S<>rvlC<! Gldo apply. Your riaht to "'""""<from fod[<for ony looo, lnoludins iet1io,ic volue afthe pckogo, le,o of ..,I.,., Income !o!ere:st, pn:rl'lt, attorney.. foos, rom, ond othorform> of domoge wheth<>r dlMct, incidental, tOM'"'!Uentlol, '" ,pecli I limited !<>the greoterof $100 artho ""thartrnd cl,ed.sred val!.sG, R:eco~ry i:am,ot 'l'!Keeed actual documem:isd fa&$. MMmum fur ltenu of mct:rnordina.rv v&IBJ~ l:-t :$~0001 e.g. - ~ . pi esduu!S tiiebds, itegot!iible frnst1 uments and other tnmm"i!~d~fa1iaute:-Wt1tt~11cts1m~ntnrsttfeift~-iW- within mlct time llmlts, ... current FedE<SaF11IW Guida. A-twr prlnWl; thi~ ~be!: CONSKlN!!E CO?V - Pi.U,31! PLACE IN FRONT OF ~OUCI! 1. Fold ~ll't limQct p;sg~ &1on9 fu111a ht.'tl'Uorc1.2!lt !!Ne. ~t !!l!ei~e ~b*J ire ihip:pll'lg pm.,eh Md ITTfu: ie- tt, )'l:llta' ~fpmtria. ".J ! 0 m 0 ~ ...j!.... I 0 !l!llll!llf ~~ - i2j:i:ij O \ 1.!,r; ~,. ".::::c 00 _,. > 81 ~iii """ ~o c: 2 r ll.l~ """, ~c:::::ju,WAI~ !!!!!!'I :.1:m me m !!lli = "'a~~ -< wj!i le!i! z o > Q is ...,, -I :z: ~ :!!!!i X O Z =:: ~ ~ 2 ;;..i---o*--,,-~- ,,__ ~!---.%......... J! i0 'Tl 0 ~ ij~; ;;ti 2!,!j ! ,, ~i :::::i l ~ -"f(l 1;i -< !El! i I .. ~ m~ ct..:.l _-......i. ;:a z z .... , )::i-0 :r.,, Q ~! :c~ Cl 0 ::c <::ii -I>: I ~ S51C11ll21Dllll4C "Tl z :r- 0 0 0 0 Page 27 of 27 0 (,) .0...1.. (!)