Document e7vB8K7yL6KMRX4oGaQeJVyMe

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>/^dK&WWE/^ &>/ZsZ>Z /Z&ZZ/ZZZZZ dYEZZ^WZZE'W^ dY&Z dYEZZ^W dW Newberry Gas Plant /Enterprise Midland Basin Midstream LLC Inspection Date 12/19/2024 Appendix A FLIR Video Log UNITED STATES ENVIRONMENTAL PROTECTION AGENCY FLIR Video Log Location: Newberry Gas Plant /Enterprise Midland Basin Midstream LLC City: Midland Midland County Video File Name: Date of Video: Time of Video: Videographer: Description: FLIR Video 271 12/19/2024 12:28 PM Schath Flares State: TX Appendix A Video File Name: Date of Video: Time of Video: Videographer: Description: FLIR Video 272 12/19/2024 12:34 pm Schath Flares Video File Name: Date of Video: Time of Video: Videographer: FLIR Video 273 12/19/2024 12:35 pm Schath Video File Name: Date of Video: Time of Video: Videographer: Description: FLIR Video 274 12/19/2024 12:44 pm Schath Tanks Video File Name: Date of Video: Time of Video: Videographer: Description: FLIR Video 275 12/19/2024 12:46 pm Schath Tanks Page 2 of 4 UNITED STATES ENVIRONMENTAL PROTECTION AGENCY FLIR Video Log Location: Newberry Gas Plant /Enterprise Midland Basin Midstream LLC City: Midland Midland County Video File Name: Date of Video: Time of Video: Videographer: Description: FLIR Video 276 12/19/2024 12:57pm Schath Tank State: TX Appendix A Video File Name: Date of Video: Time of Video: Videographer: Description: FLIR Video 277 12/19/2024 1:00 pm Schath Tanks Video File Name: Date of Video: Time of Video: Videographer: Description: FLIR Video 278 12/19/2024 1:06 pm Schath Tanks Video File Name: Date of Video: Time of Video: Videographer: Description: FLIR Video 279 12/19/2024 1:08 pm Schath Tanks Video File Name: Date of Video: Time of Video: Videographer: Description: FLIR Video 280 12/19/2024 1:10 pm Schath Carbon Bed Page 3 of 4 UNITED STATES ENVIRONMENTAL PROTECTION AGENCY FLIR Video Log Location: Newberry Gas Plant /Enterprise Midland Basin Midstream LLC City: Midland Midland County Video File Name: Date of Video: Time of Video: Videographer: Description: FLIR Video 281 12/19/2024 1:19 pm Schath Tank State: TX Appendix A Video File Name: Date of Video: Time of Video: Videographer: Description: FLIR Video 282 12/19/2024 1:21 pm Schath Loading Operations Video File Name: Date of Video: Time of Video: Videographer: Description: FLIR Video 283 12/19/2024 1:24 pm Schath Loading Operations Video File Name: Date of Video: Time of Video: Videographer: Description: FLIR Video 284 12/19/2024 2:00 pm Schath Carbon Beds Video File Name: Date of Video: Time of Video: Videographer: Description: FLIR Video 285 12/19/2024 2:06 pm Schath Tank Page 4 of 4 Newberry Gas Plant /Enterprise Midland Basin Midstream LLC Inspection Date 12/19/2024 Appendix B Inspection Follow-up Information Request Responses From: To: Subject: Date: Foley, Patrick Spina, Providence; Johnstone, Lauren FW: Enterprise Products Partners Inspection Follow-up Monday, March 17, 2025 2:59:54 PM From: Fields, Jon <JEFIELDS@eprod.com> Sent: Monday, March 17, 2025 3:27 PM To: Foley, Patrick <Foley.Patrick@epa.gov> Subject: RE: Enterprise Products Partners Inspection Follow-up ICaution: This email originated from outside EPA, please exercise additional caution when deciding whether to open attachments or click on provided links. Patrick, Enterprise is submitting information related to EPAs data request from 3/3/2025 for the Newberry Gas Plant. A Syncplicity link was submitted to you to access our responses. This is a partial response. Enterprise is working diligently gathering the remainder of the information and is targeting completion by 3/31/2025. The narrative below memorializes the questions for which Enterprise is providing data today: 1. Provide a digital plot plan for the facility that identies major pieces of equipment, process units, and emission points. Enterprise response to item 1: Please refer to the permit documents included in the file "Response 1, 2, and 3" that we have included with this response. 2. Provide a Block Flow Diagram (BFD) for the plant as a whole that shows how gas and liquids enter the facility, are processed in each of the process units, and then exit the facility. Enterprise response to item 2: Please refer to the permit documents included in the file "Response 1, 2, and 3" that we have included with this response. 3. Process Flow Diagrams (PFDs) for each process unit in the facility. Enterprise response to item 3: Please refer to the permit documents included in the file "Response 1, 2, and 3" that we have included with this response. 6. Identify the manufacturer and model number of the are tip installed on each are. Enterprise response to item 6: Please refer to the documents included in the file "Response 6" that we have included with this response. This response contains information marked as Confidential Business Information. 9. Provide the design capacity in long tons per day (LT/D) of hydrogen sulde (H2S) in the acid gas, expressed as sulfur, for each sweetening unit. Provide supporting design documents and explain all assumptions made to support the design basis. Enterprise response to item 9: Please refer to the documents included in the file "Response 9" that we have included with this response. 11. Provide the date that the carbon bed system in use on December 19, 2024, installed in an effort to control VOC emissions from Tank 2350B was rst installed. Provide all documents available on the ordering, acquisition, purchase, or rental of that system, including time of delivery and installation and any basis for sizing of the system. Provide carbon bed maintenance records, including manufacture specications and replacement records for the carbon. Provide an estimate of the pressure drop through the system from the inlet to the exible hose on the roof of the tank through the exit of the second carbon bed. Enterprise response to item 11: Please refer to the documents included in the file "Response 11" that we have included with this response. 17. For Tanks 235A and 235B and the Slop Tank, for each day from July 1 to December 31, 2024, provide: a. Whether condensate, oil, slop oil or produced water, was added to, or removed from the tank, with an estimate of the amount of each added or removed; and b. Average volume of condensate, oil, slop oil, or produced water in each tank. Enterprise response to item 17: Please refer to the documents included in the file "Response 17" that we have included with this response. 18. For tanks 235A and 235B and the Slop Tank, describe how vapors from the tank vent are controlled. If combusted, identify all points of possible combustion. Enterprise response to item 18: Please refer to the documents included in the file "Response 18" that we have included with this response. 21. For Tanks 235A and 235B and the Slop Tank, provide copies of audio, visual or olfactory inspections, recorded les for all optical gas imaging taken of the roof ttings and records of PID or FID measurements taken from July 1, 2024, to date. Enterprise response to item 21: Please refer to the documents included in the file "Response 21" that we have included with this response. 22. Describe any repairs made from December 19, 2024, to date, on the manways and pressure relief devices on Tanks 235A and 235B and the Slop Tank. State whether the roof ttings were monitored with optical gas imaging, PID or FID after the repairs, and point to the monitoring results undertaken after the repairs provided in response to 21 above. Enterprise response to item 22: Please refer to the documents included in the file "Response 22" that we have included with this response. Please let me know if you have any problems getting the Syncplicity file or any other questions related to this matter. Thank you, Jon E. Fields | Director, Field Environmental Enterprise Products Operating LLC 1100 Louisiana St., Houston, Tx 77002-5227 (713) 381-6684 office | (832) 596-7176 cell | jefields@eprod.com From: Foley, Patrick <Foley.Patrick@epa.gov> Sent: Monday, March 3, 2025 1:27 PM To: Fields, Jon <JEFIELDS@eprod.com> Subject: [EXTERNAL] Enterprise Products Partners Inspection Follow-up [Use caution with links/attachments] Hi Jon, I hope you are well. As you know we inspected the Enterprise Newberry Gas Plant on December 19, 2024. During the inspection we requested documents that the facility staff were unable to produce while we were on-site and they asked we request these documents later by email. In drafting the inspection report, we identified further documents we also need to complete the inspection report and to provide you with more complete feedback on inspection findings and compliance status. As requested by the facility staff, attached are those inspection related document requests. Please provide these documents in electronic format either by email, or in a link such as an ftp link, from which we may download them, in two weeks. If you need additional time for any specific request, we can discuss. Also, if you need an ftp site to which you can upload responses, please let us know. We can provide one. Also, below, please find an ftp link to download the optical gas imaging video files we recorded at your site with an Excel spreadsheet index of the files, and an Excel sheet of Mantis Lite data we recorded in observing your flares. Please let us know if you have any issues with downloading or opening these files. It is our intention to include all of these files as attachments to the inspection report: My contact information is below. Please reply to this email to confirm receipt. If you have any questions, please do not hesitate to reach out to me by email or my cell phone if you have any questions. I look forward to hearing from you. Patrick W. Foley Senior Environmental Engineer Air Enforcement Division Office of Civil Enforcement United States Environmental Protection Agency Cell 240-308-2721 This message (including any attachments) is confidential and intended for a specific individual and purpose. If you are not the intended recipient, please notify the sender immediately and delete this message. From: To: Cc: Subject: Date: Fields, Jon Foley, Patrick Craft, Zachary; Jacobson, Tucker Enterprise Products Partners Inspection Follow-up: 4/4/2025 Friday, April 4, 2025 9:18:53 AM I Caution: This email originated from outside EPA, please exercise additional caution when deciding whether to open attachments or click on provided links. Patrick, Enterprise is submitting information related to EPAs data request from 3/3/2025 for the Newberry Gas Plant. A Syncplicity link was submitted to you to access our responses. This is the second batch of information. A partial initial response was sent you on 3/17/2025. The narrative below memorializes the questions for which Enterprise is providing data today: 4. Provide a simplied map of the are header system for each are that shows where each gas stream from process units enter the header, where supplemental gas can be supplied, where samples are taken, and each monitoring point for ow, temperature and pressure. Enterprise Response to Item 4: Please refer to the documents included in the file "Response 4 and 5" that we have included with this response. This response contains information marked as Confidential Business Information. 5. Provide the Piping and Instrumentation Diagrams (P&IDs) for each are and are header system serving each are. Enterprise Response to Item 5: Please refer to the documents included in the file "Response 4 and 5" that we have included with this response. This response contains information marked as Confidential Business Information. 7. Provide an hourly average ow rate for gas sent to each are for the time period from July 1, 2024, to December 31, 2024. Indicate whether the ow rate is directly measured or estimated from process parameters and provide the method of estimation. For ow measurements and process parameters used to estimate ow, indicate the location of measurement in reference to the simplied map requested in 4 above. Enterprise Response to Item 7: Enterprise does not have a regulatory requirement to continuously monitor flare flow data. Therefore, no information responsive to this request are being provided. 8. Provide copies of all sampling data measuring the heating value, concentration of any individual component or overall composition of gas sent to each are for samples taken from July 1, 2024, to December 31, 2024. If fewer than 5 samples were taken in this time period, for a particular gas stream, provide copies of the last 5 samples. For each sample indicate where the sample was taken in reference to the simplied map requested in 4 above. Enterprise Response to Item 8: Please refer to the documents included in the file "Response 8" that we have included with this response. 10. Provide a narrative history of all oating roof failures (full or partial sinking) or malfunctions (physical seal problems, liquid layer on roof from inadequate seal, etc.) for Tanks 2350A and 2350B since original construction in or around 2015 to date. For each failure or malfunction, describe the cause, the date it was detected, how it was detected, how emissions were minimized during the event, and how and when the failure or malfunction was corrected. Enterprise Response to Item 10: Please refer to the documents included in the file "Response 10" that we have included with this response. 12. Provide copies of records of all audio, visual or olfactory inspections, and recorded les for all optical gas imaging taken of the roof vents for Tanks 2350A and 2350B and the vent hose and carbon beds installed on Tank 2350B from July 1, 2024 to date. Enterprise Response to Item 12: Please refer to the documents included in the file "Response 12" that we have included with this response. 13. Provide copies of records of all PID or FID measurements taken of the perimeter vents from July 1, 2024, to date, and vent hose and carbon beds since installation in or about November 2024 to date. Enterprise Response to Item 13: Please refer to the documents included in the file "Response 13" that we have included with this response. 14. Provide a narrative description of how the perimeter vents on Tank 2350B were sealed when the carbon bed system was installed in or around November 2024. Provide any photos of the seals that were taken. Enterprise Response to Item 14: Please refer to the documents included in the file "Response 14" that we have included with this response. 15. Provide an estimate of VOC emissions in pounds per day, from Tanks 2350A and 2350B for each day from the date of roof failure until the tank was emptied or until the carbon bed system was installed. Include a detailed description of the methodology for that estimate including all assumptions. Enterprise Response to Item 15: Please refer to the documents included in the file "Response 15" that we have included with this response. 16. Describe any repairs made from December 19, 2024, to date, of the taped seals on the perimeter vents on Tank 2350B that had been observed leaking during the inspection. State whether the perimeter vents were monitored with optical gas imaging, PID or FID after the repairs, and point to the monitoring results provided in response to 12 and 13 above. Enterprise Response to Item 16 Please refer to the documents included in the file "Response 16" that we have included with this response. 19. For Tanks 235A and 235B and the Slop Tank, provide closed vent system design documentation that demonstrates capability to collect all VOC vapor gases discharged from the storage vessels. Provide the pressure settings for all relief valves and thief hatches and the design pressure each tank can safely withstand in ounces per square inch. Enterprise Response to Item 19: Please refer to the documents included in the file "Response 19" that we have included with this response. 20. For Tanks 235A and 235B and the Slop Tank, provide the uncontrolled potential to emit calculations for the storage tank and the level of control as a percentage, provided by control device. Enterprise Response to Item 20: Please refer to the permit documents included in the file "Response 1, 2, and 3" that were included in the initial response. Please let me know if you have any problems getting the Syncplicity file or any other questions related to this matter. Thank you, Jon E. Fields | Director, Field Environmental Enterprise Products Operating LLC 1100 Louisiana St., Houston, Tx 77002-5227 (713) 381-6684 office | (832) 596-7176 cell | jefields@eprod.com This message (including any attachments) is confidential and intended for a specific individual and purpose. If you are not the intended recipient, please notify the sender immediately and delete this message. From: To: Cc: Subject: Date: Fields, Jon Foley, Patrick Craft, Zachary; Jacobson, Tucker RE: Enterprise Products Partners Inspection Follow-up: 4/4/2025 Thursday, April 17, 2025 11:09:24 AM I Caution: This email originated from outside EPA, please exercise additional caution when deciding whether to open attachments or click on provided links. Patrick, We have gathered the requested flare flow data. We are reviewing the meter spec data with our measurement team and will respond to your request by COB April 24. Thank you, Jon E. Fields | Director, Field Environmental Enterprise Products Operating LLC 1100 Louisiana St., Houston, Tx 77002-5227 (713) 381-6684 office | (832) 596-7176 cell | jefields@eprod.com From: Foley, Patrick <Foley.Patrick@epa.gov> Sent: Tuesday, April 15, 2025 7:13 AM To: Fields, Jon <JEFIELDS@eprod.com> Cc: Craft, Zachary <zlcraft@eprod.com>; Jacobson, Tucker <WTJACOBSON@eprod.com> Subject: [EXTERNAL] RE: Enterprise Products Partners Inspection Follow-up: 4/4/2025 [Use caution with links/attachments] Jon, Understood. You mention data from a mass flow meter in your April 9 message. Some mass flow meters measure volumetric flow and either assume a MW or density or measure density and then calculate mass flow. Others approximate mass flow by using thermal loss or Coriolis principles. It would be most helpful to have the volumetric flow rate, if that is available from the data your meter measures. Do you have an estimate for how long it will take to provide the flow data for the flares? Patrick From: Fields, Jon <JEFIELDS@eprod.com> Sent: Monday, April 14, 2025 12:11 PM To: Foley, Patrick <Foley.Patrick@epa.gov> Cc: Craft, Zachary <zlcraft@eprod.com>; Jacobson, Tucker <WTJACOBSON@eprod.com> Subject: RE: Enterprise Products Partners Inspection Follow-up: 4/4/2025 I Caution: This email originated from outside EPA, please exercise additional caution when deciding whether to open attachments or click on provided links. Patrick, We are gathering flare data and will provide an appropriate response as soon as possible. Jon E. Fields | Director, Field Environmental Enterprise Products Operating LLC 1100 Louisiana St., Houston, Tx 77002-5227 (713) 381-6684 office | (832) 596-7176 cell | jefields@eprod.com From: Foley, Patrick <Foley.Patrick@epa.gov> Sent: Wednesday, April 9, 2025 6:21 AM To: Fields, Jon <JEFIELDS@eprod.com> Cc: Craft, Zachary <zlcraft@eprod.com>; Jacobson, Tucker <WTJACOBSON@eprod.com> Subject: [EXTERNAL] RE: Enterprise Products Partners Inspection Follow-up: 4/4/2025 [Use caution with links/attachments] Jon, EPA is required to consider any credible evidence available to evaluate compliance under the Clean Air Act. We are not constrained to using only monitoring data required by regulation or permit. I do regularly use process monitor data obtained during and in follow-up to an inspection, or if necessary, obtained through a more formal Clean Air Act Section 114 Letter, in reaching conclusions from inspections and any enforcement investigations that follow. Section 114 of the Clean Air Act provides authority to EPA to obtain any information reasonably required to determine compliance during inspections and in follow-up information requests. I intend to use the flow rate data from the monitors to assess compliance with various regulatory and permit requirements that apply to emissions of various pollutants from your flares and your plant as a whole, including, but not limited to VOC and SO2. I will consider the accuracy of the monitors in my assessment. Please provide the data as requested and also provide any information you want me to consider as to the make, model number, maintenance, calibration, and accuracy of the monitors. On Syncplicity, after a few tries, we were able to download it all. It will hopefully work when you also submit the flow rate data I requested for the flares discussed above. I look forward to your response. Patrick From: Fields, Jon <JEFIELDS@eprod.com> Sent: Wednesday, April 9, 2025 6:10 AM To: Foley, Patrick <Foley.Patrick@epa.gov> Cc: Craft, Zachary <zlcraft@eprod.com>; Jacobson, Tucker <WTJACOBSON@eprod.com> Subject: RE: Enterprise Products Partners Inspection Follow-up: 4/4/2025 ICaution: This email originated from outside EPA, please exercise additional caution when deciding whether to open attachments or click on provided links. Patrick, Thank you for the chance to follow up on this subject. Could you help us understand how you would intend to use that data? The mass flow meter is not required for environmental compliance and therefore is not maintained or calibrated per EPA standards, so it is not apparent to us that hourly data from it would be appropriately provided as part of an environmental compliance evaluation. Let us know if the Syncplicity matter gets resolved or if we need to find another avenue for providing the data. Thank you, Jon E. Fields | Director, Field Environmental Enterprise Products Operating LLC 1100 Louisiana St., Houston, Tx 77002-5227 (713) 381-6684 office | (832) 596-7176 cell | jefields@eprod.com From: Foley, Patrick <Foley.Patrick@epa.gov> Sent: Tuesday, April 8, 2025 7:12 AM To: Fields, Jon <JEFIELDS@eprod.com> Cc: Craft, Zachary <zlcraft@eprod.com>; Jacobson, Tucker <WTJACOBSON@eprod.com> Subject: [EXTERNAL] RE: Enterprise Products Partners Inspection Follow-up: 4/4/2025 [Use caution with links/attachments] Jon, We are having some trouble downloading from syncplicity. We are working on it and will get back to you on whether we were successful. I did have a question about your email below. On item 7, it sounds like you have data on flow to the flares, but are unwilling to provide it, because you say you have no regulatory requirement to monitor it. During the inspection I believe I was told you monitor flow to each of these flares. Can you confirm whether you have flow data for the two acid gas flares? If you have the data, please reconsider whether you will provide it. Let me know if you want to discuss this. Pat From: Fields, Jon <JEFIELDS@eprod.com> Sent: Friday, April 4, 2025 10:19 AM To: Foley, Patrick <Foley.Patrick@epa.gov> Cc: Craft, Zachary <zlcraft@eprod.com>; Jacobson, Tucker <WTJACOBSON@eprod.com> Subject: Enterprise Products Partners Inspection Follow-up: 4/4/2025 ICaution: This email originated from outside EPA, please exercise additional caution when deciding whether to open attachments or click on provided links. Patrick, Enterprise is submitting information related to EPAs data request from 3/3/2025 for the Newberry Gas Plant. A Syncplicity link was submitted to you to access our responses. This is the second batch of information. A partial initial response was sent you on 3/17/2025. The narrative below memorializes the questions for which Enterprise is providing data today: 4. Provide a simplied map of the are header system for each are that shows where each gas stream from process units enter the header, where supplemental gas can be supplied, where samples are taken, and each monitoring point for ow, temperature and pressure. Enterprise Response to Item 4: Please refer to the documents included in the file "Response 4 and 5" that we have included with this response. This response contains information marked as Confidential Business Information. 5. Provide the Piping and Instrumentation Diagrams (P&IDs) for each are and are header system serving each are. Enterprise Response to Item 5: Please refer to the documents included in the file "Response 4 and 5" that we have included with this response. This response contains information marked as Confidential Business Information. 7. Provide an hourly average ow rate for gas sent to each are for the time period from July 1, 2024, to December 31, 2024. Indicate whether the ow rate is directly measured or estimated from process parameters and provide the method of estimation. For ow measurements and process parameters used to estimate ow, indicate the location of measurement in reference to the simplied map requested in 4 above. Enterprise Response to Item 7: Enterprise does not have a regulatory requirement to continuously monitor flare flow data. Therefore, no information responsive to this request are being provided. 8. Provide copies of all sampling data measuring the heating value, concentration of any individual component or overall composition of gas sent to each are for samples taken from July 1, 2024, to December 31, 2024. If fewer than 5 samples were taken in this time period, for a particular gas stream, provide copies of the last 5 samples. For each sample indicate where the sample was taken in reference to the simplied map requested in 4 above. Enterprise Response to Item 8: Please refer to the documents included in the file "Response 8" that we have included with this response. 10. Provide a narrative history of all oating roof failures (full or partial sinking) or malfunctions (physical seal problems, liquid layer on roof from inadequate seal, etc.) for Tanks 2350A and 2350B since original construction in or around 2015 to date. For each failure or malfunction, describe the cause, the date it was detected, how it was detected, how emissions were minimized during the event, and how and when the failure or malfunction was corrected. Enterprise Response to Item 10: Please refer to the documents included in the file "Response 10" that we have included with this response. 12. Provide copies of records of all audio, visual or olfactory inspections, and recorded les for all optical gas imaging taken of the roof vents for Tanks 2350A and 2350B and the vent hose and carbon beds installed on Tank 2350B from July 1, 2024 to date. Enterprise Response to Item 12: Please refer to the documents included in the file "Response 12" that we have included with this response. 13. Provide copies of records of all PID or FID measurements taken of the perimeter vents from July 1, 2024, to date, and vent hose and carbon beds since installation in or about November 2024 to date. Enterprise Response to Item 13: Please refer to the documents included in the file "Response 13" that we have included with this response. 14. Provide a narrative description of how the perimeter vents on Tank 2350B were sealed when the carbon bed system was installed in or around November 2024. Provide any photos of the seals that were taken. Enterprise Response to Item 14: Please refer to the documents included in the file "Response 14" that we have included with this response. 15. Provide an estimate of VOC emissions in pounds per day, from Tanks 2350A and 2350B for each day from the date of roof failure until the tank was emptied or until the carbon bed system was installed. Include a detailed description of the methodology for that estimate including all assumptions. Enterprise Response to Item 15: Please refer to the documents included in the file "Response 15" that we have included with this response. 16. Describe any repairs made from December 19, 2024, to date, of the taped seals on the perimeter vents on Tank 2350B that had been observed leaking during the inspection. State whether the perimeter vents were monitored with optical gas imaging, PID or FID after the repairs, and point to the monitoring results provided in response to 12 and 13 above. Enterprise Response to Item 16 Please refer to the documents included in the file "Response 16" that we have included with this response. 19. For Tanks 235A and 235B and the Slop Tank, provide closed vent system design documentation that demonstrates capability to collect all VOC vapor gases discharged from the storage vessels. Provide the pressure settings for all relief valves and thief hatches and the design pressure each tank can safely withstand in ounces per square inch. Enterprise Response to Item 19: Please refer to the documents included in the file "Response 19" that we have included with this response. 20. For Tanks 235A and 235B and the Slop Tank, provide the uncontrolled potential to emit calculations for the storage tank and the level of control as a percentage, provided by control device. Enterprise Response to Item 20: Please refer to the permit documents included in the file "Response 1, 2, and 3" that were included in the initial response. Please let me know if you have any problems getting the Syncplicity file or any other questions related to this matter. Thank you, Jon E. Fields | Director, Field Environmental Enterprise Products Operating LLC 1100 Louisiana St., Houston, Tx 77002-5227 (713) 381-6684 office | (832) 596-7176 cell | jefields@eprod.com This message (including any attachments) is confidential and intended for a specific individual and purpose. If you are not the intended recipient, please notify the sender immediately and delete this message. From: To: Cc: Subject: Date: Attachments: Fields, Jon Foley, Patrick Craft, Zachary; Jacobson, Tucker Newberry Flare Flow Data Wednesday, April 23, 2025 2:39:07 PM Flare Flow Data 07.01.24 to 12.31.24.xlsx I Caution: This email originated from outside EPA, please exercise additional caution when deciding whether to open attachments or click on provided links. Mr. Foley, Enterprise is providing the Newberry Gas Plant flare flow data as requested. The attached spreadsheet contains hourly average flow data over the specified time-period for the four (4) flares at the site. All four flow meters output flow data as MCF. As previously noted, these meters are not required monitoring devices and the Enterprise environmental team does not use this data for compliance purposes, nor do we oversee upkeep of these devices. Therefore, the accuracy of the data cannot be verified. Some information on the two (2) acid gas flare flow meters is included in this submittal: The Newberry T1 Acid Gas Flare flow meter is a Panametrics PanaFlow USM PF8-Z1G S/N: UE-Z1-0292. The flow output from this meter has been adjusted based on the measured flow and an assumed fixed pressure, assumed fixed temperature, and assumed fixed density/composition - these parameters are not being measured. The device adjusts the measured volume to a standard volume based on assumed fixed pressure, temperature, and density variables, making it not possible to see the measured volume before adjustment. The meter has yet to be calibrated since installation - calibration would require a process shutdown so the device could be removed and shipped off. The Newberry T2 Acid Gas Flare is a Panametrics PanaFlow MV80-VTP (8" Vortex Mass) S/N: 5519748. The flow output from this meter has been adjusted based on the measured mass and, internally measured temperature and pressure, and assumed fixed density/composition. The device adjusts the measured mass to a standard volume based on the internally measured temperature and pressure, and assumed fixed density variable, but it's not possible to independently verify / calibrate the temperature and pressure readings. The meter was replaced approximately 4 years ago - calibration would require a process shutdown so the device could be removed and shipped off. If you have any questions, please let me know. Regards, Jon E. Fields | Director, Field Environmental Enterprise Products Operating LLC 1100 Louisiana St., Houston, Tx 77002-5227 (713) 381-6684 office | (832) 596-7176 cell | jefields@eprod.com This message (including any attachments) is confidential and intended for a specific individual and purpose. If you are not the intended recipient, please notify the sender immediately and delete this message. Newberry Gas Plant /Enterprise Midland Basin Midstream LLC Inspection Date 12/19/2024 Appendix C TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 TCEQ NON-RULE STANDARD PERMIT REGISTRATION UPDATE OIL & GAS HANDLING AND PRODUCTION FACILITIES NAVITAS MIDSTREAM MIDLAND BASIN, LLC NEWBERRY GAS PLANT MIDLAND COUNTY, TEXAS For Information Contact: Ms. Michelle McCracken Manager - EH&S Navitas Midstream Midland Basin, LLC 9303 New Trails Drive, Suite 400 The Woodlands, TX 77381 (832) 982-7091 Submitted To: Texas Commission on Environmental Quality Office of Air Quality New Source Review Program P.O. Box 13087 Austin, Texas 78711-3087 Prepared By: Altamira, LLC 525 Central Park Drive, Suite 500 Oklahoma City, Oklahoma 73105 September 2019 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 TABLE OF CONTENTS Section Page LIST OF FIGURES .................................................................................................... ii LIST OF APPENDICES............................................................................................ iii 1.0 INTRODUCTION.......................................................................................... 1-1 2.0 TCEQ STANDARD PERMIT APPLICATION FORMS ................................ 2-1 3.0 FACILITY LOCATION AND DESCRIPTION ............................................... 3-1 4.0 AIR EMISSIONS .......................................................................................... 4-1 5.0 GENERAL REQUIREMENTS ...................................................................... 5-1 5.1 Non-Rule Standard Permit Applicability .................................................. 5-1 5.2 30 TAC 116.610 Applicability................................................................... 5-6 5.3 30 TAC 116.611 Registration to Use a Standard Permit....................... 5-8 5.4 30 TAC 116.614 Standard Permit Fees .................................................. 5-9 5.5 30 TAC 116.615. General Conditions ..................................................... 5-9 i TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 Figure LIST OF FIGURES 3-1 Area Map 3-3 3-2 Facility Plot Plan 3-4 3-3 Process Flow Diagram 3-5 ii TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 Appendix LIST OF APPENDICES A Emission Calculations A-1 B Supporting Documentation B-1 C Impacts Evaluation C-1 iii TCEQ NON-RULE STANDARD PERMIT REGISTRATION NAVITAS MIDSTREAM MIDLAND BASIN, LLC NEWBERRY GAS PLANT MIDLAND COUNTY, TEXAS SEPTEMBER 2019 1.0 INTRODUCTION Navitas Midstream Midland Basin, LLC (Navitas) owns and operates the Newberry Gas Plant in Midland County, Texas (Facility). Navitas is currently authorized to operate the Facility under TCEQ Non-Rule Standard Permit for Oil and Gas Handling and Production Facilities (NRSP) Registration No. 141647. Navitas is submitting this update to add four (4) natural gas-fired compressor engines, remove two (2) natural gas-fired compressor engines remove one (1) natural gas-fired heater (H-3), and update the naming schemes for the remaining engines at the Facility. In addition, various updates to existing emissions at the Facility are proposed. The emission sources to be included in the Non-Rule Standard Permit are as follows: x Six (6) Caterpillar 3516B Compressor Engines (FINs: C-1680, C-1690, C-1710, C1720, C-1730, and C-1740) x Three (3) Caterpillar 3606 Compressor Engines (FINs: C-181, C-182, and C-183) x Four (4) Caterpillar G3608A4 Compressor Engines (FINs: C-1750, C-1760, C- 1770, and C-1780) x Four (4) Waukesha 5794GSI Compressor Engines (FINs: C-171N, C-172N, C- 173N, C-174N) x Two (2) Amine Units (FINs: AMINE and AMINE-2) x One (1) Amine Reboiler Hot Oil Heater (FIN: H-1) x Two (2) Mole Sieve Regeneration Gas Heaters (FIN: H-2 and H-7) x One (1) Cryo Trim Reboiler Hot Oil Heater (FIN: H-4) x Two (2) Combo Hot Oil Heaters (FINs: H-5 and H-6) x Two (2) Plant Flares (FINs: FLARE-1 and FLARE-2) x Two (2) Process Vents to Flare (FINs: PROCESS-1, PROCESS-2) x One (1) Tank Vent Combustor (FIN: COMB-1) 1-1 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 x Two (2) 750-bbl Condensate Storage Tanks (FINs: TK-1 and TK-2) x Two (2) 10,000-bbl Condensate Storage Tanks (FINs: TK-3 and TK-4) x One (1) 210-bbl Slop Oil Tank (FIN: TK-5) x Twelve (12) 80-bbl Open Drain Storage Tanks (FIN: TK-6, TK-7, TK-8, TK-9, TK- 10, TK-11, TK-12, TK-13, TK-14, TK-15, TK-16 and TK-17) x One (1) Glycol Dehydration Unit (FIN: DEHY1) x Condensate Truck Loading Operations (FIN: L-1) x Fugitive Emissions (FIN: FUG-1 and FUG-2) x Blowdown Emissions (FIN: VENT-1) x Other Venting Emissions (FIN: VENT-2) x Engine Starter Vent Emissions (FIN: VENT-3) x MSS Emissions (FIN: MSS-1) 1-2 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 2.0 TCEQ STANDARD PERMIT APPLICATION FORMS The following TCEQ permit application forms are included in this section: x PI-1S Form x Table 29 - C-1680 x Table 29 - C-1690 x Table 29 - C-1710 x Table 29 - C-1720 x Table 29 - C-1730 x Table 29 - C-1740 x Table 29 - C-1750 x Table 29 - C-1760 x Table 29 - C-1770 x Table 29 - C-1780 x Table 29 - C-171N x Table 29 - C-172N x Table 29 - C-173N x Table 29 - C-174N x Table 29 - C-181 x Table 29 - C-182 x Table 29 - C-183 x Table 1(a) x TCEQ Summary Table 2-1 7H[DV&RPPLVVLRQRQ(QYLURQPHQWDO4XDOLW\ )RUP3,6 5HJLVWUDWLRQVIRU$LU6WDQGDUG3HUPLW 3DJH , 5HJLVWUDQW,QIRUPDWLRQ $ &RPSDQ\RU2WKHU/HJDO&XVWRPHU1DPH 1DYLWDV 0LGVWUHDP 0LGODQG %DVLQ //& % &RPSDQ\2IILFLDO&RQWDFW,QIRUPDWLRQ 0U0UV~0V2WKHU - 1DPH 0LFKHOOH 0F&UDFNHQ 7LWOH 0DQDJHU (+ 6 0DLOLQJ$GGUHVV 1HZ 7UDLOV 'ULYH 6XLWH &LW\ 7KH :RRGODQGV 3KRQH I6WDWH 7; (PDLO$GGUHVV PPFFUDFNHQ#QDYLWDVPLGVWUHDPFRP I)D[1$ I=,3&RGH $OOSHUPLWFRUUHVSRQGHQFHZLOOEHVHQWYLDHPDLO 00 & 7HFKQLFDO&RQWDFW,QIRUPDWLRQ ~ 0U0UV0V2WKHU - 1DPH =DFKDU\ &URZHOO 7LWOH $VVLVWDQW $LU *URXS 0DQDJHU &RPSDQ\1DPH $OWDPLUD //& 0DLOLQJ$GGUHVV &HQWUDO 3DUN 'U 6XLWH &LW\ 2NODKRPD &LW\ 3KRQH I6WDWH 2. 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Engine Data Manufacturer: &DWHUSLOODU Model No. *% Serial No. -() Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: & Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle Carbureted [El Spark Ignited Dual Fuel [8J Fuel Injected Diesel Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. 18] Turbo Charged Intercooled I.C. Water Temperature ~ Lean Burn Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: ~ Manufacturer Data AP-42 ~ Other (specify : /414++++ IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I NSCR Catalyst JLCC Catalyst ~ Lean Operation Parameter Adjustment @ Other (Specify : 2[LGDWLRQ &DWDO\VW Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ [8J MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: &DWHUSLOODU Model No. *% Serial No. -() Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: & Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle Carbureted [El Spark Ignited Dual Fuel [8J Fuel Injected Diesel Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. 18] Turbo Charged Intercooled I.C. Water Temperature ~ Lean Burn Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: ~ Manufacturer Data AP-42 ~ Other (specify : /414++++ IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I NSCR Catalyst JLCC Catalyst ~ Lean Operation Parameter Adjustment @ Other (Specify : 2[LGDWLRQ &DWDO\VW Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ [8J MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: &DWHUSLOODU Model No. *% Serial No. -() Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: & Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle Carbureted [El Spark Ignited Dual Fuel [8J Fuel Injected Diesel Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. 18] Turbo Charged Intercooled I.C. Water Temperature ~ Lean Burn Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: ~ Manufacturer Data AP-42 ~ Other (specify : /414++++ IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I NSCR Catalyst JLCC Catalyst ~ Lean Operation Parameter Adjustment @ Other (Specify : 2[LGDWLRQ &DWDO\VW Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ [8J MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: &DWHUSLOODU Model No. *% Serial No. -() Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: & Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle Carbureted [El Spark Ignited Dual Fuel [8J Fuel Injected Diesel Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. 18] Turbo Charged Intercooled I.C. Water Temperature ~ Lean Burn Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: ~ Manufacturer Data AP-42 ~ Other (specify : /414++++ IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I NSCR Catalyst JLCC Catalyst ~ Lean Operation Parameter Adjustment @ Other (Specify : 2[LGDWLRQ &DWDO\VW Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ [8J MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: &DWHUSLOODU Model No. *% Serial No. -() Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: & Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle Carbureted [El Spark Ignited Dual Fuel [8J Fuel Injected Diesel Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. 18] Turbo Charged Intercooled I.C. Water Temperature ~ Lean Burn Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: ~ Manufacturer Data AP-42 ~ Other (specify : /414++++ IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I NSCR Catalyst JLCC Catalyst ~ Lean Operation Parameter Adjustment @ Other (Specify : 2[LGDWLRQ &DWDO\VW Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ [8J MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: &DWHUSLOODU Model No. *% Serial No. -() Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: & Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle Carbureted [El Spark Ignited Dual Fuel [8J Fuel Injected Diesel Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. 18] Turbo Charged Intercooled I.C. Water Temperature ~ Lean Burn Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: ~ Manufacturer Data AP-42 ~ Other (specify : /414++++ IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I NSCR Catalyst JLCC Catalyst ~ Lean Operation Parameter Adjustment @ Other (Specify : 2[LGDWLRQ &DWDO\VW Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ [8J MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: &DWHUSLOODU Model No. *$ Serial No. ;+ Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: & Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle Carbureted [El Spark Ignited Dual Fuel [8J Fuel Injected Diesel Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. 18] Turbo Charged Intercooled I.C. Water Temperature ~ Lean Burn Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: ~ Manufacturer Data AP-42 Other (specify : /414++++ IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I NSCR Catalyst JLCC Catalyst ~ Lean Operation Parameter Adjustment @ Other (Specify : 2[LGDWLRQ &DWDO\VW Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ [8J MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: &DWHUSLOODU Model No. *$ Serial No. ;+ Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: & Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle Carbureted [El Spark Ignited Dual Fuel [8J Fuel Injected Diesel Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. 18] Turbo Charged Intercooled I.C. Water Temperature ~ Lean Burn Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: ~ Manufacturer Data AP-42 Other (specify : /414++++ IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I NSCR Catalyst JLCC Catalyst ~ Lean Operation Parameter Adjustment @ Other (Specify : 2[LGDWLRQ &DWDO\VW Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ [8J MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: &DWHUSLOODU Model No. *$ Serial No. ;+ Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: & Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle Carbureted [El Spark Ignited Dual Fuel [8J Fuel Injected Diesel Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. 18] Turbo Charged Intercooled I.C. Water Temperature ~ Lean Burn Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: ~ Manufacturer Data AP-42 Other (specify : /414++++ IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I NSCR Catalyst JLCC Catalyst ~ Lean Operation Parameter Adjustment @ Other (Specify : 2[LGDWLRQ &DWDO\VW Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ [8J MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: &DWHUSLOODU Model No. *$ Serial No. ;+ Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: & Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle Carbureted [El Spark Ignited Dual Fuel [8J Fuel Injected Diesel Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. 18] Turbo Charged Intercooled I.C. Water Temperature ~ Lean Burn Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: ~ Manufacturer Data AP-42 Other (specify : /414++++ IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I NSCR Catalyst JLCC Catalyst ~ Lean Operation Parameter Adjustment @ Other (Specify : 2[LGDWLRQ &DWDO\VW Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ [8J MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: :DXNHVKD Model No. *6, Serial No. Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: &1 Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle [El Carbureted [El Spark Ignited Dual Fuel Fuel Injected Diesel 18] Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. Turbo Charged Intercooled I.C. Water Temperature Lean Burn ~ Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: Manufacturer Data AP-42 Other (specify : IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I ~ NSCR Catalyst JLCC Catalyst Lean Operation Parameter Adjustment @ Other (Specify : &DWDO\WLF &RQYHUWHU Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ IE] MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: :DXNHVKD Model No. *6, Serial No. Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: &1 Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle [El Carbureted [El Spark Ignited Dual Fuel Fuel Injected Diesel 18] Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. Turbo Charged Intercooled I.C. Water Temperature Lean Burn ~ Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: Manufacturer Data AP-42 Other (specify : IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I ~ NSCR Catalyst JLCC Catalyst Lean Operation Parameter Adjustment @ Other (Specify : &DWDO\WLF &RQYHUWHU Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ IE] MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: :DXNHVKD Model No. *6, Serial No. Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: &1 Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle [El Carbureted [El Spark Ignited Dual Fuel Fuel Injected Diesel 18] Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. Turbo Charged Intercooled I.C. Water Temperature Lean Burn ~ Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: Manufacturer Data AP-42 Other (specify : IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I ~ NSCR Catalyst JLCC Catalyst Lean Operation Parameter Adjustment @ Other (Specify : &DWDO\WLF &RQYHUWHU Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ IE] MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: :DXNHVKD Model No. *6, Serial No. Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: &1 Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle [El Carbureted [El Spark Ignited Dual Fuel Fuel Injected Diesel 18] Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. Turbo Charged Intercooled I.C. Water Temperature Lean Burn ~ Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: Manufacturer Data AP-42 Other (specify : IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I ~ NSCR Catalyst JLCC Catalyst Lean Operation Parameter Adjustment @ Other (Specify : &DWDO\WLF &RQYHUWHU Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ IE] MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: &DWHUSLOODU Model No. Serial No. =6 Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: & Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle Carbureted [El Spark Ignited Dual Fuel [8J Fuel Injected Diesel Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. 18] Turbo Charged Intercooled I.C. Water Temperature ~ Lean Burn Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: ~ Manufacturer Data AP-42 Other (specify : /414++++ IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I NSCR Catalyst JLCC Catalyst ~ Lean Operation Parameter Adjustment @ Other (Specify : 2[LGDWLRQ &DWDO\VW Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ [8J MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: &DWHUSLOODU Model No. Serial No. =6 Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: & Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle Carbureted [El Spark Ignited Dual Fuel [8J Fuel Injected Diesel Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. 18] Turbo Charged Intercooled I.C. Water Temperature ~ Lean Burn Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: ~ Manufacturer Data AP-42 Other (specify : /414++++ IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I NSCR Catalyst JLCC Catalyst ~ Lean Operation Parameter Adjustment @ Other (Specify : 2[LGDWLRQ &DWDO\VW Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ [8J MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 Texas Commission on Environmental Quality Table 29 Reciprocating Engines I. Engine Data Manufacturer: &DWHUSLOODU Model No. Serial No. Manufacture Date: Rebuilds Date: No. of Cylinders: Compression Ratio: EPN: & Application: [El Gas Compression Electric Generation Refrigeration Emergency/Stand by [El 4 Stroke Cycle 2 Stroke Cycle Carbureted [El Spark Ignited Dual Fuel [8J Fuel Injected Diesel Naturally Aspirated Blower /Pump Scavenged Turbo Charged and I.C. 18] Turbo Charged Intercooled I.C. Water Temperature ~ Lean Burn Rich Burn Ignition/Injection Timing: Fixed: Manufacture Horsepower Rating: IVariable: Proposed Horsepower Rating: Stack Height Feet Discharge Parameters Stack Diameter (Feet) Stack Temperature (oF) Exit Velocity FPS II. Fuel Data Type of Fuel: 18] Field Gas Landfill Gas LP Gas Fuel Consumption (BTU/bhp-hr): I Heat LQJValue: Sulfur Content (grains/100 scf - weight %): 1HJOLJLEOH ~ Natural Gas Digester Gas Diesel I /RZHU+HDWLQJ9DOXH III. Emission Factors Before Control NOX CO SO2 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv VOC g/hp-hr ppmv Formaldehyde g/hp-hr ppmv PM10 g/hp-hr ppmv Source of Emission Factors: ~ Manufacturer Data AP-42 Other (specify : /414++++ IV. Emission Factors Post Control NOX CO SO2 VOC Formaldehyde PM10 g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv g/hp-hr ppmv Method of Emission Control: Stratified Charge I NSCR Catalyst JLCC Catalyst ~ Lean Operation Parameter Adjustment @ Other (Specify : 2[LGDWLRQ &DWDO\VW Note: Must submit a copy of any manufacturer control information that demonstrates control efficiency. Is Formaldehyde included in the VOCs? Yes [El No V. Federal and State Standards (Check all that apply 18] NSPS JJJJ [8J MACT ZZZZ NSPS IIII Title 30 Chapter 117 - List County: VI. Additional Information 1. Submit a copy of the engine manufacturer's site rating or general rating specification data. 2. Submit a typical fuel gas analysis, including sulfur content and heating value. For gaseous fuels, provide mole percent of constituents. 3. Submit description of air/fuel ratio control system (manufacturer information is acceptable). TCEQ-10195 Revised 11/17 Table 29 Reciprocating Engines This form is for use by facilities subject to air quality permit requirements and may be revised periodically. Reset Form Print Form Page 1 of 1 TEXAS COMMISSION ON ENVIRONMENTAL QUALITY Table 1(a) Emission Point Summary ..__ ..__ Date: Area Name: 9/24/2019 Navitas Midstream Midland Basin, LLC, Newberry Gas Plant Permit Number: NRSP No. 141647 Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this Table. AIR CONTAMINANT DATA 1. Emission Point EPN FIN NAME 2. Component or Air Contaminant Name A) B) C) & & +S&DWHUSLOODU% & & +S&DWHUSLOODU% & & +S&DWHUSLOODU% 12[ &2 92&D 62 30 +&+2 12[ &2 92&D 62 30 +&+2 12[ &2 92&D 62 30 +&+2 Regulated Entity No: Customer Reference No.: RN109272526 CN604937243 3. Air Contaminant Emission Rate Pounds per Hour A) TPY B) (31 (PLVVLRQ3RLQW1XPEHU),1 )DFLOLW\,GHQWLILFDWLRQ1XPEHU D92&LQFOXGHVIRUPDOGHK\GH >7&(45HYLVHG7DEOHD $3'*Y 1HZEHUU\&DOFVB[OV[ 3DJHRI TEXAS COMMISSION ON ENVIRONMENTAL QUALITY Table 1(a) Emission Point Summary - Date: Area Name: 9/24/2019 Navitas Midstream Midland Basin, LLC, Newberry Gas Plant Permit Number: NRSP No. 141647 Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this Table. AIR CONTAMINANT DATA 1. Emission Point EPN FIN NAME 2. Component or Air Contaminant Name A) B) C) & & +S&DWHUSLOODU% & & +S&DWHUSLOODU% & & +S&DWHUSLOODU% 12[ &2 92&D 62 30 +&+2 12[ &2 92&D 62 30 +&+2 12[ &2 92&D 62 30 +&+2 Regulated Entity No: Customer Reference No.: RN109272526 CN604937243 3. Air Contaminant Emission Rate Pounds per Hour A) TPY B) (31 (PLVVLRQ3RLQW1XPEHU),1 )DFLOLW\,GHQWLILFDWLRQ1XPEHU D92&LQFOXGHVIRUPDOGHK\GH >7&(45HYLVHG7DEOHD $3'*Y 1HZEHUU\&DOFVB[OV[ 3DJHRI TEXAS COMMISSION ON ENVIRONMENTAL QUALITY Table 1(a) Emission Point Summary - Date: Area Name: 9/24/2019 Navitas Midstream Midland Basin, LLC, Newberry Gas Plant Permit Number: NRSP No. 141647 Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this Table. AIR CONTAMINANT DATA 1. Emission Point EPN FIN NAME 2. Component or Air Contaminant Name A) B) C) & & +S&DWHUSLOODU*$ & & +S&DWHUSLOODU*$ & & +S&DWHUSLOODU*$ 12[ &2 92&D 62 30 +&+2 12[ &2 92&D 62 30 +&+2 12[ &2 92&D 62 30 +&+2 Regulated Entity No: Customer Reference No.: RN109272526 CN604937243 3. Air Contaminant Emission Rate Pounds per Hour A) TPY B) (31 (PLVVLRQ3RLQW1XPEHU),1 )DFLOLW\,GHQWLILFDWLRQ1XPEHU D92&LQFOXGHVIRUPDOGHK\GH >7&(45HYLVHG7DEOHD $3'*Y 1HZEHUU\&DOFVB[OV[ 3DJHRI TEXAS COMMISSION ON ENVIRONMENTAL QUALITY Table 1(a) Emission Point Summary - Date: Area Name: 9/24/2019 Navitas Midstream Midland Basin, LLC, Newberry Gas Plant Permit Number: NRSP No. 141647 Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this Table. AIR CONTAMINANT DATA 1. Emission Point EPN FIN NAME 2. Component or Air Contaminant Name A) B) C) & & +S&DWHUSLOODU*$ &1 &1 +S:DXNHVKD*6, &1 &1 +S:DXNHVKD*6, &1 &1 +S:DXNHVKD*6, 12[ &2 92&D 62 30 +&+2 12[ &2 92&D 62 30 +&+2 12[ &2 92&D 62 30 +&+2 12[ &2 92&D 62 30 +&+2 (31 (PLVVLRQ3RLQW1XPEHU),1 )DFLOLW\,GHQWLILFDWLRQ1XPEHU D92&LQFOXGHVIRUPDOGHK\GH >7&(45HYLVHG7DEOHD $3'*Y 1HZEHUU\&DOFVB[OV[ Regulated Entity No: Customer Reference No.: RN109272526 CN604937243 3. Air Contaminant Emission Rate Pounds per Hour A) TPY B) 3DJHRI TEXAS COMMISSION ON ENVIRONMENTAL QUALITY Table 1(a) Emission Point Summary - Date: Area Name: 9/24/2019 Navitas Midstream Midland Basin, LLC, Newberry Gas Plant Permit Number: NRSP No. 141647 Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this Table. AIR CONTAMINANT DATA 1. Emission Point EPN FIN NAME 2. Component or Air Contaminant Name A) B) C) &1 &1 +S:DXNHVKD*6, & & +S&DWHUSLOODU & & & & +S&DWHUSLOODU 12[ &2 92&D 62 30 +&+2 12[ &2 92&D 62 30 +&+2 12[ &2 92&D 62 30 +&+2 Regulated Entity No: Customer Reference No.: RN109272526 CN604937243 3. Air Contaminant Emission Rate Pounds per Hour A) TPY B) (31 (PLVVLRQ3RLQW1XPEHU),1 )DFLOLW\,GHQWLILFDWLRQ1XPEHU D92&LQFOXGHVIRUPDOGHK\GH >7&(45HYLVHG7DEOHD $3'*Y 1HZEHUU\&DOFVB[OV[ 3DJHRI TEXAS COMMISSION ON ENVIRONMENTAL QUALITY Table 1(a) Emission Point Summary - Date: Area Name: 9/24/2019 Navitas Midstream Midland Basin, LLC, Newberry Gas Plant Permit Number: NRSP No. 141647 Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this Table. AIR CONTAMINANT DATA 1. Emission Point EPN FIN NAME 2. Component or Air Contaminant Name A) B) C) $PLQH5HERLOHU+RW2LO+HDWHU + + 00%78KU 12[ &2 92& 0ROH6LHYH5HJHQHUDWLRQ*DV+HDWHU + + 00%78KU 62 30 12[ &2 92& 62 &U\R7ULP5HERLOHU+RW2LO+HDWHU + + 00%78KU 30 12[ &2 92& 62 30 Regulated Entity No: Customer Reference No.: RN109272526 CN604937243 3. Air Contaminant Emission Rate Pounds per Hour A) TPY B) (31 (PLVVLRQ3RLQW1XPEHU),1 )DFLOLW\,GHQWLILFDWLRQ1XPEHU D92&LQFOXGHVIRUPDOGHK\GH >7&(45HYLVHG7DEOHD $3'*Y 1HZEHUU\&DOFVB[OV[ 3DJHRI TEXAS COMMISSION ON ENVIRONMENTAL QUALITY Table 1(a) Emission Point Summary - Date: Area Name: 9/24/2019 Navitas Midstream Midland Basin, LLC, Newberry Gas Plant Permit Number: NRSP No. 141647 Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this Table. AIR CONTAMINANT DATA 1. Emission Point EPN FIN NAME 2. Component or Air Contaminant Name A) B) C) + + &RPER+RW2LO+HDWHU00%78KU 12[ &2 92& 62 30 + + &RPER+RW2LO+HDWHU00%78KU 12[ &2 92& 62 0ROH6LHYH5HJHQHUDWLRQ*DV+HDWHU + + 00%78KU 30 12[ &2 92& 62 30 Regulated Entity No: Customer Reference No.: RN109272526 CN604937243 3. Air Contaminant Emission Rate Pounds per Hour A) TPY B) (31 (PLVVLRQ3RLQW1XPEHU),1 )DFLOLW\,GHQWLILFDWLRQ1XPEHU D92&LQFOXGHVIRUPDOGHK\GH >7&(45HYLVHG7DEOHD $3'*Y 1HZEHUU\&DOFVB[OV[ 3DJHRI TEXAS COMMISSION ON ENVIRONMENTAL QUALITY Table 1(a) Emission Point Summary - Date: Area Name: 9/24/2019 Navitas Midstream Midland Basin, LLC, Newberry Gas Plant Permit Number: NRSP No. 141647 Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this Table. AIR CONTAMINANT DATA 1. Emission Point EPN FIN NAME 2. Component or Air Contaminant Name A) $0,1( B) $0,1( C) $PLQH8QLW9HQW 92& + 6 %HQ]HQH $0,1( $0,1( $PLQH8QLW9HQW 92& +6 %HQ]HQH )/$5( )/$5( 3ODQW)ODUH 12[ &2 92& 62 +6 %HQ]HQH '(+< '(+< *O\FRO'HK\GUDWLRQ8QLW'(+< 92&D %HQ]HQH )/$5( )/$5( 3ODQW)ODUH 12[ &2 92& 62 +6 %HQ]HQH Regulated Entity No: Customer Reference No.: RN109272526 CN604937243 3. Air Contaminant Emission Rate Pounds per Hour A) TPY B) (31 (PLVVLRQ3RLQW1XPEHU),1 )DFLOLW\,GHQWLILFDWLRQ1XPEHU D92&LQFOXGHVIRUPDOGHK\GH >7&(45HYLVHG7DEOHD $3'*Y 1HZEHUU\&DOFVB[OV[ 3DJHRI TEXAS COMMISSION ON ENVIRONMENTAL QUALITY Table 1(a) Emission Point Summary - Date: Area Name: 9/24/2019 Navitas Midstream Midland Basin, LLC, Newberry Gas Plant Permit Number: NRSP No. 141647 Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this Table. AIR CONTAMINANT DATA 1. Emission Point EPN FIN NAME 2. Component or Air Contaminant Name A) B) C) &20% &20% 7DQN9HQW&RPEXVWRU 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 6ORS2LO6WRUDJH7DQNEEO 6ORS2LO6WRUDJH7DQNEEO &RQGHQVDWH6WRUDJH7DQNEEO &RQGHQVDWH6WRUDJH7DQNEEO 6ORS2LO6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO *DVROLQH6WRUDJH7DQNJDO 12[ &2 92& 62 30 92& 92& 92& 92& 92& 92& 92& 92& 92& 92& 92& 92& 92& 92& 92& 92& 92& 92& (31 (PLVVLRQ3RLQW1XPEHU),1 )DFLOLW\,GHQWLILFDWLRQ1XPEHU D92&LQFOXGHVIRUPDOGHK\GH >7&(45HYLVHG7DEOHD $3'*Y 1HZEHUU\&DOFVB[OV[ Regulated Entity No: Customer Reference No.: RN109272526 CN604937243 3. Air Contaminant Emission Rate Pounds per Hour A) TPY B) 3DJHRI TEXAS COMMISSION ON ENVIRONMENTAL QUALITY Table 1(a) Emission Point Summary - Date: Area Name: 9/24/2019 Navitas Midstream Midland Basin, LLC, Newberry Gas Plant Permit Number: NRSP No. 141647 Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this Table. AIR CONTAMINANT DATA 1. Emission Point EPN FIN NAME 2. Component or Air Contaminant Name A) B) C) 7. / )8* )8* 9(17 9(17 9(17 066 7. / )8* )8* 9(17 9(17 9(17 066 'LHVHO6WRUDJH7DQNJDO 7UXFN/RDGLQJ 1RQ0RQLWRUHG6LWH)XJLWLYHV 0RQLWRUHG6LWH)XJLWLYHV %ORZGRZQ9HQW 2WKHU9HQWLQJ (QJLQH6WDUWHU9HQW 066(PLVVLRQV 92& 92& 92& +6 %HQ]HQH 92& 92& %HQ]HQH 92& %HQ]HQH 92& %HQ]HQH 92& 30 %HQ]HQH 6LWHZLGH+$37RWDO 6LWHZLGH,QGLYLGXDO+$3 Regulated Entity No: Customer Reference No.: RN109272526 CN604937243 3. Air Contaminant Emission Rate Pounds per Hour A) TPY B) (31 (PLVVLRQ3RLQW1XPEHU),1 )DFLOLW\,GHQWLILFDWLRQ1XPEHU D92&LQFOXGHVIRUPDOGHK\GH >7&(45HYLVHG7DEOHD $3'*Y 1HZEHUU\&DOFVB[OV[ 3DJHRI SUMMARY TABLE ESTIMATED EMISSIONS EPN/Emission Source Unchanged Sources C-1680 / 1,380 Hp Caterpillar 3516B C-1690 / 1,380 Hp Caterpillar 3516B C-1710 / 1,380 Hp Caterpillar 3516B C-1720 / 1,380 Hp Caterpillar 3516B C-1730 / 1,380 Hp Caterpillar 3516B C-1740 / 1,380 Hp Caterpillar 3516B C-1750 / 2,500 Hp Caterpillar G3608A4 C-1760 / 2,500 Hp Caterpillar G3608A4 C-1770 / 2,500 Hp Caterpillar G3608A4 C-1780 / 2,500 Hp Caterpillar G3608A4 C-171N / 1,380 Hp Waukesha 5794GSI C-172N / 1,380 Hp Waukesha 5794GSI C-173N / 1,380 Hp Waukesha 5794GSI C-174N / 1,380 Hp Waukesha 5794GSI C-181 / 1,775 Hp Caterpillar 3606 C-182 / 1,775 Hp Caterpillar 3606 C-183 / 1,775 Hp Caterpillar 3606 H-1 / Amine Reboiler Hot Oil Heater (34.2 MMBTU/hr) H-2 / Mole Sieve Regeneration Gas Heater 1 (9.6 MMBTU/hr) H-4 / Cryo Trim Reboiler Hot Oil Heater 1 (6.93 MMBTU/hr) H-5 / Combo Hot Oil Heater 1 (51 MMBTU/hr) H-6 / Combo Hot Oil Heater 2 (51 MMBTU/hr) H-7 / Mole Sieve Regeneration Gas Heater 2 (6.23 MMBTU/hr) AMINE / Amine Unit Vent AMINE-2 / Amine Unit 2 Vent FLARE-1 / Plant 1 Flare DEHY1 / Glycol Dehydration Unit (DEHY1) FLARE-2 / Plant 2 Flare COMB-1 / Tank Vent Combustor TK-1 / Slop Oil Storage Tank (750-bbl) TK-2 / Slop Oil Storage Tank (750-bbl) TK-3 / Condensate Storage Tank (10,000-bbl) TK-4 / Condensate Storage Tank (10,000-bbl) TK-5 / Slop Oil Storage Tank (210-bbl) TK-6 / Open Drain Storage Tank (80-bbl) TK-7 / Open Drain Storage Tank (80-bbl) TK-8 / Open Drain Storage Tank (80-bbl) TK-9 / Open Drain Storage Tank (80-bbl) TK-10 / Open Drain Storage Tank (80-bbl) TK-11 / Open Drain Storage Tank (80-bbl) TK-12 / Open Drain Storage Tank (80-bbl) TK-13 / Open Drain Storage Tank (80-bbl) TK-14 / Open Drain Storage Tank (80-bbl) TK-15 / Open Drain Storage Tank (80-bbl) TK-16 / Open Drain Storage Tank (80-bbl) TK-17 / Open Drain Storage Tank (80-bbl) TK-18 / Gasoline Storage Tank (500-gal) TK-19 / Diesel Storage Tank (500-gal) L-1 / Truck Loading FUG-1 / Non-Monitored Site Fugitives FUG-2 / Monitored Site Fugitives VENT-1 / Blowdown Vent VENT-2 / Other Venting VENT-3 / Engine Starter Vent MSS-1 / MSS Emissions Specific VOC or Other Pollutants VOC lbs/hr tpy NOx lbs/hr tpy CO lbs/hr tpy PM10 lbs/hr tpy PM 2.5 lbs/hr tpy SO2 lbs/hr tpy H2S lbs/hr tpy Benzene lbs/hr tpy Formaldehyde lbs/hr tpy 0.83 3.65 1.52 6.66 1.26 5.50 0.10 0.45 0.10 0.45 <0.01 0.03 -- 0.83 3.65 1.52 6.66 1.26 5.50 0.10 0.45 0.10 0.45 <0.01 0.03 -- 0.83 3.65 1.52 6.66 1.26 5.50 0.10 0.45 0.10 0.45 <0.01 0.03 -- 0.83 3.65 1.52 6.66 1.26 5.50 0.10 0.45 0.10 0.45 <0.01 0.03 -- 0.83 3.65 1.52 6.66 1.26 5.50 0.10 0.45 0.10 0.45 <0.01 0.03 -- 0.83 3.65 1.52 6.66 1.26 5.50 0.10 0.45 0.10 0.45 <0.01 0.03 -- 1.91 8.38 2.75 12.06 2.57 11.28 0.17 0.74 0.17 0.74 <0.01 0.04 -- 1.91 8.38 2.75 12.06 2.57 11.28 0.17 0.74 0.17 0.74 <0.01 0.04 -- 1.91 8.38 2.75 12.06 2.57 11.28 0.17 0.74 0.17 0.74 <0.01 0.04 -- 1.91 8.38 2.75 12.06 2.57 11.28 0.17 0.74 0.17 0.74 <0.01 0.04 -- 1.16 5.06 1.52 6.66 1.43 6.26 0.21 0.90 0.21 0.90 <0.01 0.03 -- 1.16 5.06 1.52 6.66 1.43 6.26 0.21 0.90 0.21 0.90 <0.01 0.03 -- 1.16 5.06 1.52 6.66 1.43 6.26 0.21 0.90 0.21 0.90 <0.01 0.03 -- 1.16 5.06 1.52 6.66 1.43 6.26 0.21 0.90 0.21 0.90 <0.01 0.03 -- 1.37 5.98 1.95 8.56 1.83 8.01 0.12 0.52 0.12 0.52 <0.01 0.03 -- 1.37 5.98 1.95 8.56 1.83 8.01 0.12 0.52 0.12 0.52 <0.01 0.03 -- -- <0.01 0.02 0.10 0.46 -- <0.01 0.02 0.10 0.46 -- <0.01 0.02 0.10 0.46 -- <0.01 0.02 0.10 0.46 -- <0.01 0.02 0.10 0.46 -- <0.01 0.02 0.10 0.46 -- <0.01 0.03 0.12 0.54 -- <0.01 0.03 0.12 0.54 -- <0.01 0.03 0.12 0.54 -- <0.01 0.03 0.12 0.54 -- 0.02 0.07 0.15 0.67 -- 0.02 0.07 0.15 0.67 -- 0.02 0.07 0.15 0.67 -- 0.02 0.07 0.15 0.67 -- <0.01 0.02 0.13 0.59 -- <0.01 0.02 0.13 0.59 0.86 3.74 3.42 14.98 1.27 5.54 0.16 0.72 0.16 0.72 0.02 0.09 -- -- <0.01 <0.01 -- -- 0.05 0.23 0.94 4.12 0.79 3.46 0.07 0.31 0.07 0.31 <0.01 0.02 -- -- <0.01 <0.01 -- -- 0.04 0.16 0.68 2.98 0.57 2.50 0.05 0.23 0.05 0.23 <0.01 0.02 -- -- <0.01 <0.01 -- -- 1.28 5.58 3.06 13.40 1.89 8.27 0.24 1.07 0.24 1.07 0.03 0.13 -- -- <0.01 <0.01 -- -- 1.28 5.58 3.06 13.40 1.89 8.27 0.24 1.07 0.24 1.07 0.03 0.13 -- -- <0.01 <0.01 -- -- 0.03 0.15 0.61 2.68 0.51 2.25 0.05 0.20 0.05 0.20 <0.01 0.02 -- -- <0.01 <0.01 -- -- 0.99 4.35 -- -- -- -- -- -- -- -- -- -- 0.03 0.13 0.07 0.32 -- -- 0.87 3.82 -- -- -- -- -- -- -- -- -- -- 0.10 0.42 0.07 0.29 -- -- 3.61 15.79 2.95 12.94 5.90 25.83 -- -- -- -- 2.64 11.55 0.03 0.12 0.07 0.31 -- -- 3.52 15.41 -- -- -- -- -- -- -- -- -- -- -- -- 0.17 0.76 -- -- 5.34 23.41 3.37 14.76 6.73 29.46 -- -- -- -- 8.76 38.38 0.09 0.41 0.07 0.29 -- -- 2.23 9.78 0.49 2.15 0.41 1.80 0.04 0.16 0.04 0.16 <0.01 0.01 <0.01 <0.01 <0.01 <0.01 -- -- 0.04 0.18 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.04 0.18 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.30 1.30 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.30 1.30 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.03 0.13 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.08 0.35 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.08 0.35 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.08 0.35 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.08 0.35 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.08 0.35 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.08 0.35 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.08 0.35 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.08 0.35 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.08 0.35 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.08 0.35 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.08 0.35 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.08 0.35 -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- 0.03 0.12 -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- 15.65 37.08 -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 0.19 0.46 -- -- 1.02 4.49 -- -- -- -- -- -- -- -- -- -- 0.01 0.01 0.01 0.01 -- -- 0.74 3.24 -- -- -- -- -- -- -- -- -- -- 0.01 0.01 0.01 0.01 -- -- 20.41 8.49 -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 0.62 0.76 -- -- 136.04 3.40 -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 0.02 <0.01 -- -- 9.03 3.76 -- -- -- -- -- -- -- -- -- -- <0.01 <0.01 <0.01 <0.01 -- -- 9.15 3.23 -- -- -- -- 0.68 <0.01 0.68 <0.01 -- -- <0.01 <0.01 <0.01 0.26 -- -- TOTAL EMISSIONS (TPY): MAXIMUM OPERATING SCHEDULE: 246.73 Hours/Day 213.33 24 206.52 Days/Week 14.05 7 Weeks/Year 14.05 52 50.86 Hours/Year 1.09 Hours/Year 1RWH(QJLQH92&LQOFXGHVIRUPDOGHK\GH 7KH158PD\EHSRZHUHGE\&&DQGRU&2XWRIWKHWKUHHHQJLQHVRQO\WZRZLOOHYHURSHUDWHDWDJLYHQWLPH&&DQG&ZLOOQRWRSHUDWHPRUHWKDQDFRPELQHGKRXUVDQQXDOO\&HPLVVLRQVDUHLQFOXGHGLQ&DQG&HPLVVLRQWRWDOV 4.08 8.75 8760 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 3.0 FACILITY LOCATION AND DESCRIPTION Navitas owns and operates the Newberry Gas Plant (Facility) located in Midland and Glasscock Counties, Texas. As shown on Figure 3-1, the Facility is located approximately 15 miles southeast of Midland, Texas. A Facility Plot Plan and Process Flow Diagram are provided in Figure 3-2 and Figure 3-3. The latitude-longitude and Universal Transverse Mercator (UTM) coordinates of the Facility are: Latitude: 31.852716 Longitude: -101.777816 UTM Coordinates: NAD 83, Zone 14 237,156 m Easting 3,527,475 m Northing The Facility consists of two parallel cryogenic processing trains with capacities of 60 million standard cubic feet per day (MMSCFD) (Train 1, or T1) and 200 MMSCFD (Train 2, or T2) for a total plant capacity of 260 MMSCFD. Inlet gas is compressed and dehydrated at field compressor stations and enters the plant at high pressure through the Facility's slug catcher, where free hydrocarbon liquids are removed from the gas stream. The hydrocarbon liquids are reduced in pressure and stabilized in the two parallel plant stabilizer systems. From the slug catcher, inlet gas is split to the two processing trains, each of which consists of a 400 gpm amine plant for removal of CO2 and small amounts of H2S, cryogenic processing and demethanization, and residue compression. Acid gas components, H2S and CO2, absorbed by the lean amine solution in each amine contactor are liberated from the rich amine solution in the amine pre-heater and regeneration system. Regenerated, lean amine is circulated back to the amine contactors to continue the process of gas sweetening. Resultant vapors from the stabilization processes are routed back to the inlet of the plant. Gas is resaturated in the amine contactor and again dehydrated upstream of the cryogenic process to allow for processing at the cold cryogenic temperatures. For T1 this is 3-1 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 accomplished solely with a molecular sieve dehydration and regeneration system. T2 incorporates a glycol dehydration unit upstream of molecular sieve dehydration to provide bulk water removal. The cryogenic processes include heat exchangers, a turboexpander unit, and gas/liquids separation. From the cryogenic plants, residue gas is recompressed and delivered to sales pipelines. Natural gas liquids removed from the inlet gas stream in the stabilization and cryogenic systems are filtered and pumped to sales or removed via pressurized tank truck. The Facility also incorporates a nitrogen rejection unit (NRU) to remove nitrogen in residue gas to specification which consists of various heat exchangers, separation, and recompression. Stabilized condensate will be removed from the Facility's atmospheric tanks via tank trucks in dedicated service. The vapors during truck loading will be routed to the combustor. Unstabilized condensate may be removed from the Facility's pressurized storage tanks via pressurized tank trucks. Flash vapors generated during this process will be captured and sent to the combustor. Emissions from MSS activities are included in this application. 3-2 Data use subject to license. Delorme.Top North AmericaTM 10. www.delorme.com } MN(O.O'E) ~ ),*85(7,7/( '$7( $5($0$3 6&$/( $66+2:1 ALTAMI RA 1 - - - - - - - - - - - - - - - - - - - - - - - - = - - - - - -'(-6,*-1(1 '%<-$-' - - - 1 ' " ' """"'"-"-OY!r,,o,w/ '2&80(177,7/( $33529('%< =& &(175$/3$5.'5 12158/(67$1'$5'3(50,75(*,675$7,21 '5$:1%< $' 68,7( &/,(17 352-(&7180%(5 2.$/+20$&,7<2. 1$9,7$60,'675($00,'/$1'%$6,1//& 103$7; ZZZDOWDPLUDXVFRP /2&$7,21 1(:%(55<*$63/$17 0,'/$1'&2817<7(;$6 ),*85(180%(5 A B C D E F G H J J I I I J J J I t I J J I I J J J I I f I --z ,ce i::::i:r:: ~ - 1 NORTH 1 1111111111J .J I I I I I I I I I - m r- 'ir'i) DD 0 E::3 Er 0 @] I I I II a ~] I I I I I I I I I I I I I I I I I I I I I I I I I I Ia [gJ ~~--,~ffl ~~~~, 0 m 00 --~ = ==> , ~ ,, 2 2 - -= C-183 NRU COMPRESSOR C-182 NRU COMPRESSOR C-181 NRU COMPRESSOR C-174N RESIDUE GAS COMPRESSOR 4 C-173N RESIDUE GAS COMPRESSOR 3 C-172N RESIDUE GAS COMPRESSOR 2 C-171N RESIDUE GAS COMPRESSOR 1 ,c m - ~~ -=0 DD TK-235A CONDENSATE STORAGE TANK I TK-235B CONDENSATE STORAGE TANK 3 3 TK-2350A CONDENSATE STORAGE TANK I I TK-2350B CONDENSATE STORAGE TANK I Z-714 ATMOSPHERIC VAPOR COMBUSTER UNIT This document is copyrighted and is an instrument of service by Samuel Engineering (SE). It was prepared solely for the Owner's/Client's use on this project only. Use, copy or disclosure of any information shown, in whole or in part, without SE's consent, is strictly prohibited, is a copyright breach and may be prosecuted. Any unauthorized reuse shall be at the sole risk of the user. DWG NO. REFERENCE DRAWINGS NO. DATE BY R E V I S I O N S A B C CLIENT PROJECT ENGINEER LEAD ENGINEER CHECK CLIENT PROJECT ENGINEER LEAD ENGINEER CHECK C-1740 RESIDUE GAS COMPRESSOR C-1730 RESIDUE GAS COMPRESSOR C-1720 RESIDUE GAS COMPRESSOR C-1710 RESIDUE GAS COMPRESSOR C-1780 RESIDUE GAS COMPRESSOR C-1770 RESIDUE GAS COMPRESSOR C-1760 RESIDUE GAS COMPRESSOR C-1750 RESIDUE GAS COMPRESSOR C-1690 RESIDUE GAS COMPRESSOR C-1680 RESIDUE GAS COMPRESSOR A ISSUED FOR APPROVAL NO. R E V I S I O N S D SCALE: NTS DESIGNED: G.P. GREEN DRAWN: J. JOHNSON 04/16/19 JRJ CHECKED: S. McCRADY DATE BY APPROVED: B. VILNER APPROVED: E DATE 03/22/19 03/22/19 03/22/19 03/22/19 CLIENT: NAVITAS MIDSTREAM LOCATION: MIDLAND, TX SE i TX-REGISTERED Samuel Engineering ENGINEERING FIRM NO. F13934 8450 E. Crescent Parkway, Suite 200 Greenwood Village, CO 80111 Phone: 303.714.4840 Fax: 303.714.4800 F TITLE NEWBERRY GAS PROCESSING PLANT PLOT PLAN OVERALL EQUIPMENT GENERAL ARRANGEMENT G 4 PROJECT NUMBER 18333 DRAWING NUMBER REV. NBP-PP-00-050 A H Dway Inlet Z Z/ Z &>/ Z E'>Z Z Z Z Z Z ZZ Z Z Z dDDd dd J r---Y1-----r1- - - - - ~ - - - ~ ,}- _}- T l Z ^ ^ W DsZh & ,K ^ W DsZh Z ZZ 8BVL EZh ZZ Z ,K Z Z ZZ Z ZZ Z Z Z Z Z 'Z d^ d^ ZZ ,K ZZ ED EW >K<&>Kt/'ZD TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 4.0 AIR EMISSIONS Emissions from the engines are based on manufacturer's data, AP-42 emission factors, and New Source Performance Standards (NSPS) Subpart JJJJ. The engine emission calculations are included in Appendix A. The engine manufacturer data sheets are provided in Appendix B. Potential VOC and HAP emissions from the glycol dehydrator still vent (DEHY1) were estimated using GRI-GLYCalc Version 4.0 software, gas analysis from a representative site, a maximum natural gas throughput of 200 million standard cubic feet per day (MMScf/d), a maximum glycol circulation rate of 41 gallons per minute (gpm), and a still vent control efficiency of 98%. The still vent vapors are initially routed to a condenser. The non-condensable vapors are routed to one of the flares which provides a 98% reduction of emissions. The glycol dehydrator will be equipped with a flash tank, and during normal operations the vapors from the flash tank will be routed to one of the flares. While the vapors may go to either flare, for calculation purposes, it was assumed that the vapors are routed to FLARE-2. The VOC and HAP emissions summary table is included in Appendix A of this application. GRI-GLYCalc output and supporting data are included in Appendix B. Emissions from fuel gas combustion for the heaters (H-1 through H-7) are based on the AP-42 natural gas combustion factors, manufacturer provided factors, and maximum firing rates. Heater emission calculations are included in Appendix A. Potential VOC and HAP emissions from the amine units (AMINE and AMINE-2) were calculated using a representative gas analysis and ProMax. The vapors from the flash tank vent and the acid vent will be controlled by routing the emissions to one of the plant flares (FLARE-1 or FLARE-2). The emissions will be reduced by at least 98%. For calculation purposes, it was assumed that AMINE is routed to FLARE-1 and AMINE-2 is routed to FLARE-2. The VOC and HAP emissions summary table is included in Appendix A of this Application. The ProMax flow diagram and supporting data are included in Appendix B. 4-1 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 EPA TANKS 4.0.9d was used to estimate volatile organic compound (VOC) emission from the storage tanks. Vapors from the fixed roof slop oil storage tanks are routed to the combustor (COMB-1) where the vapors are combusted. Tank emission calculations are included in Appendix A. TANKS 4.0.9d printouts used to calculate tank emissions are included in Appendix B Equipment leak fugitive emissions (FUG-1) were estimated using estimated component counts (i.e., valves, flanges, etc.), TCEQ Technical Guidance Document: Equipment Leak Fugitives, and a gas analysis. Components subject to NSPS Subpart OOOOa (FUG-2) are monitored in accordance with EPA protocols. A percent reduction is applied to these components based on the monitoring frequency and leak definition. The calculations are provided in Appendix A. Emissions from truck loading operations were estimated using the AP-42 calculation methodology assuming a 70% control. The captured vapors are routed to the combustor (COMB-1). Additionally, flash emissions resulting from condensate truck loading from the pressurized storage tanks are controlled by COMB-1. The calculations are provided in Appendix A. Emissions from the flares (FLARE-1 and FLARE-2) were estimated using TCEQ flare factors and stream composition data from ProMax (for the amine units) and GRIGlyCalc (for the glycol dehydrator). The stream data for PROCESS-1 and PROCESS2 are taken from a gas sample. The process streams consist primarily of vapors from the closed drain vent systems and from pressurized NGL truck loading operations. The calculations are provided in Appendix A. Potential VOC emissions from compressor startups and blowdowns and miscellaneous venting were determined using engineering calculations and the representative gas analysis. Emissions from other MSS activities were calculated using TCEQ default parameters and assumptions. The calculations are provided in Appendix A. 4-2 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 5.0 GENERAL REQUIREMENTS As required by Section VI of the TCEQ Standard Permit Registration Form PI-1S, this section addresses Navitas' compliance with the applicable general requirements for the non-rule standard permit specified in Texas Health and Safety Code section 382.05195 and with the requirements specific to Non-Rule Air Quality Standard Permit for Oil and Gas Handling and Production Facilities. 5.1 Non-Rule Standard Permit Applicability Navitas will meet the conditions specified in this section, specifically: (a) Applicability Navitas is voluntarily registering the Facility under the new requirements in (a) - (k). The Facility is not located in the Barnett Shale Area. (b) Definitions and Scope This Facility is not a major stationary source under Nonattainment or Prevention of Significant Deterioration Review Definitions. (c)(1) Existing oil and gas sites (OGS) which are authorized by previous versions of this standard permit require registration unless otherwise specified. The Facility is not authorized by any previous versions of this Standard Permit. (c)(2)(A) All facilities shall not exceed the thresholds for major source or major modification as defined in 30 TAC 116.12, Nonattainment and Prevention of Significant Deterioration Review Definitions, and in Federal Clean Air Act 112(g) or 112(j). This Facility is not a major stationary source under Nonattainment or Prevention of Significant Deterioration Review Definitions. (c)(2)(B) All facilities shall comply with all applicable 40 Code of Federal Regulations (CFR), Parts 60, 61, and 63 requirements for New Source Performance Standards (NSPS), National Emission Standards for Hazardous Air Pollutants (NESHAP), and Maximum Achievable Control Technology (MACT). The engines at the Facility will comply with NSPS Subpart JJJJ requirements. By meeting the NSPS Subpart JJJJ requirements, the 5-1 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 engines will comply with all applicable MACT Subpart ZZZZ requirements. The heaters rated of 10 MMBtu/hr are subject to NSPS Subpart Dc. The glycol dehydrator (DEHY1) will comply with the record keeping requirements of MACT Subpart HH. The compressors will comply with NSPS Subpart OOOOa, and the fugitives will comply with NSPS Subpart OOOOa. The storage tanks will be certified to have emissions less than 6 TPY of VOC per tank and will not be subject to NSPS Subpart OOOOa. (c)(2)(C) All facilities shall comply with all applicable requirements of 30 TAC Chapters 111, Control of Air Pollution from Visible Emissions and Particulate Matter, 112, Control of Air Pollution from Sulfur Compounds, 113, Standards of Performance for Hazardous Air Pollutants and for Designated Facilities and Pollutants, 115, Control of Air Pollution from Volatile Organic Compounds, and 117, Control of Air Pollution from Nitrogen Compounds. Navitas will comply with the applicable sections of Chapter 111, Chapter 112, and Chapter 113. Chapter 115 and Chapter 117 are not applicable because of the Facility location. (c)(4) Co-located facilities previously authorized by, and continuing to meet, the conditions of a PBR must be incorporated into the standard permit and meet the requirements of paragraphs (e), (i), and (j). Previously authorized facilities that are unchanged do not need to meet the requirements of paragraph (h). There are no previously authorized facilities at the Facility. (d) Only specific facilities and groups of facilities may be evaluated for a standard permit, along with supporting infrastructure equipment and facilities. Only authorized facilities and equipment are authorized under this standard permit. (e)(1) All facilities which have the potential to emit air contaminants must be maintained in good working order and operate properly during facility operations. Each operator shall establish and maintain a program to replace, repair, and/or maintain facilities to keep them in good working order. Navitas will maintain the Facility in good working order and keep all required maintenance records. (e)(2) Any OGS facility shall be operated at least 50 feet from any property line or receptor (whichever is closer to the facility). 5-2 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 All new equipment authorized under this standard permit will be located more than 50 feet from the nearest property line. (e)(3) Engine and turbines shall meet the emission and performance standards listed in Table 6 in paragraph (m). The engines at the Facility will meet the requirements listed in Table 6. (e)(4) Open-topped tanks or ponds containing VOCs or H2S are allowed up to a PTE equal to 1 tpy of VOC and 0.1 tpy of H2S. No open-topped tanks or ponds will be located at the Facility; therefore, this subsection is not applicable. (e)(5) All process equipment and storage facilities individually must meet the requirements of BACT listed in Table 10 in paragraph (m). Any combination of process equipment and storage facilities with an uncontrolled PTE of equal to or greater than 25 tpy of VOC must also meet the requirements of Table 10, row titled "Combined Control Requirements". All equipment at the Facility will meet the applicable requirements of BACT in Table 10. (e)(6) All fugitive components shall meet the requirements of this subsection. The fugitive components are subject to a LDAR program because the uncontrolled potential to emit is < 10 TPY VOC. (e)(7) Tanks and vessels must utilize a paint color that minimizes the effects of solar heating (including, but not limited to, white or aluminum). All tanks located at the Facility will be painted a light color. (e)(8) All emission estimation methods including GRI-GLYCalc, AmineCalc, E&P Tanks, and Tanks 4.0, must be used with monitoring data generated in accordance with Table 8 in subsection (m). All emission estimation methods must also be used in a way that is consistent with protocols established by the commission or promulgated in federal regulations. Where control of emissions is relied upon to meet subsection (k) of this section, control monitoring is required. All emission estimation methods were prepared in accordance with this subsection. 5-3 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 (e)(9) Process reboilers, heaters, and furnaces that are also used for control of waste gas streams may claim 50 to 99% destruction efficiency for VOCs and H2S depending on the design and level of monitoring applied. The heaters are not used to control waste gas streams; therefore, this subsection is not applicable. (e)(10) Vapor recovery systems (VRSs) may claim up to 100% control. The control efficiency is based on whether it is a mechanical VRU (mVRU) or a liquid VRU (lVRU). The VRUs must meet the appropriate design, monitoring, and record-keeping in Table 7 and Table 8 in paragraph (m). No VRU will be located at the Facility; therefore, this subsection is not applicable. (e)(11) Flares used for control of emissions from production, planned MSS, emergency, or upset events may claim design destruction efficiency of 98% for VOCs and H2S and 99% for VOCs containing no more than three carbon atoms that contain no element other than carbon and hydrogen. The flares (FLARE-1, FLARE-2) will meet the requirements of this subsection. (e)(12) Thermal oxidation and vapor combustion control devices may claim design destruction efficiency from 90% to 99.9% for VOCs and H2S depending on the design and the level of monitoring and testing applied. The combustor (COMB-1) will meet the requirements of this subsection by meeting the flare requirements. (f) For all previous claims of this standard permit (or any previous version of this standard permit) existing authorized facilities, or group of facilities, are not required to meet the requirements of this standard permit, with the exception of planned MSS, until a renewal under the standard permit is submitted after January 31, 2015. There are no previous claims of this standard permit. (g) Any claim under this standard permit must comply with all applicable requirements of 30 TAC 116.610; 116.611, Registration to Use a Standard Permit; 116.614, Standard Permit Fees; and 116.615, General Conditions. This standard permit supersedes: the 5-4 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 notification requirements of 30 TAC 116.615, General Conditions; and the emission limitations of 30 TAC 116.610(a)(1), Applicability. The Facility will comply with all applicable requirements of 116.610, 116.611, 116.614, and 116.615. (h) Total maximum estimated registered or certified emissions shall meet the most stringent limits in this standard permit. All emissions estimates must be based on representative worst-case operations and planned MSS activities. The emissions estimated represented in this standard permit reflect the worse-case operations for the Facility. (i)(1) Prior to January 5, 2012, representations and registration of planned MSS is voluntary, but if represented, must meet the applicability limits of this standard permit. After January 5, 2012, all emissions from planned MSS activities and facilities must be considered for compliance with applicable limits of this standard permit unless otherwise specified in (b)(7). This standard permit may not be used at a site or for facilities authorized under 30 TAC 116.111 if planned MSS has already been authorized under that permit. All planned MSS emissions will comply with the applicable limits of this standard permit. (i)(2) As specified, releases of air contaminants during, or as result of, planned MSS must be quantified and meet the emission limits in this standard permit, as applicable. All planned MSS emissions meet the emission limits of this standard permit. (i)(3) Other planned MSS activities authorized by this standard permit are limited. These planned MSS activities require only recordkeeping of the activity. There are no other planned MSS emissions from the Facility. (i)(4) Engine/compressor start-ups associated with preventative system shutdown activities have the option to be authorized as part of typical operations. These emissions are included in this application. (j) All records shall be maintained at a site in written or electronic form and be readily available to the agency or local air pollution control program with jurisdiction upon request. All required records must be 5-5 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 kept at the facility site. If the facility normally operates unattended, records must be maintained at an office within Texas having day-today operational control of the plant site. Navitas will maintain records at the Facility or a nearby field office. (k) All impact evaluations must be completed on a contaminant-by- contaminant basis for only any net emissions increases resulting from a project and must meet the following as appropriate: (A) Compliance with state or federal ambient air standards shall be demonstrated for NO2, SO2, and H2S at any property-line within 1 mile of a project; (B) Compliance with hourly effects screening levels (ESLs) for benzene and annual ESL for benzene, shall be determined at the nearest receptor within 1 mile of a project. There is not a receptor within one (1) mile of the Facility. Therefore, a benzene ESL review is not required. The site-wide H2S emission rate is greater than 0.025 lb/hr, the SO2 emission rate is greater than 2.0 lb/hr, and the NOx emission rate is greater than 4.0 lb/hr; therefore, impacts evaluations for NOx, H2S, and SO2 are required. The SCREEN3 modeling printouts are included in Appendix C. The modeling demonstrates compliance with the applicable state and federal air quality standards for NO2, H2S, and SO2. 5.2 30 TAC 116.610 Applicability Navitas will meet the conditions specified in this section, specifically: 116.610 (a)(1) Any project that results in a net increase in emissions of air contaminants from the project other than carbon dioxide, water, nitrogen, methane, ethane, hydrogen, oxygen, or those for which a national ambient air quality standard has been established must meet the emission limitations of 106.261 of this title (relating to Facilities (Emission Limitations), unless otherwise specified by a particular standard permit. This section is not applicable to sites authorized under the Non-Rule Standard Permit. 116.610 (a)(2) Construction or operation of the project must be commenced prior to the effective date of a revision to this subchapter under which the project would no longer meet the requirements for a standard permit. This section is not applicable to sites authorized under the Non-Rule Standard Permit. 5-6 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 116.610 (a)(3) The proposed project must comply with the applicable provisions of the Federal Clean Air Act (FCAA), 111 (concerning New Source Performance Standards) as listed under 40 Code of Federal Regulations (CFR) Part 60, promulgated by the United States Environmental Protection Agency (EPA). The Facility will comply with the applicable requirements of Part 60 NSPS Subpart Kb, Dc, JJJJ and Subpart OOOOa. 116.610 (a)(4) The proposed project must comply with the applicable provisions of FCAA, 112 (HAPS) as listed under 40 CFR Part 61. 40 CFR 61 requirements relating to hazardous air pollutants do not apply to this Facility, thus compliance is not required. 116.610 (a)(5) The proposed project must comply with the applicable maximum achievable control technology standards as listed under 40 CFR Part 63. The Facility is not a major source of HAPs but is classified as an area source. The engines at the Facility are subject to MACT ZZZZ and will show compliance by meeting the requirements of NSPS Subpart JJJJ. The glycol dehydrator is subject to MACT Subpart HH recordkeeping requirements. 116.610 (a)(6) If subject to Chapter 101, Subchapter H, Division 3 of this title (relating to Mass Emissions Cap and Trade Program) the proposed facility, group of facilities, or account must obtain allocation to operate. This project is not subject to Chapter 101, Subchapter H, Division 3 (Mass Emissions Cap and Trade Program). 116.610 (b) Any project that constitutes a new major stationary source or major modification as defined in 116.12 of this title (relating to Nonattainment and Prevention of Significant Deterioration Review Definitions) is subject to the requirements of 116.110 of this title (relating to Applicability) rather than this subchapter. This Facility is not a major stationary source under Nonattainment or Prevention of Significant Deterioration Review Definitions. 116.610 (c) Persons may not circumvent by artificial limitations the requirements of 116.110 of this title. Navitas will not circumvent the requirements of 116.110. 5-7 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 116.610 (d) Any project involving a proposed affected source (as defined in 116.15(1) of this title (relating to Section 112(g) Definitions)) shall comply with all applicable requirements under Subchapter E of this chapter (relating to Hazardous Air Pollutants: Regulations Governing Constructed or Reconstructed Major Sources (FCAA, 112(g), 40 CFR Part 63)). Affected sources subject to Subchapter E of this chapter may use a standard permit under this subchapter only if the terms and conditions of the specific standard permit meet the requirements of Subchapter E of this chapter. This project does not involve an affected source, as defined in 116.15(1) of this title; therefore, this section is not applicable. 5.3 30 TAC 116.611 Registration to Use a Standard Permit Navitas will meet the conditions specified in this section, specifically: 116.611(a) If required, registration to use a standard permit shall be sent be certified mail, return receipt requested, or hand delivered to the executive director, the appropriate commission regional office, and any local air program with jurisdiction, before a standard permit can be used. The registration must be submitted on the required form and must document compliance with the requirements of this section. The standard permit shall be prepared and submitted in accordance with this section and the requirements of the Non-Rule Standard Permit. 116.611(b) Construction may begin any time after receipt of written notification from the executive director that there are no objections or 45 days after receipt by the executive director of the registration, whichever occurs first, except where a different time period is specified for a particular standard permit. This section is not applicable to sites authorized under the Non-Rule Standard Permit. 116.611(c) In order to avoid applicability of Chapter 122 of this title (relating to Federal Operating Permits), a certified registration shall be submitted. A PI-1S form is being submitted with this registration. 5-8 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 5.4 30 TAC 116.614 Standard Permit Fees Navitas will meet the conditions specified in this section by submitting the standard permit fee of $900. 5.5 30 TAC 116.615 General Conditions Navitas will meet the conditions specified in this section, specifically: 116.615(1) Protection of public health and welfare The emissions from the Facility comply with all applicable rules and regulations of the TCEQ. 116.615(2) Standard permit representations Navitas understands that the representations made in this application become conditions upon which the Facility operates. 116.615(3) Standard permit in lieu of permit amendment The Facility does not operate under any permits authorized under 116.110. 116.615(4) Construction progress The notification requirements do not apply to sites authorized under the Non-Rule Standard Permit. 116.615(5) Start-up notification The notification requirements do not apply to sites authorized under the Non-Rule Standard Permit. 116.615(6) Sampling requirements If sampling is required, Navitas will contact the Midland Regional Office to obtain the necessary forms and procedures and to obtain approval of the testing procedures. 116.615(7) Equivalency of methods Navitas will contact the Midland Regional Office if alternate methods of controls, testing, or monitoring are proposed. 5-9 TCEQ Non-Rule Standard Permit Registration Newberry Gas Plant September 2019 116.615(8) 116.615(9) 116.615(10) 116.615(11) Recordkeeping Navitas will maintain sufficient records to demonstrate compliance with this standard permit. Maintenance of emission control Navitas will maintain all air pollution emission capture and abatement equipment in good working order and will operate it properly during normal facility operations. Compliance with rules The Facility will comply with all applicable air quality rules. Distance limitations, setbacks, and buffer zones This section is not applicable to sites authorized under the Non-Rule Standard Permit. 5-10 APPENDICES APPENDIX A EMISSION CALCULATIONS A-1 TABLE 1 POTENTIAL EMISSIONS SUMMARY NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Emissions Source Updated/New Sources +S&DWHUSLOODU% +S&DWHUSLOODU% +S&DWHUSLOODU% +S&DWHUSLOODU% +S&DWHUSLOODU% +S&DWHUSLOODU% +S&DWHUSLOODU*$ +S&DWHUSLOODU*$ +S&DWHUSLOODU*$ +S&DWHUSLOODU*$ +S:DXNHVKD*6, +S:DXNHVKD*6, +S:DXNHVKD*6, +S:DXNHVKD*6, +S&DWHUSLOODU +S&DWHUSLOODU +S&DWHUSLOODU $PLQH5HERLOHU+RW2LO+HDWHU00%78KU 0ROH6LHYH5HJHQHUDWLRQ*DV+HDWHU00%78KU &U\R7ULP5HERLOHU+RW2LO+HDWHU00%78KU &RPER+RW2LO+HDWHU00%78KU &RPER+RW2LO+HDWHU00%78KU 0ROH6LHYH5HJHQHUDWLRQ*DV+HDWHU00%78KU $PLQH8QLW9HQW $PLQH8QLW9HQW 3ODQW)ODUH *O\FRO'HK\GUDWLRQ8QLW'(+< 3ODQW)ODUH 7DQN9HQW&RPEXVWRU 6ORS2LO6WRUDJH7DQNEEO 6ORS2LO6WRUDJH7DQNEEO &RQGHQVDWH6WRUDJH7DQNEEO &RQGHQVDWH6WRUDJH7DQNEEO 6ORS2LO6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO *DVROLQH6WRUDJH7DQNJDO 'LHVHO6WRUDJH7DQNJDO 7UXFN/RDGLQJ 1RQ0RQLWRUHG6LWH)XJLWLYHV 0RQLWRUHG6LWH)XJLWLYHV %ORZGRZQ9HQW 2WKHU9HQWLQJ (QJLQH6WDUWHU9HQW 066(PLVVLRQV FIN/EPN & & & & & & & & & & &1 &1 &1 &1 & & & + + + + + + $0,1( $0,1( )/$5( '(+< )/$5( &20% 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. / )8* )8* 9(17 9(17 9(17 066 NOx lb/hr) T/yr) VOC lb/hr) T/yr) CO lb/hr) T/yr) PM10/PM2.5 lb/hr) T/yr) SO2 lb/hr) T/yr) H2S lb/hr) T/yr) Benzene lb/hr) T/yr) Formaldehyde lb/hr) T/yr Other HAPs1 lb/hr) T/yr) Total Facility Emissions Plus Formaldehyde 48.71 213.33 231.83 237.98 47.15 206.52 3.89 14.05 11.61 50.86 0.27 2.00 8.75 1.09 1.44 Total 233.83 246.73 1RWHV 2WKHU+$3VLQFOXGHVEHQ]HQH 7KH158PD\EHSRZHUHGE\&&DQGRU&2XWRIWKHWKUHHHQJLQHVRQO\WZRZLOOHYHURSHUDWHDWDJLYHQWLPH&&DQG&ZLOOQRWRSHUDWHPRUHWKDQDFRPELQHGKRXUVDQQXDOO\ &HPLVVLRQVDUHLQFOXGHGLQ&DQG&HPLVVLRQWRWDOV 4.08 2.00 8.75 0.62 2.00 1HZEHUU\&DOFVB[OV[ $ 6XPPDU\ Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 2 POTENTIAL EMISSIONS FROM CATERPILLAR 3516B (C-1680) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWD (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHOHDQEXUQHQJLQHV 7KH62IDFWRULVVFDOHGWRSSP+6 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ & Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 3 POTENTIAL EMISSIONS FROM CATERPILLAR 3516B (C-1690) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWD (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHOHDQEXUQHQJLQHV 7KH62IDFWRULVVFDOHGWRSSP+6 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ & Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 4 POTENTIAL EMISSIONS FROM CATERPILLAR G3516B (C-1710) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWD (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHOHDQEXUQHQJLQHV 7KH62IDFWRULVVFDOHGWRSSP+6 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ & Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 5 POTENTIAL EMISSIONS FROM CATERPILLAR G3516B (C-1720) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWD (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHOHDQEXUQHQJLQHV 7KH62IDFWRULVVFDOHGWRSSP+6 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ & Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 6 POTENTIAL EMISSIONS FROM CATERPILLAR G3516B (C-1730) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWD (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHOHDQEXUQHQJLQHV 7KH62IDFWRULVVFDOHGWRSSP+6 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ & Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 7 POTENTIAL EMISSIONS FROM CATERPILLAR G3516B (C-1740) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWD (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHOHDQEXUQHQJLQHV 7KH62IDFWRULVVFDOHGWRSSP+6 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ & Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 8 POTENTIAL EMISSIONS FROM CATERPILLAR G3608A4 (C-1750) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWD (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHOHDQEXUQHQJLQHV 7KH62IDFWRULVVFDOHGWRSSP+6 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ & Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 9 POTENTIAL EMISSIONS FROM CATERPILLAR G3608A4 (C-1760) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWD (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHOHDQEXUQHQJLQHV 7KH62IDFWRULVVFDOHGWRSSP+6 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ & Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 10 POTENTIAL EMISSIONS FROM CATERPILLAR G3608A4 (C-1770) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWD (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHOHDQEXUQHQJLQHV 7KH62IDFWRULVVFDOHGWRSSP+6 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ & Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 11 POTENTIAL EMISSIONS FROM CATERPILLAR G3608A4 (C-1780) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWD (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHOHDQEXUQHQJLQHV 7KH62IDFWRULVVFDOHGWRSSP+6 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ & Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 12 POTENTIAL EMISSIONS FROM WAUKESHA 5794GSI (C-171N) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWDZLWKWKHRSHUDWLRQRID16&5 (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHULFKEXUQHQJLQHV 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ &1 Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 13 POTENTIAL EMISSIONS FROM WAUKESHA 5794GSI (C-172N) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWDZLWKWKHRSHUDWLRQRID16&5 (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHULFKEXUQHQJLQHV 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ &1 Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 14 POTENTIAL EMISSIONS FROM WAUKESHA 5794GSI (C-173N) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWDZLWKWKHRSHUDWLRQRID16&5 (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHULFKEXUQHQJLQHV 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ &1 Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 15 POTENTIAL EMISSIONS FROM WAUKESHA 5794GSI (C-174N) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWDZLWKWKHRSHUDWLRQRID16&5 (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHULFKEXUQHQJLQHV 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ &1 Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 16 POTENTIAL EMISSIONS FROM CATERPILLAR 3606 (C-181) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWD (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHOHDQEXUQHQJLQHV 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ & Pollutant 12[ 92& &2 62 30 +&+2 %HQ]HQH Horsepower TABLE 17 POTENTIAL EMISSIONS FROM CATERPILLAR 3606 (C-182, C-183) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Operating Hours Emission Factors grams/Hp-hr) 1 lb/MMBtu) 2 Potential Emission Rate lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVIRU12[92&IRUPDOGHK\GHDQG&2DUHEDVHGRQPDQXIDFWXUHUGDWD (PLVVLRQIDFWRUVIRU6230DQGEHQ]HQHREWDLQHGIURP$37DEOHVWURNHOHDQEXUQHQJLQHV 3RWHQWLDOHPLVVLRQVEDVHGRQHPLVVLRQIDFWRUVPD[LPXPKRUVHSRZHUIXHOFRQVXPSWLRQUDWHRI%WX+SKU DQGKRXUVRIRSHUDWLRQSHU\HDU 1HZEHUU\&DOFVB[OV[ $ & & Pollutant +6 3URSDQH ,VREXWDQH Q%XWDQH ,VRSHQWDQH Q3HQWDQH Q+H[DQH 2WKHUKH[DQHV +HSWDQH %HQ]HQH 7ROXHQH (WK\OEHQ]HQH ;\OHQH 2FWDQH 1RQDQH 7RWDO+$3V 7RWDO92& TABLE 18 POTENTIAL EMISSIONS FROM AMINE UNIT VENT (AMINE) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Potential Uncontrolled Acid Vent1 T/yr Potential Uncontrolled Flash Tank1 T/yr % Capture2 Total Emissions 3 lb/hr T/yr 1RWHV 3RWHQWLDOHPLVVLRQVEDVHGRQ3520$;H[WHQGHGJDVDQDO\VLV006&)' &DSWXUHZLOOEHDFKLHYHGE\URXWLQJWKHHPLVVLRQVWRWKHIODUH)/$5($VVXPHVRIWKH DPLQHDFLGYHQWDQGIODVKWDQNYDSRUVDUHFDSWXUHGDQGVHQWWRWKHIODUHDQGRIWKHYDSRUV DUHHPLWWHGDWWKHDPLQHXQLW &RQWUROOHG(PLVVLRQV $FLG9HQW)ODVK7DQN[&RQWURO(IILFLHQF\ 1HZEHUU\&DOFVB[OV[ $ $PLQH Pollutant +6 3URSDQH ,VREXWDQH Q%XWDQH ,VRSHQWDQH Q3HQWDQH Q+H[DQH 2WKHUKH[DQHV +HSWDQH %HQ]HQH 7ROXHQH (WK\OEHQ]HQH ;\OHQH 2FWDQH 1RQDQH 7RWDO+$3V 7RWDO92& TABLE 19 POTENTIAL EMISSIONS FROM AMINE UNIT 2 VENT (AMINE2) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Potential Uncontrolled Acid Vent1 T/yr Potential Uncontrolled Flash Tank1 T/yr % Capture2 Total Emissions 3 lb/hr T/yr 1RWHV 3RWHQWLDOHPLVVLRQVEDVHGRQ3520$;H[WHQGHGJDVDQDO\VLV006&)' &DSWXUHZLOOEHDFKLHYHGE\URXWLQJWKHHPLVVLRQVWRWKHIODUH)/$5($VVXPHVRIWKH DPLQHDFLGYHQWDQGIODVKWDQNYDSRUVDUHFDSWXUHGDQGVHQWWRWKHIODUHDQGRIWKHYDSRUV DUHHPLWWHGDWWKHDPLQHXQLW &RQWUROOHG(PLVVLRQV $FLG9HQW)ODVK7DQN[&RQWURO(IILFLHQF\ 1HZEHUU\&DOFVB[OV[ $ $PLQH TABLE 20 POTENTIAL EMISSIONS SUMMARY GLYCOL DEHYDRATION UNIT VENT (DEHY1) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Pollutant QKH[DQH EHQ]HQH WROXHQH HWK\OEHQ]HQH [\OHQH 7RWDO+$36 7RWDO92& Potential Emissions 1 Still Vent Flash Tank T/yr T/yr Potential Emissions 1 T/yr Still Vent Control Efficiency % Flash Tank Control Efficiency % Safety Factor % Total Emission Rates 2 lb/hr T/yr 1RWHV 3RWHQWLDO92&DQG+$3HPLVVLRQVEDVHGRQ*5,*/<&DOFH[WHQGHGJDVDQDO\VLVPD[LPXPJO\FROFLUFXODWLRQUDWHJSP DQGWKHPD[LPXPJDVWKURXJKSXW006&)' 7KHJO\FROGHK\GUDWRUVWLOOYHQWLVURXWHGDFRQGHQVHUDQGWKHQWRDIODUHUHVXOWLQJLQDWOHDVWFRQWURORIYDSRUV7KHIODVKWDQNLVURXWHGWRDIODUHUHVXOWLQJLQ DWOHDVWFRQWURORIYDSRUV 1HZEHUU\&DOFVB[OV[ $ '(+< Flare Pilot Rating: 15.0 MMBtu/hr TABLE 21 POTENTIAL EMISSIONS SUMMARY PLANT FLARE (FLARE-1) FIN: AMINE, EPN: FLARE-1 FIN: PROCESS-1, EPN: FLARE-1 NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS I t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lare Pilot Rating: 15.0 MMBtu/hr TABLE 22 POTENTIAL EMISSIONS SUMMARY PLANT FLARE (FLARE-2) FIN: AMINE-2, EPN: FLARE-2 FIN: DEHY, EPN: FLARE-2 FIN: PROCESS-2, EPN: FLARE-2 NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS I t---------+----------+------i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ollutant 12[ 92& &2 62 30 %HQ]HQH Max Firing Rate MMBtu/hr) TABLE 23 POTENTIAL EMISSIONS FROM AMINE REBOILER HOT OIL HEATER (H-1) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Gas Heating Value MMBtu/scf) Emission Factor lb/MMBTU) 1 Emission Factor lb/MMSCF) 1 Potential Emission Rates 2 lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVREWDLQHGIURPPDQXIDFWXUHUVSHFVKHHWIRU12;&292&30DQG$37DEOH WKURXJKIRUFRPPHUFLDOERLOHUVIRU62DQGEHQ]HQH 3RWHQWLDOHPLVVLRQVEDVHGRQ$3HPLVVLRQIDFWRUVPD[LPXPILULQJUDWHRI00%WXKU %WXVFIIXHOKHDWLQJYDOXHDQGKRXUVSHU\HDURIRSHUDWLRQ 1HZEHUU\&DOFVB[OV[ $ + Pollutant 12[ 92& &2 62 30 %HQ]HQH TABLE 24 POTENTIAL EMISSIONS FROM MOLE SEIVE REGENERATION GAS HEATER (H-2) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Max Firing Rate MMBtu/hr) Gas Heating Value MMBtu/scf) Emission Factor lb/MMSCF) 1 Potential Emission Rates 2 lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVREWDLQHGIURP$37DEOHWKURXJKIRUFRPPHUFLDOERLOHUV 3RWHQWLDOHPLVVLRQVEDVHGRQ$3HPLVVLRQIDFWRUVPD[LPXPILULQJUDWHRI00%WXKU %WXVFIIXHOKHDWLQJYDOXHDQGKRXUVSHU\HDURIRSHUDWLRQ 1HZEHUU\&DOFVB[OV[ $ + Pollutant 12[ 92& &2 62 30 %HQ]HQH TABLE 26 POTENTIAL EMISSIONS FROM CRYO TRIM REBOILER HOT OIL HEATER (H-4) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Max Firing Rate MMBtu/hr) Gas Heating Value MMBtu/scf) Emission Factor lb/MMSCF) 1 Potential Emission Rates 2 lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVREWDLQHGIURP$37DEOHWKURXJKIRUFRPPHUFLDOERLOHUV 3RWHQWLDOHPLVVLRQVEDVHGRQ$3HPLVVLRQIDFWRUVPD[LPXPILULQJUDWHRI00%WXKU %WXVFIIXHOKHDWLQJYDOXHDQGKRXUVSHU\HDURIRSHUDWLRQ 1HZEHUU\&DOFVB[OV[ $ + Pollutant 12[ 92& &2 62 30 %HQ]HQH Max Firing Rate MMBtu/hr) TABLE 27 POTENTIAL EMISSIONS FROM COMBO HOT OIL HEATER 1 (H-5) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Gas Heating Value MMBtu/scf) Emission Factor lb/MMBTU) 1 Emission Factor lb/MMSCF) 1 Potential Emission Rates 2 lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVREWDLQHGIURPPDQXIDFWXUHUVSHFVKHHWIRU12;&292&30DQG$37DEOH WKURXJKIRUFRPPHUFLDOERLOHUVIRU62DQGEHQ]HQH 3RWHQWLDOHPLVVLRQVEDVHGRQ$3HPLVVLRQIDFWRUVPD[LPXPILULQJUDWHRI00%WXKU %WXVFIIXHOKHDWLQJYDOXHDQGKRXUVSHU\HDURIRSHUDWLRQ 1HZEHUU\&DOFVB[OV[ $ + Pollutant 12[ 92& &2 62 30 %HQ]HQH Max Firing Rate MMBtu/hr) TABLE 28 POTENTIAL EMISSIONS FROM COMBO HOT OIL HEATER 2 (H-6) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Gas Heating Value MMBtu/scf) Emission Factor lb/MMBTU) 1 Emission Factor lb/MMSCF) 1 Potential Emission Rates 2 lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVREWDLQHGIURPPDQXIDFWXUHUVSHFVKHHWIRU12;&292&30DQG$37DEOH WKURXJKIRUFRPPHUFLDOERLOHUVIRU62DQGEHQ]HQH 3RWHQWLDOHPLVVLRQVEDVHGRQ$3HPLVVLRQIDFWRUVPD[LPXPILULQJUDWHRI00%WXKU %WXVFIIXHOKHDWLQJYDOXHDQGKRXUVSHU\HDURIRSHUDWLRQ 1HZEHUU\&DOFV $ + Pollutant 12[ 92& &2 62 30 %HQ]HQH TABLE 29 POTENTIAL EMISSIONS FROM MOLE SIEVE REGENERATION GAS HEATER 2 (H-7) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Max Firing Rate MMBtu/hr) Gas Heating Value MMBtu/scf) Emission Factor lb/MMSCF) 1 Potential Emission Rates 2 lb/hr) T/yr) 1RWHV (PLVVLRQIDFWRUVREWDLQHGIURP$37DEOHWKURXJKIRUFRPPHUFLDOERLOHUV 3RWHQWLDOHPLVVLRQVEDVHGRQ$3HPLVVLRQIDFWRUVPD[LPXPILULQJUDWHRI00%WXKU %WXVFIIXHOKHDWLQJYDOXHDQGKRXUVSHU\HDURIRSHUDWLRQ 1HZEHUU\&DOFVB[OV[ $ + Source 6ORS2LO6WRUDJH7DQNEEO 6ORS2LO6WRUDJH7DQNEEO &RQGHQVDWH6WRUDJH7DQNEEO &RQGHQVDWH6WRUDJH7DQNEEO 6ORS2LO6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO 2SHQ'UDLQ6WRUDJH7DQNEEO *DVROLQH6WRUDJH7DQNJDO 'LHVHO6WRUDJH7DQNJDO FIN TK-1 TK-2 TK-3 TK-4 TK-5 TK-6 TK-7 TK-8 TK-9 TK-10 TK-11 TK-12 TK-13 TK-14 TK-15 TK-16 TK-17 TK-18 TK-19 Annual Throughput 1 gallons/year) TABLE 30 POTENTIAL EMISSIONS FROM STORAGE TANK (TK-1 - TK-17) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Potential VOC Emissions 1 Tank Capacity gallons) Annual Breathing Losses2 lbs) Annual Working Losses2 lbs) Floating Roof Losses3 T/yr) Combustor Capture Efficiency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enzene Emissions5 lb/hr) T/yr) 0.01 0.03 VOC Emissions5 lb/hr) T/yr) 1.69 7.39 1HZEHUU\&DOFVB[OV[ $ 7$1.6 TABLE 31 POTENTIAL EMISSIONS SUMMARY - CONDENSATE STORAGE TANKS NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Identification - Internal Floating Roof Tanks 7DQN,' 'HVFULSWLRQ 7KURXJKSXW%3' D Tank Dimensions 'LDPHWHUIW 9ROXPHJDO 7XUQRYHUV 6HOI6XSS5RRI"\Q 1RRI&ROXPQV (II&RO'LDPIW 1HW7KURXJKSXWJDO\U Paint Characteristics ,QWHUQDO6KHOO&RQGLWLRQ 6KHOO&RORU6KDGH 6KHOO&RQGLWLRQ 5RRI&RORU6KDGH 5RRI&RQGLWLRQ 0HWHRURORJLFDO'DWD Rim-Seal System 3ULPDU\6HDO 6HFRQGDU\6HDO Deck Characteristics 'HFN)LWWLQJ&DWHJRU\ 'HFN7\SH Tank Contents 0L[WXUH&RPSRQHQW Tank VOC Emissions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aterial Name FIN &RQGHQVDWH / :DWHU / Saturation Factor 1 S) True Vapor Pressure 2 P) Avg Max Molecular Weight of Vapors 2 (M) lb/lb-mole) Temp of Loaded Liquid 2 F) Max Temp of Loaded Liquid (F) Emission Factor 1 (lb VOC/103 gal) Avg Max Annual Throughput 3 (gals) Estimated Hourly Throughput 3 gal) TOTAL Weight Percent of VOC in HC Vapors %) 2.00 Total Uncontrolled VOC Emissions lb/hr) 4 T/yr) 5 50.97 123.14 Control Efficiency 7 %) Total Uncontrolled VOC Emissions lb/hr) 8 T/yr) 9 TOTAL 15.65 37.08 Total VOC Emissions to COMB lb/hr) 10 T/yr) 35.68 86.20 %Benzene 11 Total Benzene Emissions lb/hr) 12 T/yr) 13 0.191 0.461 %H2S 11 Total H2S Emissions lb/hr) 12 T/yr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nput Parameters for Emission Calculations 'HVLJQHG)LULQJ5DWH $YHUDJH+HDWLQJ9DOXHRI*DV%XUQHG 2SHUDWLQJ+RXUVSHU<HDU TABLE 33 ESTIMATED EMISSIONS FROM COMBUSTOR (COMB-1) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS 00%WXKU %WX&XELF)HHW +UV<U Calculated Inputs (VWLPDWHG1DWXUDO*DV8VDJH 92&)URP6WRUDJH7DQNV 92&)URP7UXFN/RDGLQJ 92&)URP3UHVVXUL]HG7UXFN/RDGLQJ 00&XELF)HHW+U OEKU OEKU OEKU 1111 I I I I I I II POLLUTANT EMISSION FACTOR NATURAL GAS FEED RATE PER HOUR HOURLY EMISSIONS ANNUAL OPERATING HOURS WEIGHT CONVERSION ANNUAL EMISSIONS &2 OE&2 [ 00&XELF)HHW 00FXIW1DWXUDO*DV%XUQHG +U OE&2 +RXUV [ +U \U WRQ OEV WRQV&2 \U 12[ OE12[ [ 00&XELF)HHW 00FXIW1DWXUDO*DV%XUQHG +U OE12[ +RXUV [ +U \U WRQ OEV WRQV12[ \U 30 OE30 [ 00&XELF)HHW 00FXIW1DWXUDO*DV%XUQHG +U OE30 +RXUV [ +U \U WRQ OEV WRQV30 \U 62 OE62 [ 00&XELF)HHW 00FXIW1DWXUDO*DV%XUQHG +U OE62 +RXUV [ +U \U WRQ OEV WRQV62 \U %HQ]HQH OE%HQ]HQH [ 00&XELF)HHW 00FXIW1DWXUDO*DV%XUQHG +U OE%HQ]HQH +RXUV [ +U \U WRQ OEV WRQV%HQ]HQH \U 92& OE92& [ 00&XELF)HHW 00FXIW1DWXUDO*DV%XUQHG +U OE92& +RXUV [ +U \U WRQ OEV WRQV92& \U 92& 92& OE92& KU OE92& KU [ 'HVWUXFWLRQ (IILFLHQF\ OE92& +RXUV [ +U \U [ 'HVWUXFWLRQ (IILFLHQF\ OE92& +RXUV [ +U \U Total = 2.23 lb VOC Hr WRQ WRQV92& OEV \U WRQ WRQV92& OEV \U Total = 9.78 tons VOC yr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omponent Type 9DOYHV )ODQJHV &RPSUHVVRU6HDOV 5HOLHI9DOYHV 9DOYHV )ODQJHV 3XPS6HDOV 5HOLHI9DOYHV Totals: Type of Service 1 *DV9DSRU *DV9DSRU *DV9DSRU *DV9DSRU /LJKW/LTXLG /LJKW/LTXLG /LJKW/LTXLG /LJKW/LTXLG --- Number of Components 1 1,800 Oil and Gas Production Emission Factors lb/hr-component) 2 --- Percent VOC 3 --- 1RWHV 1XPEHURIHDFKFRPSRQHQWDQGW\SHRIVHUYLFHHVWLPDWHGEDVHGRQDVLPLODUVWDWLRQ (PLVVLRQIDFWRUVEDVHGRQ(3$ VQDWXUDOJDVSURFHVVLQJIDFWRUVIRUSURFHVVSLSLQJIXJLWLYHHPLVVLRQV 3HUFHQW92&DQG+ 6IRU*DV9DSRUVHUYLFHEDVHGRQDIDFLOLW\JDVDQDO\VLVUHIHUWR7DEOH (PLVVLRQUDWHVEDVHGRQKRXUVRIRSHUDWLRQSHU\HDU Percent H2S 3 Percent Benzene 3 Potential VOC Emission Rates 4 lb/hr) T/yr) 1.02 4.49 Potential H2S Emission Rates 4 lb/hr) T/yr) 0.01 0.01 Potential Benzene Emission Rates 4 lb/hr) T/yr) 0.01 0.01 1HZEHUU\&DOFVB[OV[ $ )8* TABLE 35 POTENTIAL EMISSIONS SUMMARY NSPS OOOOa MONITORED PROCESS PIPING FUGITIVES (FUG2) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Component Type 9DOYHV &RQQHFWRUV )ODQJHV &RPSUHVVRU6HDOV 5HOLHI9DOYHV 9DOYHV &RQQHFWRUV )ODQJHV 3XPS6HDOV 5HOLHI9DOYHV Totals: Type of Service 1 *DV9DSRU *DV9DSRU *DV9DSRU *DV9DSRU *DV9DSRU /LJKW/LTXLG /LJKW/LTXLG /LJKW/LTXLG /LJKW/LTXLG /LJKW/LTXLG --- Number of Components 1 10,091 Oil and Gas Production Emission Factors lb/hr-component) 2 --- Control Effectiveness 3 --- Percent VOC 4 --- Percent H2S 4 Percent Benzene 4 Potential VOC Emission Rates 5 lb/hr) T/yr) 0.74 3.24 Potential H2S Emission Rates 5 lb/hr) T/yr) 0.01 0.01 1RWHV 1XPEHURIHDFKFRPSRQHQWDQGW\SHRIVHUYLFHHVWLPDWHGEDVHGRQ/'$5PRQLWRULQJIRUDVLPLODUVLWH (PLVVLRQIDFWRUVEDVHGRQ(3$ VQDWXUDOJDVSURFHVVLQJIDFWRUVIRUSURFHVVSLSLQJIXJLWLYHHPLVVLRQV &RQWUROHIIHFWLYHQHVVEDVHGRQIXJLWLYHHPLVVLRQPRQLWRULQJUHTXLUHGE\16366XESDUW2222LQDFFRUGDQFHZLWK(3$ V/HDN'HWHFWLRQDQG5HSDLU$%HVW3UDFWLFHV*XLGHDQG3URWRFROIRU(TXLSPHQW/HDN(PLVVLRQ(VWLPDWHV 3HUFHQW92&DQG+6IRU*DV9DSRUVHUYLFHEDVHGRQDIDFLOLW\JDVDQDO\VLVUHIHUWR7DEOH (PLVVLRQUDWHVEDVHGRQKRXUVSHU\HDURIRSHUDWLRQ Potential Benzene Emission Rates 5 lb/hr) T/yr) 0.01 0.01 1HZEHUU\&DOFVB[OV[ $ )8* TABLE 36 POTENTIAL EMISSIONS FROM BLOWDOWNS (VENT-1) NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS 9ROXPHRI*DV0&)+U 9ROXPHRI*DV0&)<U 0ROH 1 &2 +6 & & & ,& 1& ,& 1& & %HQ]HQH 7RWDO 1XPEHURI &RPSUHVVRUV BLOWDOWN RATES %ORZGRZQ5DWHVDQG*DV&RPSRVLWLRQ 0&)+U &X)W OEVKU 0&)<U &X)W OEV\U 7RWDO92&OEKU 7RWDO92&OE\USHUFRPSUHVVRU 7RWDO92&7\U 1RWHV 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ngine Power @ 100% Load @ 75% Load Engine Speed Max Altitude @ Rated Torque and 38C (100F) Speed Turndown @ Max Altitude, Rated Torque, and 38C (100F) SCAC Temperature Emissions* NOx CO CO2 VOC** Fuel Consumption*** @ 100% Load @ 75% Load Heat Balance Heat Rejection to Jacket Water @ 100% Load @ 75% Load Heat Rejection to Aftercooler @ 100% Load @ 75% Load Heat Rejection to Exhaust LHV to 25C (77 F) @ 100% Load @ 75% Load Exhaust System Exhaust Gas Flow Rate @ 100% Load @ 75% Load Exhaust Stack Temperature @ 100% Load @ 75% Load Intake System Air Inlet Flow Rate @ 100% Load @ 75% Load Gas Pressure DM5137-03 1368 (1835) 1026 (1376) 1000 1219.2 (4000) 20 43 (110) .94 (0.7) 3.4 (2.5) 589 (439) 0.8 (0.6) 9.34 (6600) 9.73 (6876) 321 (18,281) 278 (15,801) 269 (15,297) 149 (8466) 1334 (75,883) 1061 (60,310) 346.48 (12,236) 273.97 (9675) 454 (850) 471 (880) 133.29 (4707) 102.96 (3636) 295-324 (42.8-47) DM5433-05 1324 (1775) 993 (1331) 1000 609.6 (2000) 23 54 (130) .94 (0.7) 3.4 (2.5) 590 (440) 0.81 (0.6) 9.37 (6620) 9.77 (6903) 314 (17,894) 270 (15,400) 235 (13,350) 128 (7300) 1320 (75,085) 1047 (59,560) 339.92 (12,004) 269.49 (9517) 464 (867) 477 (891) 129.01 (4556) 100.50 (3549) 295-324 (42.8-47) B-5 G3606 LE GAS PETROLEUM ENGINE 1324-1413 bkW (1775-1895 bhp) GAS PETROLEUM ENGINE 4638.4 mm (182.61 in) 1744.2 mm (68.67 in) 2921.1 mm (115.00 in) Length Width Height Shipping Weight DIMENSIONS mm (in.) mm (in.) mm (in.) kg (lb) 4638.4 (182.61) 1744.2 (68.67) 2921.1 (115.00) 15,676 (34,560) Note: General configuration not to be used for installation. See general dimension drawings for detail. RATING DEFINITIONS AND CONDITIONS Engine performance is obtained in accordance with SAE J1995, ISO3046/1, BS5514/1, and DIN6271/1 standards. Transient response data is acquired from an engine/ generator combination at normal operating temperature and in accordance with ISO3046/1 standard ambient conditions. Also in accordance with SAE J1995, BS5514/1, and DIN6271/1 standard reference conditions. Conditions: Power for gas engines is based on fuel having an LHV of 33.74 kJ/L (905 Btu/cu ft) at 101 kPa (29.91 in. Hg) and 15 C (59 F). Fuel rate is based on a cubic meter at 100 kPa (29.61 in. Hg) and 15.6 C (60.1 F). Air flow is based on a cubic foot at 100 kPa (29.61 in. Hg) and 25 C (77 F). Exhaust flow is based on a cubic foot at 100 kPa (29.61 in. Hg) and stack temperature. Materials and specifications are subject to change without notice. The International System of Units (SI) is used in this publication. CAT, CATERPILLAR, their respective logos, SOS, ADEM, "Caterpillar Yellow" and the "Power Edge" trade dress, as well as corporate and product identity used herein, are trademarks of Caterpillar and may not be used without permission. Performance Numbers: DM5137-03, DM5432-05, DM5433-05, DM8605-02 LEHW0039-02 (8-10) Supersedes LEHW0812-05 B-6 2010 Caterpillar All rights reserved. GE Power & Water Distributed Power Waukesha*gas engines VH p* Series Four* L5794/L7044GSI-EPA 1380/1680 BHP (1029/1253 kWb) a product of econ u~ nation multi-fuel mobile power With over 100 yeors of engine design, development and manufacturing experience, GE's Waukesha gas engines are redefining oil field power generation in drill rig applications with a non-road EPA mobile certified solution that provides diesel-like performance, fuel flexibility to run on noturol gos/field gos and low emissions output for excellent engine performance. generation Operation - runs and provides power like a diesel without the cost of diesel fuel Flexibility - reliable, proven fuel flexibility across a wide BTU range Emissions - non-road mobile certified by the US EPA Mobility- Simple to package with a pony skid or tailboard skid for plug and ploy operation Power - maintains consistent power output across changing field conditions standard engine features 1. Flywheel machined for generator coupli ng 2. Side inlet jacket water pump header 3. Jacket water outlet includes Dresser coupling 4. Auxiliary water thermostatic valve 5. Main bearing temperature sensors 6. Exhaust temperature sensors 7. Front stub shaft 8. Standard air/gas starter. optional electric starters 9. Three-way catalytic converter, includes housing, elements, flexibile bellows; integrated catalyst silencer option 10. 1/0 box with display ond MIL functiona lity 11. Single point fuel Inlet 12. 5 spin-on oil filters 13. Closed breather system technical data L5794GSI EPA Cylinders V12 Piston displacement 5788 cu. in.I95 L) Compression ratio 8.25:1 Bore & stroke 8.5" x 8.5" (216 x 216 mml Jacket woter system capacity 107 gal. (405 L) Lube oil capacity 190 gal. (719 U Starting system 90 - 150 psi air/gas; optional 24V electric L7044GSI EPA Cylinders Piston displacement Compression rotio Bore & stroke Jacket water system capacity Lube oil capacity Starting system V12 7040 cu. in. (115 LI 8:1 9.375" X 8.5" (238 X 216) 100 gal. (379 L) 190 gal. (719 L) 90 -150 psi air/gas; optional 24V electric .,-,odemork of General Eleclrfc Company . engine power ratings at site conditions L5794GSI using 91 WKI fuel, BHP Ambient temperature F 77 1000 1380 2000 1380 3000 1380 Elevation ft. 4000 5000 1380 1380 6000 1380 7000 1380 8000 1376 86 1380 1380 1380 1380 1380 1380 1380 1376 100 1380 1380 1380 1380 1380 1380 1380 1376 104 1374 1374 1374 1374 1374 1374 1374 1374 120 1352 1352 1352 1352 1352 1352 1352 1352 L7044GSI using 91 WKI fuel, BHP Ambient temperature F 77 86 100 104 120 1000 1680 1680 1680 1673 1646 2000 1680 1680 1680 1673 1646 3000 1680 1680 1680 1673 1646 Elevation ft. 4000 5000 1680 1680 1680 1680 1680 1680 1673 1673 1646 1620 6000 1680 1680 1680 1673 1593 7000 1680 1680 1680 1663 1481 8000 1675 1627 1515 1476 1289 Fuel Standard: All natural gas engine ratings are based on 900 BTU/ft' 135.38 MJ/m'I SLHV, 91 WKI minimum, commercial quality natural gas. Refer to S-7884-7 llatest version) for full gaseous fuel specifications. dimensions/weight model L5794GSI EPA L7044GSI EPA A in(mml 147 (3734) 147 (3734) B in(mm) 85 (2159) 85 (2159) C in(mml 97.83 (2485) 97.83 (2485) D in(mml 24 (610) 24 (610) E in(mml 48 (1219) 48 (1219) F in(mml 10.80 (274) 10.80 (274) weight lb (kg) 21,000 (9,525) 21,000 (9,525) *1/0 Panel shipped loose. **Engine shipped on shipping skid mobileFLEX Multi-Fuel Mobile Power Generation GE Energy Gas Engines Waukesha* gas engine VHP* Series Four* L5794GSI 920 - 1380 BHP (686 - 1029 kWb) GE's Waukesha Series Four rich-burn engines are the engines of choice for the harshest and most demanding gas compression, power generation and mechanical drive applications. The Series Four engines can reliably produce more power on the hottest eld gases, a the highest altitudes, and in the most remote locations, all while delivering the lowest available emissions when paired with a 3-way catalyst (NSCR). technical data Cylinders V12 Piston displacement 5788 cu. in. (95 L) Compression ratio 8.25:1 Bore & stroke 8.5" x 8.5" (216 x 216 mm) Jacket water system capacity 107 gal. (405 L) Lube oil capacity 190 gal. (719 L) Starting system 125 - 150 psi air/gas 24V electric Dimensions l x w x h inch (mm) 147 (3734) x 85 (2159) x 97.83 (2485) Weights lb (kg) 21,000 (9,525) imagination at work *Trademark of General Electric Company Intake/ Exhaust System Heat Balance Emissions performance data Intercooler Water Temperature 130F (54C) Power bhp (kWb) BSFC (LHV) Btu/bhp-hr (kJ/kWh) Fuel Consumption Btu/hr x 1000 (kW) NOx g/bhp-hr (mg/Nm3 @ 5% O2) CO g/bhp-hr (mg/Nm3 @ 5% O2) NMHC g/bhp-hr (mg/Nm3 @ 5% 02) THC g/bhp-hr (mg/Nm3 @ 5% O2) Heat to Jacket Water Btu/hr x 1000 (kW) Heat to Lube Oil Btu/hr x 1000 (kW) Heat to Intercooler Btu/hr x 1000 (kW) Heat to Radiation Btu/hr x 1000 (kW) Total Exhaust Heat Btu/hr x 1000 (kW) Induction Air Flow scfm (Nm3/hr) Exhaust Flow lb/hr (kg/hr) Exhaust Temperature F (C) 1200 RPM 1380 (1029) 7665 (10846) 10578 (3100) 13.50 (5011) 10.50 (3770) 0.28 (105) 1.80 (682) 3037 (890) 470 (138) 132 (39) 674 (198) 2959 (867) 2001 (3014) 8984 (4075) 1136 (613) 1000 RPM 1150 (858) 7496 (10602) 8621 (2527) 14.90 (5508) 10.10 (3734) 0.30 (110) 2.00 (733) 2512 (736) 372 (109) 74 (22) 605 (177) 2298 (674) 1638 (2467) 7355 (3336) 1077 (581) All data according to full load and subject to technical development and modication. Consult your local GE Energy's representative for system application assistance. The manufacturer reserves the right to change or modify without notice, the design or equipment specications as herein set forth without incurring any obligation either with respect to equipment previously sold or in the process of construction except where otherwise specically guaranteed by the manufacturer. imagination at work GE Energy 1101 West Saint Paul Ave. Waukesha, WI 53188-4999 P: 262.547.3311 F: 262.549.2759 Visit us online at: www.waukeshaengine.com 2011 General Electric Company All Rights Reserved 7058 1211 GEA-18928 MOBILE ANALYTICAL LABORATORIES, P.O. BOX 69210 ODESSA, TEXAS 79769 PHONE (432)337-4744 I NC. GAS ANALYSIS REPORT 45295 COMPANY . . LEASE/PLANT OPERATOR CYLINDER H2S PPM. NAVITAS MIDSTREAM PLANT VENT NEWBERRY 881 0.0 PARTNERS STATION PRESS. PSIG TEMP. DEG. F SAMPLED/ RECEIVED SAMPLED BY .815 .58 .01/17/18 .RR COMPONENT NITROGEN CARBON DIOXIDE METHANE ETHANE PROPANE ISO-BUTANE N-BUTANE ISO-PENTANE N-PENTANE. HEXANES PLUS H2S . . . CALC. SP.GRAVITY TOTALS 0.744 DISTRIBUTION: MR. CHRIS BUMGARNER FRACTIONAL ANALYSIS MOL% 2.811 0.000 74.094 13 . 129 7.420 0.496 1.519 0. 1 86 0.179 0. 1 66 0.000 100.000 GPM C2+ 0.000 0 . 000 0.000 3.504 2.040 0 . 162 0.478 0 . 068 0.065 0.072 0.000 6.389 GPM cs+ -----0.000 0 . 000 0.000 0.000 0.000 0.000 0.000 0.068 0.065 0.072 0.000 ---- -- 0 . 205 BTU/CU. FT. (14.650 PSIA, 60 DEG. F) CALC. GROSS WET 1235 CALC. GROSS DRY 1257 NOTES: REPORT DATE: 01/24/18 MOBILE ANALYTICAL LABORATORIES, P . 0 . BOX 6 9210 ODESSA, TEXAS 79769 PHONE (432)337 - 4744 INC . GAS ANALYSIS REPORT 45294 COMPANY . . LEASE/PLANT OPERATOR CYLINDER H2S PPM. NAVITAS MIDSTREAM RESIDUE GAS NEWBERRY 1096 0.0 PARTNERS STATION PRESS. PSIG TEMP. DEG. F SAMPLED/ RECEIVED SAMPLED BY .878 .57 .01/17/18 .RR FRACTIONAL ANALYSIS COMPONENT ---------- ---------- NITROGEN CARBON DIOXIDE METHANE ETHANE PROPANE ISO-BUTANE N-BUTANE ISO-PENTANE N-PENTANE HEXANES PLUS H2S TOTALS CALC. SP.GRAVITY 0.630 MOL % -- - ---3.344 0.000 84. 813 11.150 0.685 0.003 0.003 0.000 0.000 0.002 0.000 - --- --100.000 GPM C2+ ---- -0.000 0.000 0.000 2.972 0.188 0.001 0.001 0.000 0.000 0.001 0.000 -----3.163 GPM CS+ -----0.000 0.000 0.000 0.000 0 . 000 0.000 0.000 0.000 0.000 0.001 0.000 -- - -- 0.001 BTU/CU. FT . (14.650 PSIA, 60 DEG. F) CALC. GROSS WET 1052 CALC. GROSS DRY 1071 DISTRIBUTION: MR. CHRIS BUMGARNER NOTES: REPORT DATE: 01/24/18 S ? L Certificate of Analysis Number: 5030-19060407-001A Midland Laboratory 2200 East I-20 Midland, TX 79706 Phone 432-689-7252 CHRIS PUTZEL NAVITAS MIDSTREAM 14108 E CR 230 MIDLAND, TX 79706 Station Name: STABILIZED CONDENSATE Station Location:NEWBERRY PLANT Cylinder No: 5030-32799 Analyzed: 06/26/2019 16:54:37 by MB June 26, 2019 Sampled By: DEREK VAN WINKLE Sample Of: NGL Spot Sample Date: 06/20/2019 17:00 Sample Conditions:1225 psig, @ 162 F Method: GPA 2186 Components Mol. % Wt. % Analytical Data L.V. % Nitrogen Carbon Dioxide Methane Ethane Propane Iso-Butane n-Butane Iso-Pentane n-Pentane Hexanes Plus 0.011 0.000 0.496 7.422 33.977 5.992 24.422 6.739 7.951 12.990 100.000 0.005 0.000 0.139 3.886 26.092 6.065 24.719 8.467 9.990 20.637 100.000 Calculated Physical Properties Specific Gravity at 60F API Gravity at 60F Molecular Weight Pounds per Gallon (in Vacuum) Pounds per Gallon (in Air) Specific Gravity as a vapor Cu. Ft. Vapor per Gallon @ 14.696 psia BTU / Cu. Ft. @ 14.696 psia DRY BTU / GAL. BTU / LB. CO2, Ethane LV Ratio Methane, Ethane LV Ratio Vapor Pressure @ 100F 0.004 0.000 0.266 6.260 29.526 6.185 24.285 7.773 9.091 16.610 100.000 Total 0.5739 115.0443 57.423 4.785 4.780 1.983 31.622 3211 101540 21220 0.00 4.25 168.37 C6+ 0.7130 66.9544 91.225 5.944 5.938 3.150 24.728 4926 121813 20486 4.16 Quality Assurance: Hydrocarbon Laboratory Manager The above analyses are performed in accordance with ASTM, UOP, GPA guidelines for quality assurance, unless otherwise stated. Page 1 of 4 S ? L Certificate of Analysis Number: 5030-19060407-001A Midland Laboratory 2200 East I-20 Midland, TX 79706 Phone 432-689-7252 CHRIS PUTZEL NAVITAS MIDSTREAM 14108 E CR 230 MIDLAND, TX 79706 Station Name: STABILIZED CONDENSATE Station Location:NEWBERRY PLANT Cylinder No: 5030-32799 Analyzed: 06/26/2019 16:54:37 by MB June 26, 2019 Sampled By: DEREK VAN WINKLE Sample Of: NGL Spot Sample Date: 06/20/2019 17:00 Sample Conditions:1225 psig, @ 162 F Method: GPA 2186 Components Mol. % Wt. % Analytical Data L.V. % Nitrogen Carbon Dioxide Methane Ethane Propane Iso-Butane n-Butane Iso-Pentane n-Pentane Hexanes Heptanes Plus 0.011 0.000 0.496 7.422 33.977 5.992 24.422 6.739 7.951 5.816 7.174 100.000 0.005 0.000 0.139 3.886 26.092 6.065 24.719 8.467 9.990 8.606 12.031 100.000 Calculated Physical Properties Specific Gravity at 60F API Gravity at 60F Molecular Weight Pounds per Gallon (in Vacuum) Pounds per Gallon (in Air) Specific Gravity as a vapor Cu. Ft. Vapor per Gallon @ 14.696 psia BTU / Cu. Ft. @ 14.696 psia DRY BTU / GAL. BTU / LB. 0.004 0.000 0.266 6.260 29.526 6.185 24.285 7.773 9.091 7.397 9.213 100.000 Total 0.5739 115.0443 57.423 4.785 4.780 1.983 31.622 3211 101540 21220 C7+ 0.7492 57.3722 96.315 6.246 6.239 3.325 24.610 5129 126213 20207 Quality Assurance: Hydrocarbon Laboratory Manager The above analyses are performed in accordance with ASTM, UOP, GPA guidelines for quality assurance, unless otherwise stated. Page 2 of 4 S ? L Certificate of Analysis Number: 5030-19060407-001A Midland Laboratory 2200 East I-20 Midland, TX 79706 Phone 432-689-7252 CHRIS PUTZEL NAVITAS MIDSTREAM 14108 E CR 230 MIDLAND, TX 79706 Station Name: STABILIZED CONDENSATE Station Location:NEWBERRY PLANT Cylinder No: 5030-32799 Analyzed: 06/26/2019 16:54:37 by MB June 26, 2019 Sampled By: DEREK VAN WINKLE Sample Of: NGL Spot Sample Date: 06/20/2019 17:00 Sample Conditions:1225 psig, @ 162 F Method: GPA 2186 Components Mol. % Wt. % Analytical Data L.V. % Nitrogen Methane Carbon Dioxide Ethane Propane Iso-Butane n-Butane Iso-Pentane n-Pentane i-Hexanes n-Hexane Benzene Cyclohexane i-Heptanes n-Heptane Toluene i-Octanes n-Octane Ethylbenzene Xylenes i-Nonanes n-Nonane i-Decanes n-Decane Undecanes Plus 0.011 0.496 NIL 7.422 33.977 5.992 24.422 6.739 7.951 3.652 2.164 0.272 0.790 3.309 0.589 0.190 1.470 0.156 0.028 0.051 0.198 0.032 0.076 0.009 0.004 100.000 0.005 0.139 NIL 3.886 26.092 6.065 24.719 8.467 9.990 5.358 3.248 0.370 1.158 5.318 1.029 0.305 2.708 0.310 0.053 0.095 0.414 0.072 0.163 0.023 0.013 100.000 Calculated Physical Properties Specific Gravity at 60F API Gravity at 60F Molecular Weight Pounds per Gallon (in Vacuum) Pounds per Gallon (in Air) Specific Gravity as a vapor Cu. Ft. Vapor per Gallon @ 14.696 psia BTU / Cu. Ft. @ 14.696 psia DRY BTU / GAL. BTU / LB. 0.004 0.266 NIL 6.260 29.526 6.185 24.285 7.773 9.091 4.587 2.810 0.240 0.848 4.146 0.858 0.200 2.063 0.252 0.035 0.063 0.309 0.057 0.114 0.018 0.010 100.000 Total 0.5739 115.0443 57.423 4.785 4.780 1.983 31.622 3211 101540 21220 C11+ 0.7471 57.8894 160.617 6.229 6.222 5.531 14.717 8697 128322 20600 Quality Assurance: Hydrocarbon Laboratory Manager The above analyses are performed in accordance with ASTM, UOP, GPA guidelines for quality assurance, unless otherwise stated. Page 3 of 4 1Lj ' Report ToNavitas IComoanvName) Address: 14108 ECR 230 $PL, Inc. AnalysisRequest Chain ofCustodyRecord SPL Work OrderNo.: Acct. Mate Code Dept. Code .....................----------- -------------------- ProjecUStation Name: Project/Station Number: ProjecVStation Location: ---------------.... ...................___-- .............................----------------- Special lnstructi1X1s: PaQe Pa9es 1 1 Requested TAT' City/State/Zip: Midland Contact: Chris Putzel Phone: 432,631-6112 Invoice To Naiitas !Comoanv Name) Address: 14108 ECR 230 Citv/State/Zio: Midiand Contact: Chris Putzel Phone: 432-631-6112 ClientPO# or Rel. No.: Contract/Proposal#: (ie SPLOem) SampleID Sample (used to log/track sample) Dale Sample Time TX 79706 Clll!IZel@navi1as1T11dslream.com Indicate Billing Type: (Place 'X", where Fax: appropriate] Net 30 day Acct. Credit Card TX 79706 ~utze1:1i)navilas-midstream com N/A Sample ~ Type -~ 8. 0 a (Gas/Liq. a. ~ E en /Solid) 0 0 () 1Terms: Cylinders willberented for S10/cyl.All C)iinders checked out are to be returned within 21 days, whether they contain sample or not. Cylinders not returned after 30 dayswill be consideredlost andwill be billed al current replacementcost. Cylinder Trackinglnfo1 Cylinder# Date Out DateIn (j a ~ I cJ d) T1 Slug Catcher 06/20/19 4:00 NGL Super Sized SlugCalcher 06120/19 4:30 NGL Stab1hzer 06'20/19 5:00 NGL \ X tOJ0.-08532 06/20/19 X 1030-06527 06120/19 X 5030,32799 06/20/19 06/20/19 06/20/19 00/20/1~ 10 business days Check# <Contact SPL,Inc for CC payment arrangements. RequestedAnalysis (Place an"X"next toSampleIDbelow) SurchargesMay Apply (See quote fa- details) ? iii ll. .... ~ Q. iii E ~ QJ~ ~ QJ :l C. VI VI E QJ Ill \. ll. IJ) QJ C. E (0 IJ) Comments 1000 110 850 78 1225 162 Sampled By-Print Name: Derek Van Wnkle ~ Signature: Derek Van Winkle -\M Relinquished By-Pnnt Name, .. Signature: Derek Van Winkle Date: Time: Derek Van Winkle -- 06/20/19 7:00 Relirniuished By-Pnnl Name ---- Signature: Dale: Time: Relinquished By-Prinl Name Signature Dale: Time: ---------------- Received By-Company: ,; I Received By-PrintName: \""o t..f~ Signature- I Received ByPrinl Name: I -- S~nature: /"\. 1----~ ReceivedBy-Print Name: ---------------..-- Signature: Date: Time: ----- Date: Time: Date: Time: ... !Chooso SPL Facility> Ship toAddress: 300 Faudree Rd.,MidlandTX79765 j Phone: 432-689-7252 Note -As aconvenience to our clienls,!his form is available in an electronic format. Please contact one ofouroffices above for the form lo bee-mailed toyou. 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OEIIW %WXIWA %WXOE %WXIWA %WXOE %ORZGRZQ 6ROYHG 0DNHXS%ORZGRZQ Flash Tank Solved V-100 PCV-100A 6DWXUDQW:DWHU 6ROYHG 6DWXUDWRU Still Vent Solved V-106 PCV-106 107.736 70 100 0 0 21.7441 0.307583 7.17468 156.007 507.203 63.2357 0.0653442 0.889570 0.983296 0.750764 -251059 -1609.28 0.493779 1.23248 0.0111144 2.25581 0.0182970 1168.95 20318.9 1287.86 22394.2 ( 120.000 6 100 0 0 41.6002 0.139219 71.7441 2984.57 21437.9 2672.78 0.653417 7.33042 0.994117 1.43634 -1.15551E+07 -3871.60 0.220341 1.27949 0.0160284 7.18738 0.0107749 23.4872 103.600 29.7743 160.951 GRI-GLYCalc VERSION 4.0 - EMISSIONS SUMMARY Page: 1 Case Name: Newberry Dehy File Name: X:\Projects\Navitas\TEXAS\Midland\Air Permitting and Compliance\Newberry Gas Plant\0117NRSP\Newberry.ddf Date: March 06, 2017 CONTROLLED REGENERATOR EMISSIONS ------------------------------------------------------------------- Component lbs/hr lbs/day tons/yr ------------------------------- ----------- ----------- ----------- Methane 2.8513 68.430 12.4885 Ethane 8.5866 206.079 37.6094 Propane 19.3886 465.327 84.9221 Isobutane 3.6644 87.946 16.0502 n-Butane 15.5718 373.724 68.2046 Isopentane n-Pentane n-Hexane Other Hexanes Heptanes 2.7428 3.8708 0.7272 1.1744 1.2240 65.828 92.900 17.452 28.186 29.377 12.0137 16.9543 3.1849 5.1439 5.3613 Benzene Toluene Ethylbenzene Xylenes C8+ Heavies ------------------------------Total Emissions 5.5474 1.0140 0.0192 0.0912 0.1296 ----------66.6033 133.137 24.335 0.460 2.190 3.109 ----------1598.480 24.2974 4.4412 0.0840 0.3997 0.5674 ----------291.7226 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions 66.6033 55.1655 7.3989 6.6718 1598.480 1323.971 177.574 160.122 291.7226 241.6247 32.4072 29.2223 UNCONTROLLED REGENERATOR EMISSIONS ------------------------------------------------------------------- Component lbs/hr lbs/day tons/yr ------------------------------- ----------- ----------- ----------- Methane 2.8544 68.506 12.5024 Ethane 8.6232 206.957 37.7697 Propane 19.7276 473.463 86.4069 Isobutane 3.7858 90.858 16.5817 n-Butane 16.2742 390.580 71.2808 Isopentane n-Pentane n-Hexane Other Hexanes Heptanes 3.0076 4.3365 0.9386 1.4473 2.1940 72.182 104.077 22.527 34.735 52.655 13.1732 18.9940 4.1112 6.3392 9.6096 Benzene Toluene Ethylbenzene Xylenes C8+ Heavies ------------------------------Total Emissions 7.8328 2.3194 0.0762 0.4380 29.4425 ----------103.2982 187.987 55.666 1.830 10.513 706.621 ----------- 2479.157 34.3076 10.1590 0.3339 1.9185 128.9583 ----------452.4461 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions 103.2982 91.8205 11.6051 10.6665 2479.157 2203.693 278.522 255.995 452.4461 402.1740 50.8303 46.7191 Page: 2 FLASH GAS EMISSIONS ------------------------------------------------------------------- Component lbs/hr lbs/day tons/yr ------------------------------- ----------- ----------- ----------- Methane 2.6716 64.118 11.7015 Ethane 2.1647 51.952 9.4813 Propane 2.0385 48.924 8.9287 Isobutane 0.2445 5.869 1.0711 n-Butane 0.7763 18.632 3.4004 Isopentane n-Pentane n-Hexane Other Hexanes Heptanes 0.1203 0.1347 0.0152 0.0319 0.0164 2.886 3.232 0.366 0.765 0.394 0.5267 0.5899 0.0668 0.1395 0.0719 Benzene Toluene Ethylbenzene Xylenes C8+ Heavies ------------------------------Total Emissions 0.0037 0.0007 <0.0001 <0.0001 0.0217 ----------8.2403 0.090 0.016 <0.001 0.001 0.522 ----------197.767 0.0163 0.0029 0.0001 0.0002 0.0952 ----------36.0924 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions 8.2403 3.4040 0.0197 0.0045 197.767 81.697 0.473 0.107 36.0924 14.9097 0.0863 0.0195 FLASH TANK OFF GAS ------------------------------------------------------------------- Component lbs/hr lbs/day tons/yr ------------------------------- ----------- ----------- ----------- Methane 53.4314 1282.353 234.0294 Ethane 43.2934 1039.042 189.6252 Propane 40.7704 978.489 178.5743 Isobutane 4.8908 117.380 21.4219 n-Butane 15.5268 372.642 68.0072 Isopentane n-Pentane n-Hexane Other Hexanes Heptanes 2.4051 2.6936 0.3049 0.6371 0.3282 57.722 64.646 7.317 15.292 7.876 10.5342 11.7979 1.3354 2.7907 1.4374 Benzene Toluene Ethylbenzene Xylenes C8+ Heavies ------------------------------Total Emissions 0.0746 0.0134 0.0002 0.0009 0.4348 ----------164.8056 1.790 0.322 0.006 0.022 10.434 ----------3955.334 0.3267 0.0588 0.0011 0.0040 1.9043 ----------721.8484 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions 164.8056 68.0808 0.3941 0.0892 3955.334 1633.939 9.457 2.140 721.8484 298.1939 1.7260 0.3905 GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Page: 1 Case Name: Newberry Dehy File Name: X:\Projects\Navitas\TEXAS\Midland\Air Permitting and Compliance\Newberry Gas Plant\0117NRSP\Newberry.ddf Date: March 06, 2017 DESCRIPTION: ------------------------------------------------------------------- Description: 200 MMSCFD after the Amine unit 41 GPM Annual Hours of Operation: 8760.0 hours/yr WET GAS: ------------------------------------------------------------------- Temperature: 120.00 deg. F Pressure: 960.00 psig Wet Gas Water Content: Saturated Component ------------------------------Carbon Dioxide Nitrogen Methane Ethane Propane Conc. (vol %) ----------- 0.1300 2.0300 73.6924 13.4443 7.3865 Isobutane n-Butane Isopentane n-Pentane n-Hexane 0.6528 1.8824 0.2826 0.2939 0.0308 Other Hexanes Heptanes Benzene Toluene Ethylbenzene 0.0650 0.0333 0.0060 0.0012 0.0000 Xylenes C8+ Heavies 0.0001 0.0800 DRY GAS: ------------------------------------------------------------------- Flow Rate: Water Content: 200.0 MMSCF/day 7.0 lbs. H2O/MMSCF LEAN GLYCOL: ------------------------------------------------------------------- Glycol Type: TEG Water Content: Flow Rate: 1.5 wt% H2O 41.0 gpm PUMP: ------------------------------------------------------------------- Glycol Pump Type: Electric/Pneumatic Page: 2 FLASH TANK: ------------------------------------------------------------------- Flash Control: Combustion device Flash Control Efficiency: 95.00 % Temperature: 100.0 deg. F Pressure: 50.0 psig REGENERATOR OVERHEADS CONTROL DEVICE: ------------------------------------------------------------------- Control Device: Condenser Temperature: 120.0 deg. F Pressure: 14.0 psia Control Device: Combustion Device Destruction Efficiency: 0.0 % Excess Oxygen: 0.0 % Ambient Air Temperature: 95.0 deg. 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JP JP JP YES 1HZEHUU\&DOFVB[OV[ & 12[0RGHOLQJ TABLE 41 SCREEN MODELING INPUTS AND RESULTS NEWBERRY GAS PLANT NAVITAS MIDSTREAM MIDLAND BASIN, LLC MIDLAND COUNTY, TEXAS Inputs 62(PLVVLRQ5DWH 6WDFN+HLJKW 6WDFN,QVLGH'LDPHWHU 6WDFN([LW)ORZ5DWH 6WDFN([LW9HORFLW\ 6WDFN*DV([LW7HPS $PELHQW$LU7HPS 5HFHSWRU+HLJKW 8UEDQ5XUDO 'RZQZDVK CATERPILLAR 3516B (C-1680 - C-1740) OEKU62 IW IW IWVHF ) IW 5XUDO 1RQH JVHF P P PVHF . . P 5XUDO 1RQH Screen Modeling Results (hourly) 0D[LPXP0RGHOHG&RQFHQWUDWLRQ 1XPEHURI/LNH.LQG8QLWV 0D[LPXP0RGHOHG&RQFHQWUDWLRQIRUHDFKPRGHO JP JP Hourly Results for All Stacks Combined 7RWDO0RGHOHG&RQFHQWUDWLRQ %DFNJURXQG&RQFHQWUDWLRQ 7RWDO&RQFHQWUDWLRQ Is Total Concentration less than 196 g/m3 ? 7RWDOKRXU0RGHOHG&RQFHQWUDWLRQ %DFNJURXQG 7RWDO0RGHOHG&RQFHQWUDWLRQZLWK%DFNJURXQG &RQYHUVLRQ)DFWRUKRXUO\WRKRXU 7RWDOKRXUFRQFHQWUDWLRQ Is Total Concentration less than 1300 g/m3 ? 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JP YES 1HZEHUU\&DOFVB[OV[ & +60RGHOLQJ *** SCREEN3 MODEL RUN *** *** VERSION DATED 13043 *** C3516NOx.OUT 08/07/19 12:07:49 Newberry - NOx - Caterpillar 3516LB SIMPLE TERRAIN INPUTS: SOURCE TYPE = EMISSION RATE (G/S) = STACK HEIGHT (M) = STK INSIDE DIAM (M) = STK EXIT VELOCITY (M/S)= STK GAS EXIT TEMP (K) = AMBIENT AIR TEMP (K) = RECEPTOR HEIGHT (M) = URBAN/RURAL OPTION = BUILDING HEIGHT (M) = MIN HORIZ BLDG DIM (M) = MAX HORIZ BLDG DIM (M) = POINT 0.383000E-01 9.1440 0.3048 58.8659 806.4833 293.1500 0.0000 RURAL 0.0000 0.0000 0.0000 THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED. THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED. BUOY. FLUX = 8.534 M**4/S**3; MOM. FLUX = 29.254 M**4/S**2. *** FULL METEOROLOGY *** ********************************** *** SCREEN AUTOMATED DISTANCES *** ********************************** *** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES *** DIST (M) ------1. 100. 200. 300. 400. 500. 600. 700. 800. 900. 1000. 1100. 1200. 1300. 1400. 1500. 1600. 1700. 1800. 1900. 2000. 2100. 2200. 2300. 2400. CONC (UG/M**3) ---------- 0.000 0.4565 1.372 1.210 1.174 1.086 0.9831 0.9293 0.8614 0.8014 0.7477 0.7001 0.6547 0.6200 0.5863 0.5543 0.5351 0.5551 0.5720 0.5858 0.5970 0.6025 0.6063 0.6085 0.6094 STAB ---- 1 3 3 4 4 4 4 4 4 4 4 4 4 4 4 4 5 5 5 5 5 5 5 5 5 U10M (M/S) ----- 1.0 10.0 10.0 15.0 10.0 8.0 5.0 5.0 4.5 4.0 3.5 3.5 3.0 3.0 3.0 3.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 USTK MIX HT (M/S) (M) ----- ------ 1.0 320.0 10.0 3200.0 10.0 3200.0 15.0 4800.0 10.0 3200.0 8.0 2560.0 5.0 1600.0 5.0 1600.0 4.5 1440.0 4.0 1280.0 3.5 1120.0 3.5 1120.0 3.0 960.0 3.0 960.0 3.0 960.0 3.0 960.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 Page 1 PLUME HT (M) ------ 116.12 19.84 19.84 16.28 19.84 22.52 30.54 30.54 32.92 35.89 39.71 39.71 44.80 44.80 44.80 44.80 69.89 69.89 69.89 69.89 69.89 69.89 69.89 69.89 69.89 SIGMA Y (M) ------ 2.59 12.62 23.82 22.70 29.61 36.35 43.15 49.57 55.99 62.35 68.68 74.82 81.08 87.12 93.11 99.07 80.05 84.38 88.69 92.98 97.26 101.52 105.77 110.00 114.22 SIGMA Z (M) ------ 2.56 7.71 14.36 12.26 15.57 18.69 22.07 24.80 27.63 30.44 33.26 35.22 37.50 39.34 41.14 42.90 33.88 34.85 35.82 36.78 37.72 38.56 39.39 40.21 41.02 DWASH ----- 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 2500. 2600. 2700. 2800. 2900. 3000. 3500. 4000. 4500. 5000. 5500. 6000. 6500. 7000. 7500. 8000. 8500. 9000. 9500. 10000. 15000. 20000. 25000. 30000. 40000. 50000. 0.6090 0.6090 0.6192 0.6283 0.6362 0.6432 0.6498 0.6455 0.6345 0.6193 0.6018 0.5829 0.5636 0.5443 0.5239 0.5044 0.4860 0.4685 0.4519 0.4363 0.3187 0.2474 0.2013 0.1692 0.1283 0.1031 C3516NOx.OUT 5 1.0 1.0 10000.0 69.89 118.42 41.82 NO 6 1.0 1.0 10000.0 59.55 82.04 28.81 NO 6 1.0 1.0 10000.0 59.55 84.80 29.26 NO 6 1.0 1.0 10000.0 59.55 87.56 29.71 NO 6 1.0 1.0 10000.0 59.55 90.31 30.15 NO 6 1.0 1.0 10000.0 59.55 93.04 30.58 NO 6 1.0 1.0 10000.0 59.55 106.63 32.36 NO 6 1.0 1.0 10000.0 59.55 120.04 34.03 NO 6 1.0 1.0 10000.0 59.55 133.28 35.61 NO 6 1.0 1.0 10000.0 59.55 146.38 37.12 NO 6 1.0 1.0 10000.0 59.55 159.34 38.55 NO 6 1.0 1.0 10000.0 59.55 172.18 39.92 NO 6 1.0 1.0 10000.0 59.55 184.90 41.24 NO 6 1.0 1.0 10000.0 59.55 197.52 42.52 NO 6 1.0 1.0 10000.0 59.55 210.03 43.61 NO 6 1.0 1.0 10000.0 59.55 222.45 44.67 NO 6 1.0 1.0 10000.0 59.55 234.78 45.69 NO 6 1.0 1.0 10000.0 59.55 247.03 46.68 NO 6 1.0 1.0 10000.0 59.55 259.19 47.64 NO 6 1.0 1.0 10000.0 59.55 271.29 48.57 NO 6 1.0 1.0 10000.0 59.55 388.69 56.74 NO 6 1.0 1.0 10000.0 59.55 501.16 61.99 NO 6 1.0 1.0 10000.0 59.55 609.92 66.44 NO 6 1.0 1.0 10000.0 59.55 715.73 70.33 NO 6 1.0 1.0 10000.0 59.55 920.34 75.87 NO 6 1.0 1.0 10000.0 59.55 1117.52 80.49 NO MAXIMUM 1-HR CONCENTRATION AT OR BEYOND 1. M: 193. 1.375 3 10.0 10.0 3200.0 19.84 23.17 13.98 NO DWASH= MEANS NO CALC MADE (CONC = 0.0) DWASH=NO MEANS NO BUILDING DOWNWASH USED DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB *************************************** *** SUMMARY OF SCREEN MODEL RESULTS *** *************************************** CALCULATION PROCEDURE -------------SIMPLE TERRAIN MAX CONC (UG/M**3) ----------- 1.375 DIST TO TERRAIN MAX (M) HT (M) --------- ------- 193. 0. Page 2 *** SCREEN3 MODEL RUN *** *** VERSION DATED 13043 *** C3606NOx.OUT 08/07/19 12:49:07 Newberry - NOx - Caterpillar 3606 SIMPLE TERRAIN INPUTS: SOURCE TYPE = EMISSION RATE (G/S) = STACK HEIGHT (M) = STK INSIDE DIAM (M) = STK EXIT VELOCITY (M/S)= STK GAS EXIT TEMP (K) = AMBIENT AIR TEMP (K) = RECEPTOR HEIGHT (M) = URBAN/RURAL OPTION = BUILDING HEIGHT (M) = MIN HORIZ BLDG DIM (M) = MAX HORIZ BLDG DIM (M) = POINT 0.493000E-01 9.1440 0.3048 78.5614 725.9278 293.1500 0.0000 RURAL 0.0000 0.0000 0.0000 THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED. THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED. BUOY. FLUX = 10.667 M**4/S**3; MOM. FLUX = 57.888 M**4/S**2. *** FULL METEOROLOGY *** ********************************** *** SCREEN AUTOMATED DISTANCES *** ********************************** *** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES *** DIST (M) ------1. 100. 200. 300. 400. 500. 600. 700. 800. 900. 1000. 1100. 1200. 1300. 1400. 1500. 1600. 1700. 1800. 1900. 2000. 2100. 2200. 2300. 2400. CONC (UG/M**3) ---------- 0.000 0.3077 1.459 1.351 1.285 1.189 1.086 0.9813 0.9343 0.8719 0.8153 0.7623 0.7149 0.6747 0.6388 0.6044 0.5774 0.5768 0.5986 0.6174 0.6334 0.6431 0.6508 0.6566 0.6609 STAB ---- 1 3 3 4 4 4 4 4 4 4 4 4 4 4 4 4 4 5 5 5 5 5 5 5 5 U10M (M/S) ----- 1.0 10.0 10.0 15.0 10.0 8.0 8.0 5.0 5.0 5.0 4.5 4.0 4.0 3.5 3.5 3.5 3.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 USTK MIX HT (M/S) (M) ----- ------ 1.0 320.0 10.0 3200.0 10.0 3200.0 15.0 4800.0 10.0 3200.0 8.0 2560.0 8.0 2560.0 5.0 1600.0 5.0 1600.0 5.0 1600.0 4.5 1440.0 4.0 1280.0 4.0 1280.0 3.5 1120.0 3.5 1120.0 3.5 1120.0 3.0 960.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 Page 1 PLUME HT (M) ------ 135.61 21.79 21.79 17.57 21.79 24.95 24.95 34.44 34.44 34.44 37.25 40.76 40.76 45.28 45.28 45.28 51.30 74.58 74.58 74.58 74.58 74.58 74.58 74.58 74.58 SIGMA Y (M) ------ 3.26 12.65 23.87 22.74 29.68 36.43 42.96 49.72 56.04 62.30 68.60 74.86 80.94 87.13 93.13 99.08 105.18 84.66 88.96 93.24 97.51 101.76 106.00 110.22 114.43 SIGMA Z (M) ------ 3.24 7.75 14.44 12.33 15.69 18.85 21.69 25.10 27.74 30.34 33.08 35.30 37.20 39.38 41.17 42.93 45.08 35.54 36.49 37.43 38.35 39.18 40.00 40.81 41.60 DWASH ----- 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 2500. 2600. 2700. 2800. 2900. 3000. 3500. 4000. 4500. 5000. 5500. 6000. 6500. 7000. 7500. 8000. 8500. 9000. 9500. 10000. 15000. 20000. 25000. 30000. 40000. 50000. 0.6638 0.6654 0.6658 0.6652 0.6670 0.6769 0.6941 0.6986 0.6946 0.6848 0.6713 0.6554 0.6381 0.6202 0.6000 0.5805 0.5616 0.5436 0.5263 0.5097 0.3812 0.2992 0.2454 0.2074 0.1583 0.1277 C3606NOx.OUT 5 1.0 1.0 10000.0 74.58 118.62 42.39 NO 5 1.0 1.0 10000.0 74.58 122.80 43.17 NO 5 1.0 1.0 10000.0 74.58 126.97 43.93 NO 5 1.0 1.0 10000.0 74.58 131.12 44.69 NO 6 1.0 1.0 10000.0 63.45 90.49 30.69 NO 6 1.0 1.0 10000.0 63.45 93.22 31.12 NO 6 1.0 1.0 10000.0 63.45 106.79 32.87 NO 6 1.0 1.0 10000.0 63.45 120.17 34.52 NO 6 1.0 1.0 10000.0 63.45 133.41 36.08 NO 6 1.0 1.0 10000.0 63.45 146.49 37.56 NO 6 1.0 1.0 10000.0 63.45 159.45 38.98 NO 6 1.0 1.0 10000.0 63.45 172.28 40.34 NO 6 1.0 1.0 10000.0 63.45 184.99 41.64 NO 6 1.0 1.0 10000.0 63.45 197.60 42.90 NO 6 1.0 1.0 10000.0 63.45 210.11 43.99 NO 6 1.0 1.0 10000.0 63.45 222.53 45.04 NO 6 1.0 1.0 10000.0 63.45 234.85 46.05 NO 6 1.0 1.0 10000.0 63.45 247.10 47.03 NO 6 1.0 1.0 10000.0 63.45 259.26 47.98 NO 6 1.0 1.0 10000.0 63.45 271.35 48.91 NO 6 1.0 1.0 10000.0 63.45 388.74 57.03 NO 6 1.0 1.0 10000.0 63.45 501.19 62.26 NO 6 1.0 1.0 10000.0 63.45 609.95 66.69 NO 6 1.0 1.0 10000.0 63.45 715.76 70.56 NO 6 1.0 1.0 10000.0 63.45 920.35 76.09 NO 6 1.0 1.0 10000.0 63.45 1117.53 80.70 NO MAXIMUM 1-HR CONCENTRATION AT OR BEYOND 1. M: 214. 1.470 3 10.0 10.0 3200.0 21.79 25.50 15.42 NO DWASH= MEANS NO CALC MADE (CONC = 0.0) DWASH=NO MEANS NO BUILDING DOWNWASH USED DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB *************************************** *** SUMMARY OF SCREEN MODEL RESULTS *** *************************************** CALCULATION PROCEDURE -------------SIMPLE TERRAIN MAX CONC (UG/M**3) ----------- 1.470 DIST TO TERRAIN MAX (M) HT (M) --------- ------- 214. 0. Page 2 *** SCREEN3 MODEL RUN *** *** VERSION DATED 13043 *** C3608NOx.OUT 08/07/19 12:46:58 Spraberry - NOx - Caterpillar 3608 SIMPLE TERRAIN INPUTS: SOURCE TYPE = EMISSION RATE (G/S) = STACK HEIGHT (M) = STK INSIDE DIAM (M) = STK EXIT VELOCITY (M/S)= STK GAS EXIT TEMP (K) = AMBIENT AIR TEMP (K) = RECEPTOR HEIGHT (M) = URBAN/RURAL OPTION = BUILDING HEIGHT (M) = MIN HORIZ BLDG DIM (M) = MAX HORIZ BLDG DIM (M) = POINT 0.693000E-01 9.1440 0.4054 88.0872 720.9278 293.1500 0.0000 RURAL 0.0000 0.0000 0.0000 THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED. THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED. BUOY. FLUX = 21.059 M**4/S**3; MOM. FLUX = 129.638 M**4/S**2. *** FULL METEOROLOGY *** ********************************** *** SCREEN AUTOMATED DISTANCES *** ********************************** *** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES *** DIST (M) ------1. 100. 200. 300. 400. 500. 600. 700. 800. 900. 1000. 1100. 1200. 1300. 1400. 1500. 1600. 1700. 1800. 1900. 2000. 2100. 2200. 2300. 2400. CONC (UG/M**3) ---------- 0.000 0.2392E-01 0.7531 1.111 1.076 1.003 0.9073 0.8545 0.7847 0.7367 0.6840 0.6311 0.5827 0.5541 0.5320 0.5095 0.4873 0.4657 0.4449 0.4438 0.4590 0.4692 0.4818 0.4938 0.5046 STAB ---- 1 6 3 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 5 5 5 5 5 5 U10M (M/S) ----- 1.0 1.0 10.0 20.0 20.0 15.0 10.0 10.0 10.0 8.0 8.0 8.0 8.0 5.0 5.0 5.0 5.0 5.0 5.0 1.5 1.5 1.5 1.0 1.0 1.0 USTK MIX HT (M/S) (M) ----- ------ 1.0 320.0 1.0 10000.0 10.0 3200.0 20.0 6400.0 20.0 6400.0 15.0 4800.0 10.0 3200.0 10.0 3200.0 10.0 3200.0 8.0 2560.0 8.0 2560.0 8.0 2560.0 8.0 2560.0 5.0 1600.0 5.0 1600.0 5.0 1600.0 5.0 1600.0 5.0 1600.0 5.0 1600.0 1.5 10000.0 1.5 10000.0 1.5 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 Page 1 PLUME HT (M) ------ 219.77 77.27 30.21 19.68 19.68 23.19 30.21 30.21 30.21 35.47 35.47 35.47 35.47 51.27 51.27 51.27 51.27 51.27 51.27 80.86 80.86 80.86 91.24 91.24 91.24 SIGMA Y (M) ------ 4.26 19.88 24.01 22.79 29.61 36.37 43.14 49.55 55.90 62.34 68.54 74.69 80.79 87.35 93.33 99.27 105.18 111.06 116.91 93.62 97.87 102.10 106.94 111.13 115.30 SIGMA Z (M) ------ 4.25 19.60 14.68 12.42 15.56 18.73 22.05 24.78 27.45 30.41 32.96 34.94 36.87 39.86 41.64 43.37 45.07 46.74 48.38 38.35 39.26 40.07 42.43 43.20 43.95 DWASH ----- 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 2500. 2600. 2700. 2800. 2900. 3000. 3500. 4000. 4500. 5000. 5500. 6000. 6500. 7000. 7500. 8000. 8500. 9000. 9500. 10000. 15000. 20000. 25000. 30000. 40000. 50000. 0.5142 0.5228 0.5303 0.5369 0.5426 0.5474 0.5610 0.5613 0.5476 0.5551 0.5596 0.5604 0.5584 0.5542 0.5455 0.5362 0.5265 0.5165 0.5064 0.4963 0.4039 0.3301 0.2785 0.2404 0.1881 0.1545 C3608NOx.OUT 5 1.0 1.0 10000.0 91.24 119.46 44.69 NO 5 1.0 1.0 10000.0 91.24 123.62 45.43 NO 5 1.0 1.0 10000.0 91.24 127.76 46.16 NO 5 1.0 1.0 10000.0 91.24 131.89 46.88 NO 5 1.0 1.0 10000.0 91.24 136.00 47.59 NO 5 1.0 1.0 10000.0 91.24 140.11 48.30 NO 5 1.0 1.0 10000.0 91.24 160.48 51.73 NO 5 1.0 1.0 10000.0 91.24 180.59 55.02 NO 5 1.0 1.0 10000.0 91.24 200.46 57.79 NO 6 1.0 1.0 10000.0 77.27 146.97 39.36 NO 6 1.0 1.0 10000.0 77.27 159.88 40.71 NO 6 1.0 1.0 10000.0 77.27 172.68 42.01 NO 6 1.0 1.0 10000.0 77.27 185.37 43.27 NO 6 1.0 1.0 10000.0 77.27 197.95 44.49 NO 6 1.0 1.0 10000.0 77.27 210.44 45.53 NO 6 1.0 1.0 10000.0 77.27 222.84 46.55 NO 6 1.0 1.0 10000.0 77.27 235.15 47.53 NO 6 1.0 1.0 10000.0 77.27 247.37 48.48 NO 6 1.0 1.0 10000.0 77.27 259.52 49.40 NO 6 1.0 1.0 10000.0 77.27 271.60 50.30 NO 6 1.0 1.0 10000.0 77.27 388.91 58.23 NO 6 1.0 1.0 10000.0 77.27 501.33 63.36 NO 6 1.0 1.0 10000.0 77.27 610.06 67.71 NO 6 1.0 1.0 10000.0 77.27 715.85 71.53 NO 6 1.0 1.0 10000.0 77.27 920.43 76.99 NO 6 1.0 1.0 10000.0 77.27 1117.59 81.55 NO MAXIMUM 1-HR CONCENTRATION AT OR BEYOND 1. M: 329. 1.127 4 20.0 20.0 6400.0 19.68 24.87 13.41 NO DWASH= MEANS NO CALC MADE (CONC = 0.0) DWASH=NO MEANS NO BUILDING DOWNWASH USED DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB *************************************** *** SUMMARY OF SCREEN MODEL RESULTS *** *************************************** CALCULATION PROCEDURE -------------SIMPLE TERRAIN MAX CONC (UG/M**3) ----------- 1.127 DIST TO TERRAIN MAX (M) HT (M) --------- ------- 329. 0. Page 2 5794NOx.OUT 08/19/19 13:49:41 ***SCREEN3MODELRUN*** ***VERSIONDATED13043*** SpraberryNOxWaukesha5794GSI SIMPLETERRAININPUTS: SOURCETYPE=POINT EMISSIONRATE(G/S)=0.378000E01 STACKHEIGHT(M)=9.1440 STKINSIDEDIAM(M)=0.3048 STKEXITVELOCITY(M/S)=58.8660 STKGASEXITTEMP(K)=886.4833 AMBIENTAIRTEMP(K)=293.1500 RECEPTORHEIGHT(M)=0.0000 URBAN/RURALOPTION=RURAL BUILDINGHEIGHT(M)=0.0000 MINHORIZBLDGDIM(M)=0.0000 MAXHORIZBLDGDIM(M)=0.0000 THEREGULATORY(DEFAULT)MIXINGHEIGHTOPTIONWASSELECTED. THEREGULATORY(DEFAULT)ANEMOMETERHEIGHTOF10.0METERSWASENTERED. BUOY.FLUX=8.973M**4/S**3;MOM.FLUX=26.615M**4/S**2. ***FULLMETEOROLOGY*** ********************************** ***SCREENAUTOMATEDDISTANCES*** ********************************** ***TERRAINHEIGHTOF0.MABOVESTACKBASEUSEDFORFOLLOWINGDISTANCES*** DISTCONCU10MUSTKMIXHTPLUMESIGMASIGMA (M)(UG/M**3)STAB(M/S)(M/S)(M)HT(M)Y(M)Z(M)DWASH 1.0.00011.01.0320.0120.232.512.48NO 100.0.3948310.010.03200.020.2512.637.72NO 200.1.303310.010.03200.020.2523.8314.38NO 300.1.160415.015.04800.016.5522.7112.28NO 400.1.121410.010.03200.020.2529.6215.60NO 500.1.03748.08.02560.023.0336.3618.72NO 600.0.923045.05.01600.031.3643.1922.14NO 700.0.880845.05.01600.031.3649.6024.86NO 800.0.817444.54.51440.033.8356.0227.70NO 900.0.760144.04.01280.036.9162.3930.52NO Page1 5794NOx.OUT 1000.0.711244.04.01280.036.9168.5933.06NO 1100.0.665343.53.51120.040.8874.8635.31NO 1200.0.624243.53.51120.040.8880.9537.21NO 1300.0.588043.03.0960.046.1787.1639.45NO 1400.0.557843.03.0960.046.1793.1541.24NO 1500.0.528843.03.0960.046.1799.1142.99NO 1600.0.503051.01.010000.070.9280.1234.03NO 1700.0.522751.01.010000.070.9284.4435.00NO 1800.0.539451.01.010000.070.9288.7535.96NO 1900.0.553451.01.010000.070.9293.0436.92NO 2000.0.564851.01.010000.070.9297.3137.86NO 2100.0.570851.01.010000.070.92101.5738.69NO 2200.0.575151.01.010000.070.92105.8239.52NO 2300.0.577951.01.010000.070.92110.0540.34NO 2400.0.579451.01.010000.070.92114.2641.14NO 2500.0.579751.01.010000.070.92118.4641.94NO 2600.0.579051.01.010000.070.92122.6542.72NO 2700.0.583261.01.010000.060.4184.8429.38NO 2800.0.592261.01.010000.060.4187.6029.82NO 2900.0.600361.01.010000.060.4190.3430.26NO 3000.0.607461.01.010000.060.4193.0830.70NO 3500.0.615761.01.010000.060.41106.6632.47NO 4000.0.613561.01.010000.060.41120.0734.14NO 4500.0.604561.01.010000.060.41133.3135.71NO 5000.0.591461.01.010000.060.41146.4037.21NO 5500.0.575761.01.010000.060.41159.3738.64NO 6000.0.558761.01.010000.060.41172.2040.01NO 6500.0.541061.01.010000.060.41184.9241.33NO 7000.0.523261.01.010000.060.41197.5442.60NO 7500.0.504161.01.010000.060.41210.0543.69NO 8000.0.485961.01.010000.060.41222.4744.75NO 8500.0.468661.01.010000.060.41234.8045.77NO 9000.0.452161.01.010000.060.41247.0446.75NO 9500.0.436561.01.010000.060.41259.2147.71NO 10000.0.421761.01.010000.060.41271.3048.64NO 15000.0.309661.01.010000.060.41388.7056.80NO 20000.0.240961.01.010000.060.41501.1662.05NO 25000.0.196461.01.010000.060.41609.9366.49NO 30000.0.165361.01.010000.060.41715.7470.38NO 40000.0.125561.01.010000.060.41920.3475.92NO 50000.0.100961.01.010000.060.411117.5280.54NO MAXIMUM1HRCONCENTRATIONATORBEYOND1.M: 197.1.303310.010.03200.020.2523.6214.26NO DWASH=MEANSNOCALCMADE(CONC=0.0) DWASH=NOMEANSNOBUILDINGDOWNWASHUSED DWASH=HSMEANSHUBERSNYDERDOWNWASHUSED Page2 5794NOx.OUT DWASH=SSMEANSSCHULMANSCIREDOWNWASHUSED DWASH=NAMEANSDOWNWASHNOTAPPLICABLE,X<3*LB *************************************** ***SUMMARYOFSCREENMODELRESULTS*** *************************************** CALCULATIONMAXCONCDISTTOTERRAIN PROCEDURE(UG/M**3)MAX(M)HT(M) SIMPLETERRAIN1.303197.0. Page3 *** SCREEN3 MODEL RUN *** *** VERSION DATED 13043 *** C3516SO2.OUT 08/07/19 12:29:15 Newberry - SO2 - Caterpillar 3516LB SIMPLE TERRAIN INPUTS: SOURCE TYPE = EMISSION RATE (G/S) = STACK HEIGHT (M) = STK INSIDE DIAM (M) = STK EXIT VELOCITY (M/S)= STK GAS EXIT TEMP (K) = AMBIENT AIR TEMP (K) = RECEPTOR HEIGHT (M) = URBAN/RURAL OPTION = BUILDING HEIGHT (M) = MIN HORIZ BLDG DIM (M) = MAX HORIZ BLDG DIM (M) = POINT 0.800000E-03 9.1440 0.3048 58.8659 806.4833 293.1500 0.0000 RURAL 0.0000 0.0000 0.0000 THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED. THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED. BUOY. FLUX = 8.534 M**4/S**3; MOM. FLUX = 29.254 M**4/S**2. *** FULL METEOROLOGY *** ********************************** *** SCREEN AUTOMATED DISTANCES *** ********************************** *** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES *** DIST (M) ------1. 100. 200. 300. 400. 500. 600. 700. 800. 900. 1000. 1100. 1200. 1300. 1400. 1500. 1600. 1700. 1800. 1900. 2000. 2100. 2200. 2300. 2400. CONC (UG/M**3) ---------- 0.000 0.9536E-02 0.2866E-01 0.2528E-01 0.2452E-01 0.2268E-01 0.2053E-01 0.1941E-01 0.1799E-01 0.1674E-01 0.1562E-01 0.1462E-01 0.1368E-01 0.1295E-01 0.1225E-01 0.1158E-01 0.1118E-01 0.1160E-01 0.1195E-01 0.1224E-01 0.1247E-01 0.1259E-01 0.1266E-01 0.1271E-01 0.1273E-01 STAB ---- 1 3 3 4 4 4 4 4 4 4 4 4 4 4 4 4 5 5 5 5 5 5 5 5 5 U10M (M/S) ----- 1.0 10.0 10.0 15.0 10.0 8.0 5.0 5.0 4.5 4.0 3.5 3.5 3.0 3.0 3.0 3.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 USTK MIX HT (M/S) (M) ----- ------ 1.0 320.0 10.0 3200.0 10.0 3200.0 15.0 4800.0 10.0 3200.0 8.0 2560.0 5.0 1600.0 5.0 1600.0 4.5 1440.0 4.0 1280.0 3.5 1120.0 3.5 1120.0 3.0 960.0 3.0 960.0 3.0 960.0 3.0 960.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 Page 1 PLUME HT (M) ------ 116.12 19.84 19.84 16.28 19.84 22.52 30.54 30.54 32.92 35.89 39.71 39.71 44.80 44.80 44.80 44.80 69.89 69.89 69.89 69.89 69.89 69.89 69.89 69.89 69.89 SIGMA Y (M) ------ 2.59 12.62 23.82 22.70 29.61 36.35 43.15 49.57 55.99 62.35 68.68 74.82 81.08 87.12 93.11 99.07 80.05 84.38 88.69 92.98 97.26 101.52 105.77 110.00 114.22 SIGMA Z (M) ------ 2.56 7.71 14.36 12.26 15.57 18.69 22.07 24.80 27.63 30.44 33.26 35.22 37.50 39.34 41.14 42.90 33.88 34.85 35.82 36.78 37.72 38.56 39.39 40.21 41.02 DWASH ----- 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 2500. 0.1272E-01 5 2600. 0.1272E-01 6 2700. 0.1293E-01 6 2800. 0.1312E-01 6 2900. 0.1329E-01 6 3000. 0.1343E-01 6 3500. 0.1357E-01 6 4000. 0.1348E-01 6 4500. 0.1325E-01 6 5000. 0.1294E-01 6 5500. 0.1257E-01 6 6000. 0.1218E-01 6 6500. 0.1177E-01 6 7000. 0.1137E-01 6 7500. 0.1094E-01 6 8000. 0.1054E-01 6 8500. 0.1015E-01 6 9000. 0.9786E-02 6 9500. 0.9440E-02 6 10000. 0.9113E-02 6 15000. 0.6656E-02 6 20000. 0.5167E-02 6 25000. 0.4205E-02 6 30000. 0.3535E-02 6 40000. 0.2680E-02 6 50000. 0.2153E-02 6 C3516SO2.OUT 1.0 1.0 10000.0 69.89 118.42 41.82 NO 1.0 1.0 10000.0 59.55 82.04 28.81 NO 1.0 1.0 10000.0 59.55 84.80 29.26 NO 1.0 1.0 10000.0 59.55 87.56 29.71 NO 1.0 1.0 10000.0 59.55 90.31 30.15 NO 1.0 1.0 10000.0 59.55 93.04 30.58 NO 1.0 1.0 10000.0 59.55 106.63 32.36 NO 1.0 1.0 10000.0 59.55 120.04 34.03 NO 1.0 1.0 10000.0 59.55 133.28 35.61 NO 1.0 1.0 10000.0 59.55 146.38 37.12 NO 1.0 1.0 10000.0 59.55 159.34 38.55 NO 1.0 1.0 10000.0 59.55 172.18 39.92 NO 1.0 1.0 10000.0 59.55 184.90 41.24 NO 1.0 1.0 10000.0 59.55 197.52 42.52 NO 1.0 1.0 10000.0 59.55 210.03 43.61 NO 1.0 1.0 10000.0 59.55 222.45 44.67 NO 1.0 1.0 10000.0 59.55 234.78 45.69 NO 1.0 1.0 10000.0 59.55 247.03 46.68 NO 1.0 1.0 10000.0 59.55 259.19 47.64 NO 1.0 1.0 10000.0 59.55 271.29 48.57 NO 1.0 1.0 10000.0 59.55 388.69 56.74 NO 1.0 1.0 10000.0 59.55 501.16 61.99 NO 1.0 1.0 10000.0 59.55 609.92 66.44 NO 1.0 1.0 10000.0 59.55 715.73 70.33 NO 1.0 1.0 10000.0 59.55 920.34 75.87 NO 1.0 1.0 10000.0 59.55 1117.52 80.49 NO MAXIMUM 1-HR CONCENTRATION AT OR BEYOND 1. M: 193. 0.2872E-01 3 10.0 10.0 3200.0 19.84 23.17 13.98 NO DWASH= MEANS NO CALC MADE (CONC = 0.0) DWASH=NO MEANS NO BUILDING DOWNWASH USED DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB *************************************** *** SUMMARY OF SCREEN MODEL RESULTS *** *************************************** CALCULATION PROCEDURE -------------SIMPLE TERRAIN MAX CONC (UG/M**3) ----------- 0.2872E-01 DIST TO TERRAIN MAX (M) HT (M) --------- ------- 193. 0. Page 2 *** SCREEN3 MODEL RUN *** *** VERSION DATED 13043 *** C3606SO2.OUT 08/07/19 12:30:47 Newberry - SO2 - Caterpillar 3606 SIMPLE TERRAIN INPUTS: SOURCE TYPE = EMISSION RATE (G/S) = STACK HEIGHT (M) = STK INSIDE DIAM (M) = STK EXIT VELOCITY (M/S)= STK GAS EXIT TEMP (K) = AMBIENT AIR TEMP (K) = RECEPTOR HEIGHT (M) = URBAN/RURAL OPTION = BUILDING HEIGHT (M) = MIN HORIZ BLDG DIM (M) = MAX HORIZ BLDG DIM (M) = POINT 0.130000E-02 9.1440 0.3048 88.0878 720.9278 293.1500 0.0000 RURAL 0.0000 0.0000 0.0000 THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED. THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED. BUOY. FLUX = 11.904 M**4/S**3; MOM. FLUX = 73.282 M**4/S**2. *** FULL METEOROLOGY *** ********************************** *** SCREEN AUTOMATED DISTANCES *** ********************************** *** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES *** DIST (M) ------1. 100. 200. 300. 400. 500. 600. 700. 800. 900. 1000. 1100. 1200. 1300. 1400. 1500. 1600. 1700. 1800. 1900. 2000. 2100. 2200. 2300. 2400. CONC (UG/M**3) ---------- 0.000 0.5540E-02 0.3433E-01 0.3282E-01 0.3083E-01 0.2881E-01 0.2663E-01 0.2400E-01 0.2235E-01 0.2117E-01 0.1977E-01 0.1851E-01 0.1737E-01 0.1639E-01 0.1548E-01 0.1474E-01 0.1402E-01 0.1362E-01 0.1418E-01 0.1468E-01 0.1511E-01 0.1538E-01 0.1561E-01 0.1579E-01 0.1594E-01 STAB ---- 1 3 3 4 4 4 4 4 4 4 4 4 4 4 4 4 4 5 5 5 5 5 5 5 5 U10M (M/S) ----- 1.0 10.0 10.0 15.0 10.0 10.0 8.0 8.0 5.0 5.0 4.5 4.5 4.0 4.0 3.5 3.5 3.5 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 USTK MIX HT (M/S) (M) ----- ------ 1.0 320.0 10.0 3200.0 10.0 3200.0 15.0 4800.0 10.0 3200.0 10.0 3200.0 8.0 2560.0 8.0 2560.0 5.0 1600.0 5.0 1600.0 4.5 1440.0 4.5 1440.0 4.0 1280.0 4.0 1280.0 3.5 1120.0 3.5 1120.0 3.5 1120.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 Page 1 PLUME HT (M) ------ 146.45 22.88 22.88 18.30 22.88 22.88 26.31 26.31 36.61 36.61 39.66 39.66 43.47 43.47 48.38 48.38 48.38 77.02 77.02 77.02 77.02 77.02 77.02 77.02 77.02 SIGMA Y (M) ------ 3.53 12.66 23.89 22.76 29.71 36.36 43.00 49.43 56.12 62.38 68.68 74.82 81.04 87.07 93.23 99.18 105.09 84.82 89.11 93.38 97.64 101.89 106.12 110.34 114.54 SIGMA Z (M) ------ 3.51 7.77 14.48 12.37 15.77 18.71 21.77 24.53 27.91 30.49 33.26 35.22 37.40 39.25 41.40 43.15 44.86 35.91 36.85 37.78 38.70 39.52 40.33 41.13 41.92 DWASH ----- 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 2500. 0.1604E-01 5 2600. 0.1612E-01 5 2700. 0.1616E-01 5 2800. 0.1619E-01 5 2900. 0.1618E-01 5 3000. 0.1616E-01 5 3500. 0.1661E-01 6 4000. 0.1683E-01 6 4500. 0.1682E-01 6 5000. 0.1667E-01 6 5500. 0.1641E-01 6 6000. 0.1609E-01 6 6500. 0.1572E-01 6 7000. 0.1533E-01 6 7500. 0.1487E-01 6 8000. 0.1442E-01 6 8500. 0.1398E-01 6 9000. 0.1356E-01 6 9500. 0.1316E-01 6 10000. 0.1276E-01 6 15000. 0.9665E-02 6 20000. 0.7630E-02 6 25000. 0.6282E-02 6 30000. 0.5326E-02 6 40000. 0.4079E-02 6 50000. 0.3300E-02 6 C3606SO2.OUT 1.0 1.0 10000.0 77.02 118.73 42.70 NO 1.0 1.0 10000.0 77.02 122.91 43.47 NO 1.0 1.0 10000.0 77.02 127.07 44.23 NO 1.0 1.0 10000.0 77.02 131.22 44.98 NO 1.0 1.0 10000.0 77.02 135.36 45.73 NO 1.0 1.0 10000.0 77.02 139.49 46.46 NO 1.0 1.0 10000.0 65.47 106.87 33.15 NO 1.0 1.0 10000.0 65.47 120.25 34.78 NO 1.0 1.0 10000.0 65.47 133.48 36.33 NO 1.0 1.0 10000.0 65.47 146.56 37.80 NO 1.0 1.0 10000.0 65.47 159.51 39.21 NO 1.0 1.0 10000.0 65.47 172.33 40.56 NO 1.0 1.0 10000.0 65.47 185.04 41.86 NO 1.0 1.0 10000.0 65.47 197.65 43.12 NO 1.0 1.0 10000.0 65.47 210.16 44.20 NO 1.0 1.0 10000.0 65.47 222.57 45.24 NO 1.0 1.0 10000.0 65.47 234.89 46.25 NO 1.0 1.0 10000.0 65.47 247.13 47.23 NO 1.0 1.0 10000.0 65.47 259.29 48.17 NO 1.0 1.0 10000.0 65.47 271.38 49.10 NO 1.0 1.0 10000.0 65.47 388.76 57.19 NO 1.0 1.0 10000.0 65.47 501.21 62.41 NO 1.0 1.0 10000.0 65.47 609.96 66.82 NO 1.0 1.0 10000.0 65.47 715.77 70.69 NO 1.0 1.0 10000.0 65.47 920.36 76.21 NO 1.0 1.0 10000.0 65.47 1117.54 80.81 NO MAXIMUM 1-HR CONCENTRATION AT OR BEYOND 1. M: 225. 0.3520E-01 3 10.0 10.0 3200.0 22.88 26.71 16.16 NO DWASH= MEANS NO CALC MADE (CONC = 0.0) DWASH=NO MEANS NO BUILDING DOWNWASH USED DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB *************************************** *** SUMMARY OF SCREEN MODEL RESULTS *** *************************************** CALCULATION PROCEDURE -------------SIMPLE TERRAIN MAX CONC (UG/M**3) ----------- 0.3520E-01 DIST TO TERRAIN MAX (M) HT (M) --------- ------- 225. 0. Page 2 *** SCREEN3 MODEL RUN *** *** VERSION DATED 13043 *** C3608SO2.OUT 08/07/19 12:32:24 Spraberry - SO2 - Caterpillar 3608A4 SIMPLE TERRAIN INPUTS: SOURCE TYPE = EMISSION RATE (G/S) = STACK HEIGHT (M) = STK INSIDE DIAM (M) = STK EXIT VELOCITY (M/S)= STK GAS EXIT TEMP (K) = AMBIENT AIR TEMP (K) = RECEPTOR HEIGHT (M) = URBAN/RURAL OPTION = BUILDING HEIGHT (M) = MIN HORIZ BLDG DIM (M) = MAX HORIZ BLDG DIM (M) = POINT 0.900000E-03 9.1440 0.4054 78.5624 725.9278 293.1500 0.0000 RURAL 0.0000 0.0000 0.0000 THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED. THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED. BUOY. FLUX = 18.871 M**4/S**3; MOM. FLUX = 102.408 M**4/S**2. *** FULL METEOROLOGY *** ********************************** *** SCREEN AUTOMATED DISTANCES *** ********************************** *** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES *** DIST (M) ------1. 100. 200. 300. 400. 500. 600. 700. 800. 900. 1000. 1100. 1200. 1300. 1400. 1500. 1600. 1700. 1800. 1900. 2000. 2100. 2200. 2300. 2400. CONC (UG/M**3) ---------- 0.000 0.4107E-03 0.1218E-01 0.1598E-01 0.1526E-01 0.1399E-01 0.1300E-01 0.1201E-01 0.1116E-01 0.1034E-01 0.9496E-02 0.8705E-02 0.8346E-02 0.7970E-02 0.7592E-02 0.7222E-02 0.6866E-02 0.6566E-02 0.6282E-02 0.6424E-02 0.6626E-02 0.6822E-02 0.6998E-02 0.7156E-02 0.7295E-02 STAB ---- 1 3 3 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 5 5 5 5 5 5 U10M (M/S) ----- 1.0 10.0 10.0 20.0 15.0 15.0 10.0 10.0 8.0 8.0 8.0 5.0 5.0 5.0 5.0 5.0 5.0 4.5 4.5 1.5 1.0 1.0 1.0 1.0 1.0 USTK MIX HT (M/S) (M) ----- ------ 1.0 320.0 10.0 3200.0 10.0 3200.0 20.0 6400.0 15.0 4800.0 15.0 4800.0 10.0 3200.0 10.0 3200.0 8.0 2560.0 8.0 2560.0 8.0 2560.0 5.0 1600.0 5.0 1600.0 5.0 1600.0 5.0 1600.0 5.0 1600.0 5.0 1600.0 4.5 1440.0 4.5 1440.0 1.5 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 Page 1 PLUME HT (M) ------ 203.13 28.54 28.54 18.84 22.08 22.08 28.54 28.54 33.39 33.39 33.39 47.94 47.94 47.94 47.94 47.94 47.94 52.25 52.25 78.28 88.29 88.29 88.29 88.29 88.29 SIGMA Y (M) ------ 3.93 12.74 23.98 22.77 29.69 36.33 43.08 49.50 56.00 62.27 68.48 75.13 81.20 87.23 93.21 99.16 105.08 111.09 116.94 93.46 98.33 102.55 106.76 110.95 115.13 SIGMA Z (M) ------ 3.92 7.89 14.63 12.40 15.71 18.67 21.92 24.67 27.66 30.27 32.83 35.88 37.76 39.58 41.37 43.12 44.83 46.82 48.45 37.97 40.41 41.20 41.97 42.74 43.50 DWASH ----- 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 2500. 0.7418E-02 5 2600. 0.7524E-02 5 2700. 0.7617E-02 5 2800. 0.7695E-02 5 2900. 0.7761E-02 5 3000. 0.7814E-02 5 3500. 0.7937E-02 5 4000. 0.7880E-02 5 4500. 0.7856E-02 6 5000. 0.7949E-02 6 5500. 0.7978E-02 6 6000. 0.7956E-02 6 6500. 0.7897E-02 6 7000. 0.7811E-02 6 7500. 0.7666E-02 6 8000. 0.7515E-02 6 8500. 0.7360E-02 6 9000. 0.7204E-02 6 9500. 0.7048E-02 6 10000. 0.6893E-02 6 15000. 0.5527E-02 6 20000. 0.4485E-02 6 25000. 0.3764E-02 6 30000. 0.3237E-02 6 40000. 0.2521E-02 6 50000. 0.2064E-02 6 C3608SO2.OUT 1.0 1.0 10000.0 88.29 119.30 44.26 NO 1.0 1.0 10000.0 88.29 123.46 45.00 NO 1.0 1.0 10000.0 88.29 127.61 45.74 NO 1.0 1.0 10000.0 88.29 131.74 46.46 NO 1.0 1.0 10000.0 88.29 135.86 47.18 NO 1.0 1.0 10000.0 88.29 139.97 47.90 NO 1.0 1.0 10000.0 88.29 160.36 51.36 NO 1.0 1.0 10000.0 88.29 180.48 54.66 NO 1.0 1.0 10000.0 74.82 133.82 37.59 NO 1.0 1.0 10000.0 74.82 146.87 39.02 NO 1.0 1.0 10000.0 74.82 159.80 40.38 NO 1.0 1.0 10000.0 74.82 172.60 41.69 NO 1.0 1.0 10000.0 74.82 185.29 42.96 NO 1.0 1.0 10000.0 74.82 197.88 44.18 NO 1.0 1.0 10000.0 74.82 210.38 45.24 NO 1.0 1.0 10000.0 74.82 222.78 46.26 NO 1.0 1.0 10000.0 74.82 235.09 47.24 NO 1.0 1.0 10000.0 74.82 247.32 48.20 NO 1.0 1.0 10000.0 74.82 259.47 49.13 NO 1.0 1.0 10000.0 74.82 271.55 50.04 NO 1.0 1.0 10000.0 74.82 388.88 58.00 NO 1.0 1.0 10000.0 74.82 501.30 63.15 NO 1.0 1.0 10000.0 74.82 610.04 67.52 NO 1.0 1.0 10000.0 74.82 715.83 71.35 NO 1.0 1.0 10000.0 74.82 920.41 76.82 NO 1.0 1.0 10000.0 74.82 1117.58 81.38 NO MAXIMUM 1-HR CONCENTRATION AT OR BEYOND 1. M: 312. 0.1602E-01 4 20.0 20.0 6400.0 18.84 23.67 12.82 NO DWASH= MEANS NO CALC MADE (CONC = 0.0) DWASH=NO MEANS NO BUILDING DOWNWASH USED DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB *************************************** *** SUMMARY OF SCREEN MODEL RESULTS *** *************************************** CALCULATION PROCEDURE -------------SIMPLE TERRAIN MAX CONC (UG/M**3) ----------- 0.1602E-01 DIST TO TERRAIN MAX (M) HT (M) --------- ------- 312. 0. Page 2 *** SCREEN3 MODEL RUN *** *** VERSION DATED 13043 *** 5794SO2.OUT 08/07/19 14:10:17 Spraberry - SO2 - Waukesha 5794GSI SIMPLE TERRAIN INPUTS: SOURCE TYPE = EMISSION RATE (G/S) = STACK HEIGHT (M) = STK INSIDE DIAM (M) = STK EXIT VELOCITY (M/S)= STK GAS EXIT TEMP (K) = AMBIENT AIR TEMP (K) = RECEPTOR HEIGHT (M) = URBAN/RURAL OPTION = BUILDING HEIGHT (M) = MIN HORIZ BLDG DIM (M) = MAX HORIZ BLDG DIM (M) = POINT 0.130000E-02 9.1440 0.3048 58.8660 886.4833 293.1500 0.0000 RURAL 0.0000 0.0000 0.0000 THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED. THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED. BUOY. FLUX = 8.973 M**4/S**3; MOM. FLUX = 26.615 M**4/S**2. *** FULL METEOROLOGY *** ********************************** *** SCREEN AUTOMATED DISTANCES *** ********************************** *** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES *** DIST (M) ------1. 100. 200. 300. 400. 500. 600. 700. 800. 900. 1000. 1100. 1200. 1300. 1400. 1500. 1600. 1700. 1800. 1900. 2000. 2100. 2200. 2300. 2400. CONC (UG/M**3) ---------- 0.000 0.1358E-01 0.4480E-01 0.3989E-01 0.3854E-01 0.3566E-01 0.3174E-01 0.3029E-01 0.2811E-01 0.2614E-01 0.2446E-01 0.2288E-01 0.2147E-01 0.2022E-01 0.1919E-01 0.1819E-01 0.1730E-01 0.1798E-01 0.1855E-01 0.1903E-01 0.1943E-01 0.1963E-01 0.1978E-01 0.1988E-01 0.1993E-01 STAB ---- 1 3 3 4 4 4 4 4 4 4 4 4 4 4 4 4 5 5 5 5 5 5 5 5 5 U10M (M/S) ----- 1.0 10.0 10.0 15.0 10.0 8.0 5.0 5.0 4.5 4.0 4.0 3.5 3.5 3.0 3.0 3.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 USTK MIX HT (M/S) (M) ----- ------ 1.0 320.0 10.0 3200.0 10.0 3200.0 15.0 4800.0 10.0 3200.0 8.0 2560.0 5.0 1600.0 5.0 1600.0 4.5 1440.0 4.0 1280.0 4.0 1280.0 3.5 1120.0 3.5 1120.0 3.0 960.0 3.0 960.0 3.0 960.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 1.0 10000.0 Page 1 PLUME HT (M) ------ 120.23 20.25 20.25 16.55 20.25 23.03 31.36 31.36 33.83 36.91 36.91 40.88 40.88 46.17 46.17 46.17 70.92 70.92 70.92 70.92 70.92 70.92 70.92 70.92 70.92 SIGMA Y (M) ------ 2.51 12.63 23.83 22.71 29.62 36.36 43.19 49.60 56.02 62.39 68.59 74.86 80.95 87.16 93.15 99.11 80.12 84.44 88.75 93.04 97.31 101.57 105.82 110.05 114.26 SIGMA Z (M) ------ 2.48 7.72 14.38 12.28 15.60 18.72 22.14 24.86 27.70 30.52 33.06 35.31 37.21 39.45 41.24 42.99 34.03 35.00 35.96 36.92 37.86 38.69 39.52 40.34 41.14 DWASH ----- 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 2500. 0.1994E-01 5 2600. 0.1991E-01 5 2700. 0.2006E-01 6 2800. 0.2037E-01 6 2900. 0.2064E-01 6 3000. 0.2089E-01 6 3500. 0.2117E-01 6 4000. 0.2110E-01 6 4500. 0.2079E-01 6 5000. 0.2034E-01 6 5500. 0.1980E-01 6 6000. 0.1921E-01 6 6500. 0.1861E-01 6 7000. 0.1799E-01 6 7500. 0.1734E-01 6 8000. 0.1671E-01 6 8500. 0.1612E-01 6 9000. 0.1555E-01 6 9500. 0.1501E-01 6 10000. 0.1450E-01 6 15000. 0.1065E-01 6 20000. 0.8285E-02 6 25000. 0.6754E-02 6 30000. 0.5684E-02 6 40000. 0.4315E-02 6 50000. 0.3470E-02 6 5794SO2.OUT 1.0 1.0 10000.0 70.92 118.46 41.94 NO 1.0 1.0 10000.0 70.92 122.65 42.72 NO 1.0 1.0 10000.0 60.41 84.84 29.38 NO 1.0 1.0 10000.0 60.41 87.60 29.82 NO 1.0 1.0 10000.0 60.41 90.34 30.26 NO 1.0 1.0 10000.0 60.41 93.08 30.70 NO 1.0 1.0 10000.0 60.41 106.66 32.47 NO 1.0 1.0 10000.0 60.41 120.07 34.14 NO 1.0 1.0 10000.0 60.41 133.31 35.71 NO 1.0 1.0 10000.0 60.41 146.40 37.21 NO 1.0 1.0 10000.0 60.41 159.37 38.64 NO 1.0 1.0 10000.0 60.41 172.20 40.01 NO 1.0 1.0 10000.0 60.41 184.92 41.33 NO 1.0 1.0 10000.0 60.41 197.54 42.60 NO 1.0 1.0 10000.0 60.41 210.05 43.69 NO 1.0 1.0 10000.0 60.41 222.47 44.75 NO 1.0 1.0 10000.0 60.41 234.80 45.77 NO 1.0 1.0 10000.0 60.41 247.04 46.75 NO 1.0 1.0 10000.0 60.41 259.21 47.71 NO 1.0 1.0 10000.0 60.41 271.30 48.64 NO 1.0 1.0 10000.0 60.41 388.70 56.80 NO 1.0 1.0 10000.0 60.41 501.16 62.05 NO 1.0 1.0 10000.0 60.41 609.93 66.49 NO 1.0 1.0 10000.0 60.41 715.74 70.38 NO 1.0 1.0 10000.0 60.41 920.34 75.92 NO 1.0 1.0 10000.0 60.41 1117.52 80.54 NO MAXIMUM 1-HR CONCENTRATION AT OR BEYOND 1. M: 197. 0.4482E-01 3 10.0 10.0 3200.0 20.25 23.62 14.26 NO DWASH= MEANS NO CALC MADE (CONC = 0.0) DWASH=NO MEANS NO BUILDING DOWNWASH USED DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB *************************************** *** SUMMARY OF SCREEN MODEL RESULTS *** *************************************** CALCULATION PROCEDURE -------------SIMPLE TERRAIN MAX CONC (UG/M**3) ----------- 0.4482E-01 DIST TO TERRAIN MAX (M) HT (M) --------- ------- 197. 0. Page 2 Newberry Gas Plant /Enterprise Midland Basin Midstream LLC Inspection Date 12/19/2024 Appendix C.1 TCEQ Final Action 9-24-2019 Jon ietmann, Chairman Emily Lindley, Commissioner Bobby Janecka, Commissioner Toby Baker, ExecutiYe Director TExAS COMMISSION ON ENVIRONMENTAL QUALITY Protecting Texas by Reducing and Preventing Pollution September 24, 2019 Ms. Michelle Mccracken Manager - Eh&s Navitas Midstream Midland Basin, LLC 9303 New Trails Dr Ste 400 The Woodlands, TX 77381 Standard Permit Registration Number: 141647 Navitas Midstream Midland Basin, LLC Project Description/Unit: Newberry Gas Plant City: Midland, Midland County Regulated Entity Number: RN109272526 Customer Reference Number: CN604937243 Oil and Gas Standard Permit (Non-rule) Effective Date: 11/08/2012 This is in response to your standard permit registration submitted through the online ePermits process for the proposed facility located near Midland, Midland County. Based on the information submitted and review completed by the ePermits process, this is an acknowledgement that Navitas Midstream Midland Basin, LLC has certified emissions associated with Newberry Gas Plant under the standard permit listed above. For rule information see:www.tceq.texas.gov/permitting/air/nav/standard.html. Records must be maintained in accordance to the standard permit to demonstrate compliance. As a reminder, regardless of the authorization mechanism, all facilities must be in compliance and operate in accordance with all rules and regulations of the TCEQ and the U.S. Environmental Protection Agency. Facilities not operating in accordance with these rules and regulations, in accordance with the authorization, or that misrepresented or failed to fully disclose all relevant facts in obtaining this authorization may be subject to formal enforcement action. If you need further information or have questions, please contact the Rule Registrations Section at (512) 2391250 or write to the Texas Commission on Environmental Quality, Office of Air, Air Permits Division, MC-163, P.O. Box 13087, Austin, Texas 78711-3087. This action is taken under authority delegated by the Executive Director of the TCEQ. Sincerely, Mark Meyer, Manager Rule Registrations Section Air Permits Division Texas Commission on Environmental Quality P.O. Box 13087 * Austin, Texas 78711-3087 * 512-239-1000 * tceq.texas.gov How is our customer service? tceq.texas.gov/customersurvey Newberry Gas Plant /Enterprise Midland Basin Midstream LLC Inspection Date 12/19/2024 Appendix C.2 TCEQ Non-Rule Standard Permit Air Quality Standard Permit for Oil and Gas Handling and Production Facilities Effective November 8, 2012 (a) Applicability. This standard permit applies to all stationary facilities, or groups of facilities, at a site which handle gases and liquids associated with the production, conditioning, processing, and pipeline transfer of fluids or gases found in geologic formations on or beneath the earth's surface including, but not limited to, crude oil, natural gas, condensate, and produced water with the following conditions. (1) The requirements in paragraphs (a)-(k) of this standard permit are applicable in only for new projects and dependent facilities located in the Barnett Shale (Cooke, Dallas, Denton, Ellis, Erath, Hill, Hood, Jack, Johnson, Montague, Palo Pinto, Parker, Somervell, Tarrant, and Wise Counties) on or after April 1, 2011. For all other new projects and dependent facilities in all other counties of the state, paragraph (l) of this standard permit is applicable. (2) Only one Air Quality Standard Permit for Oil and Gas Handling and Production Facilities for an oil and gas site (OGS) may be registered for a combination of dependent facilities and authorizes all facilities in sweet or sour service. This standard permit may not be used if operationally dependent facilities are authorized by the permit by rule in Title 30, Texas Administrative Code (30 TAC) 106.352, Oil and Gas Handling and Production Facilities, or a permit under 30 TAC 116.111,General Application. Existing authorized facilities, or groups of facilities, at an OGS under this standard permit which are not changing certified character or quantity of emissions must only meet subsections (i) and (k) of this standard permit (protectiveness review and planned maintenance, startup, and shutdown (MSS) requirements) and otherwise retain their existing authorization. Other facilities which are not covered under this standard permit may be authorized by other authorizations at an OGS if (b)(6) and (k) of this standard permit are met. (3) This standard permit does not relieve the owner or operator from complying with any other applicable provision of the Texas Health and Safety Code, Texas Water Code, rules of the Texas Commission on Environmental Quality (TCEQ), or any additional local, state or federal regulations. Emissions that exceed the limits in this standard permit are not authorized and are violations. (4) Emissions from upsets, emergencies, or malfunctions are not authorized by this standard permit. This standard permit does not regulate methane, ethane, or carbon dioxide. Page 1 of 67 (b) Definitions and Scope. (1) Facility is a discrete or identifiable structure, device, item, equipment, or enclosure that constitutes or contains a stationary source. Stationary sources associated with a mine, quarry, or well test lasting less than 72 hours are not considered facilities. (2) Receptor includes any building which is in use as a single or multi-family residence, school, day-care, hospital, business, or place of worship at the time this standard permit is registered. A residence is a structure primarily used as a permanent dwelling. A business is a structure that is occupied for at least 8 hours a day, 5 days a week, and does not include businesses who are handling or processing materials as described in subsection (a). This term does not include structures occupied or used solely by the owner or operator of the oil and gas facility, or the mineral rights owner of the property upon which the facility is located. All measurements of distance to receptors shall be taken from the emission release point at the oil and gas facility that is nearest to the point on the building that is nearest to the oil and gas facility. (3) An OGS is defined as all facilities which meet the following: (A) Located on contiguous or adjacent properties; (B) Under common control of the same person (or persons under common control); and (C) Designated under same 2-digit standard industrial classification (SIC) codes. (4) For purposes of determining applicability of 30 TAC Chapter 122, Federal Operating Permits, the definitions of 30 TAC 122.10, General Definitions, apply. (5) A project under this standard permit is defined as the following and must meet all requirements of this standard permit prior to construction or implementation of changes. (A) Any new facility or new group of operationally dependent facilities at an OGS; or (B) Physical changes to existing authorized facilities or group of facilities at an OGS which increase the potential to emit over previously registered emission limits; or (C) Operational changes to existing authorized facilities or group of facilities at an OGS which increase the potential to emit over previously registered emission limits. (6) For purposes of registration under this standard permit, the following facilities shall be included: (A) All facilities or groups of facilities at an OGS which are operationally dependent on each other; Page 2 of 67 (B) Facilities must be located within a 1/4 mile of a project emission point, vent, or fugitive component, except for those components excluded in (b)(6)(C) of this standard permit; (C) If piping or fugitive components are the only connection between facilities and the distance between facilities exceeds 1/4 mile, then the facilities are considered separate for purposes of this registration; (D) The boundaries of the registration become fixed at the time this standard permit is registered. No individual facility may be authorized under more than one registration; (E) Any facility or group of facilities authorized under an existing standard permit registration which is operationally dependent on a project must be revised to incorporate the project; and (F) A registration may include facilities which are claiming 30 TAC 116.620, Installation and/or Modification of Oil and Gas Facilities as well as projects which are claiming this standard permit. Existing authorized facilities, or group of facilities, at an OGS under this standard permit which are not changing registered and certified character or quantity of emissions must only meet paragraphs (i) and (k) of this standard permit (the protectiveness review and planned maintenance, startup, and shutdown (MSS) requirements) until the registration is renewed after December 31, 2015, after which paragraphs (a) - (k) of this standard permit apply. (7) For purposes of all previous claims of this standard permit (or any previous version of this standard permit) where no project is occurring: (A) Existing authorized facilities, or group of facilities, which have not registered planned MSS activity emissions prior to the effective dates in (a)(1) of this standard permit must meet paragraph (i) of this standard permit (planned MSS) no later than January 5, 2012; or (B) Existing authorized facilities, or group of facilities, which have registered planned MSS activity emissions and compliance with 30 TAC 116.620(a)(1) has been demonstrated prior to the effective dates in (a)(1) of this standard permit, must meet paragraph (i) of this standard permit (planned MSS) no later than the registration renewal submitted after December 31, 2015. (8) For purposes of ensuring protection of public health and welfare and demonstrating compliance with applicable ambient air standards and effects screening levels, the impacts analysis as specified in paragraph (k) of this standard permit must be completed. (A) All impacts analysis must be done on a contaminant-bycontaminant basis for any net project increases. If a claim under this standard permit is only for planned MSS under paragraph (i) of this standard permit, the analysis shall evaluate planned MSS scenarios only. Page 3 of 67 (B) Hourly and annual emissions shall be limited based on the most stringent of paragraphs (h) or (k) of this standard permit. (c) Authorized Facilities, Changes and Activities. (1) For existing OGS which are authorized by previous versions of this standard permit: (A) A project requires registration unless otherwise specified. (B) The following projects do not require registration, but must comply with best management practices in paragraph (e) of this standard permit, compliance demonstrations in paragraphs (i) and (j) of this standard permit and must be incorporated into the registration at the next revision or certification: (i) Addition of any piping, fugitive components, any other new facilities that increase registered emissions less than or equal to 1.0 tpy volatile organic compounds (VOC), 5.0 tpy nitrogen oxides (NOx), 0.01 tpy benzene, and 0.05 tpy hydrogen sulfide (H2S) over a rolling 12-month period; (ii) Changes to any existing facilities that increase registered emissions less than or equal to 1.0 tpy VOC, 5.0 tpy nitrogen oxides (NOx), 0.01 tpy benzene, and 0.05 tpy H2S over a rolling 12-month period; or (iii) Total increases over a rolling 60-month period that are less than or equal to 5.0 tpy VOC or NOX, 0.05 tpy benzene, or 0.1 tpy H2S; or (iv) Addition of any new engine rated less than 100 horsepower (hp); or (v) Replacement of any facility if the new facility does not increase the previous registered emissions. (C) In lieu of registering proposed changes under this standard permit, incremental emissions increases associated with construction of new facilities or changes to existing facilities may be authorized by 30 TAC 106.261, Facilities (Emission Limitations) or 106.262, Facilities (Emissions and Distance Limitations), if the maximum worst-case emissions also meet the limitations established by paragraphs (b)(8) and (k) of this standard permit for all air contaminants with proposed increases. (2) All authorizations under this standard permit shall meet the following: (A) New, changed, or replacement facilities shall not exceed the thresholds for major source or major modification as defined in 30 TAC 116.12, Nonattainment and Prevention of Significant Deterioration Review Definitions, and in Federal Clean Air Act 112(g) or 112(j); (B) All facilities shall comply with all applicable 40 Code of Federal Regulations (CFR), Parts 60, 61, and 63 requirements for New Source Performance Standards (NSPS), National Emission Standards for Page 4 of 67 Hazardous Air Pollutants (NESHAP), and Maximum Achievable Control Technology (MACT); and (C) All facilities shall comply with all applicable requirements of 30 TAC Chapters 111, Control of Air Pollution from Visible Emissions and Particulate Matter, 112, Control of Air Pollution from Sulfur Compounds, 113, Standards of Performance for Hazardous Air Pollutants and for Designated Facilities and Pollutants, 115, Control of Air Pollution from Volatile Organic Compounds), and 117, Control of Air Pollution from Nitrogen Compounds. (3) To be eligible for this standard permit an applicant: (A) shall meet all applicable requirements as set forth in this standard permit; (B) shall not misrepresent or fail to fully disclose all relevant facts in obtaining the permit; and (C) shall not be indebted to the state for failure to make payment of penalties or taxes imposed by the statutes or rules within the commission's jurisdiction. (4) All facilities related to the operation of any OGS, under any version of this standard permit (or co-located at a site with an OGS standard permit), previously authorized by, and continuing to meet, the conditions of a permit by rule under 30 TAC Chapter 106, Permits by Rule (or any historical version) must: (A) Be incorporated into this standard permit in any initial registration, revision, or renewal for this standard permit. These facilities will become authorized by this standard permit and previous authorizations will be voided. (B) Meet all emission limits established by this standard permit and review in accordance with paragraph (b)(8) of this standard permit. (C) Meet requirements of paragraphs (e), (i), and (j) of this standard permit for Best Management Practices and Minimum Requirements, Planned MSS, and associated Records, Sampling and Monitoring of this standard permit. (D) Only if facilities or groups of facilities are changed in such a way as to increase the potential to emit, production processing capacity, or registered emission rate, the requirements in paragraph (e) (BACT) of this standard permit are required to be met. In all other cases, these facilities are not required to meet paragraph (e) of this standard permit. (d) Facilities and Exclusions (1) Only the following specific facilities and groups of facilities have been evaluated for this standard permit, along with supporting infrastructure equipment and facilities, and may be included in a registration: Page 5 of 67 (A) Fugitive components, including valves, pressure relief valves, pipe flanges and connectors, pumps, compressors, stuffing boxes, instrumentation and meters, natural gas driven pneumatic pumps, and other similar devices with seals that separate process and waste material from the atmosphere and the associated piping; (B) Separators, including all gas, oil, and water physical separation units; (C) Treatment and processing equipment, including heater-treaters, methanol injection, glycol dehydrators, molecular or mole sieves, amine sweeteners, H2S scavenger chemical reaction vessels for sulfur removal, and iron sponge units; (D) Cooling towers and associated heat exchangers; (E) Gas recovery units, including cryogenic expansion, absorption, adsorption, heat exchangers, and refrigeration units; (F) Combustion units, including engines, turbines, boilers, reboilers, and heaters; (G) Storage tanks for crude oil, condensate, produced water fuels, treatment chemicals, slop and sump oils and pressure tanks with liquified petroleum gases; (H) Surface facilities associated with underground storage of gas or liquids; (I) Truck loading equipment; (J) Control equipment, including vapor recovery systems, glycol and amine reboiler condensers, flares, vapor combustors, and thermal oxidizers; and (K) Temporary facilities used for planned maintenance, and temporary control devices for planned start-ups and shutdowns. (2) Exclusions. The following are not authorized under this standard permit: (A) Sour water strippers or sulfur recovery units; (B) Carbon dioxide hot carbonate processing units; (C) Water injection facilities (these facilities may otherwise be authorized by 30 TAC 106.351, Salt Water Disposal); (D) Liquefied petroleum gases, crude oil, or condensate transfer or loading into or from railcars, ships, or barges. These facilities may otherwise be authorized by 30 TAC 106.261, Facilities (Emission Limitations)) and 106.262, Facilities (Emissions and Distance Limitations); (E) Incinerators for solid waste destruction; (F) Remediation of petroleum contaminated water and soil. These facilities may otherwise be authorized by 30 TAC 106.533, Remediation; and (G) Cooling Towers and heat exchangers with direct contact with gaseous or liquid process streams containing VOC, H2S, halogens or halogen compounds, cyanide compounds, inorganic acids, or acid gases. Page 6 of 67 (e) Best Management Practices (BMP) and Best Available Control Technology (BACT) Requirements. For any project, and any associated emission control equipment registered under this standard permit this paragraph shall be met as applicable. These requirements are not applicable to existing, unchanging facilities until any renewal submitted after December 31, 2015. (1) All facilities which have the potential to emit air contaminants must be maintained in good working order and operated properly during facility operations. Each operator shall establish and maintain a program to replace, repair, and/or maintain facilities to keep them in good working order. The minimum requirements of this program shall include: (A) Compliance with manufacturer's specifications and recommended programs applicable to equipment performance and effect on emissions, or alternatively, an owner or operator developed maintenance plan for such equipment that is consistent with good air pollution control practices. (B) Cleaning and routine inspection of all equipment; and (C) Replacement and repair of equipment on schedules which prevent equipment failures and maintain performance. (2) Any OGS facility shall be operated at least 50 feet from any property line or receptor (whichever is closer to the facility). This distance limitation does not apply to the following:] (A) Any fugitive components that are used for isolation and or safety purposes may be located at one-half of the width of any applicable easement; (B) Any facility at a location for which the distance requirements were satisfied at the time this standard permit is registered (provided that the authorization was maintained) regardless of whether a receptor is subsequently built or put to use less than 50 feet from any OGS facility; or (C) Existing facilities which are located less than 50 feet from a property line or receptor when constructed and previously authorized. If modified or replaced, the operator shall consider, to the extent that good engineering practice will permit, moving these facilities to meet the 50 foot requirement. Replacement facilities must meet all other requirements of this standard permit. (3) Engines and turbines shall meet the emission and performance standards listed in Table 6 in paragraph (m) and the following requirements: (A) Liquid fueled engines used for back-up power generation and periodic power needs at the OGS are authorized if the fuel has no more than 0.05% sulfur and the engine is operated less than 876 hours per rolling 12-month period. (B) Engines and turbines used for electric generation more than 876 hours per rolling 12-month period are authorized if no reliable electric service is readily available. In all other circumstances, Page 7 of 67 electric generators must meet the technical requirements of the Air Quality Standard Permit for Electric Generating Unit (EGU) (not including the EGU standard permit registration requirements) and the emissions shall be included in the registration under this standard permit; (C) All applicable requirements of 30 TAC Chapter 117; and (D) All applicable requirements of 40 CFR Part 60 and 40 CFR Part 63. (E) Compression ignition engines that are rated less than 225 kW (300 hp) and emit less than or equal to the emission tier for an equivalent sized model year 2008 non-road compression ignition engine located at 40 CFR 89.112, Table 1 are authorized. (4) Open-topped tanks or ponds containing VOCs or H2S are allowed up to a PTE equal to 1 tpy of VOC and 0.1 tpy of H2S. (5) All process equipment and storage facilities individually must meet the requirements of BACT listed in Table 10 in paragraph (m). Any combination of process equipment and storage facilities with an uncontrolled PTE of equal to or greater than 25 tpy of VOC must also meet the requirements of Table 10, row titled "Combined Control Requirements." All of the following streams and facilities must be included for this site-wide assessment: (A) For any gaseous vent stream with a concentration of 1% VOC must be considered for capture and control requirements; (B) For any liquid stream with a potential to emit of equal to or greater than 1 tpy VOC for each vessel or storage facility. (6) The following shall apply to all fugitive components associated with the project: (A) All seals and gaskets in VOC or H2S service shall be installed, checked, and properly maintained to prevent leaking. All components shall be physically inspected quarterly for leaks. (B) New and replaced fugitive components and instrumentation in gas or liquid service with the uncontrolled potential to emit equal to or greater than 10 tpy VOC or 1 tpy H2S are subject to a leak detection and repair (LDAR) program as specified in Table 9 in paragraph (m). Additional requirements are applicable where uncontrolled potential to emit equal to or greater than 25 tpy VOC or 5 tpy H2S as specified in Table 9. Planned MSS from fugitive components must also meet the requirements of Table 9. (C) All components found to be leaking shall be repaired. Every reasonable effort shall be made to repair a leaking component. All leaks not repaired immediately shall be tagged or noted in a log. At manned sites, leaks shall be repaired no later than 30 days after the leak is found. At unmanned sites, leaks shall be repaired no later than 60 days after the leak is found. If the repair of a component would require a unit shutdown, which would create more emissions than the repair would eliminate, the repair may be delayed until the next shutdown. Page 8 of 67 (D) Tank hatches, not designed to be completely sealed, shall remain closed (but not completely sealed in order to maintain safe design functionality) except for sampling, gauging, loading, unloading, or planned maintenance activities. (E) To the extent that good engineering practices will permit, new and reworked valves and piping connections shall be located in a place that is reasonably accessible for leak checking during plant operation and underground process pipelines shall contain no buried valves such that fugitive emission monitoring is rendered impractical. (7) Tanks and vessels must utilize a paint color that minimizes the effects of solar heating (including, but not limited to, white or aluminum). To meet this requirement the solar absorptance should be 0.43 or less, as referenced in Table 7.1-6 in Compilation of Air Pollutant Emission Factors (AP-42). Paint shall be applied according to paint producers recommended application requirements if provided and in sufficient quantity as to be considered solar resistant. Paint shall be maintained in good condition and will not compromise tank integrity. Minimal amounts of rust may be present not to exceed 10% of the external surface area of the roof or walls of the tank and in no way may compromise tank integrity. Additionally, up to 10% of the external surface area of the roof or walls of the tank or vessel may be painted with other colors to allow for identification and/or aesthetics. For tanks and vessels purposefully darkened to create the process reaction and help condense liquids from being entrained in the vapor or are in an area whereby a local, state, federal law, ordinance, or private contract predating this standard permit's effective date establishes in writing tank and vessel colors other than white, these requirements do not apply. (8) All emission estimation methods including but not limited to computer programs such as GRI-GLYCalc, AmineCalc, E&P Tanks, and Tanks 4.0, must be used with monitoring data generated in accordance with Table 8 in subsection (m) of this section where monitoring is required. All emission estimation methods must also be used in a way that is consistent with protocols established by the commission or promulgated in federal regulations (NSPS, NESHAPS). Where control of emissions is relied upon to meet subsection (k) of this section, control monitoring is required. (9) Process reboilers, heaters, and furnaces that are also used for control of waste gas streams may claim 50 to 99% destruction efficiency for VOCs and H2S depending on the design and level of monitoring applied. The 90% destruction may be claimed where the waste gas is delivered to the flame zone or combustion fire box with basic monitoring as specified in Page 9 of 67 paragraph (j). Any value greater than 90% and up to 99% destruction efficiency may be claimed where enhanced monitoring and/or testing are applied as specified in paragraph (j). If the waste gas is premixed with the primary fuel gas and used as the primary fuel in the device through the primary fuel burners, 99% destruction may be claimed with basic monitoring as specified in paragraph (j). In systems where the combustion device is designed to cycle on and off to maintain the designed heating parameters, and may not fully utilize the waste gas stream, records of run time and enhanced monitoring is required to claim any run time beyond 50%. (10) Vapor recovery Systems (VRSs) may claim up to 100% control. The control efficiency is based on whether it is a mechanical VRU (mVRU) or a liquid VRU (lVRU). The VRUs must meet the appropriate design, monitoring and record-keeping in Table 7 and Table 8 in paragraph (m). (11) Flares used for control of emissions from production, planned MSS, emergency, or upset events may claim design destruction efficiency of 98% for VOCs and H2S and 99% for VOCs containing no more than three carbon atoms that contain no elements other than carbon and hydrogen. All flares must be designed and operated in accordance with the following: (A) Meet specifications for minimum heating values of waste gas, maximum tip velocity, and pilot flame monitoring found in 40 CFR 60.18; (B) If necessary to ensure adequate combustion, sufficient gas shall be added to make the gases combustible; (C) An infrared monitor is considered equivalent to a thermocouple for flame monitoring purposes; (D) An automatic ignition system may be used in lieu of a continuous pilot; (E) Flares must be lit at all times when gas streams are present; (F) Fuel for all flares shall be sweet gas or liquid petroleum gas except where only field gas is available and it is not sweetened at the site; and (G) Flares shall be designed for and operated with no visible emissions, except for periods not to exceed at total of 5 minutes during any two consecutive hours. Acid gas flares which must comply with opacity limits and records in accordance with 30 TAC 111.111(a)(4), Requirements for Specified Sources, regarding gas flares, are exempt from this visible emission limitation. (H) Flares may be designed with steam or air assist to help reduce visible emissions from the flare but must meet the appropriate requirements in 40 CFR 60.18. (I) At no time shall minimum heating values fall below the associated minimum heating value in 60.18 Page 10 of 67 (12) Thermal oxidation and vapor combustion control devices may claim design destruction efficiency from 90 to 99.9% for VOCs and H2S depending on the design and the level of monitoring and testing applied. A device designed for the variability of the waste gas streams it controls with basic monitoring to indicate oxidation or combustion is occurring when waste gas is directed to the device may claim 90% destruction efficiency. Devices with intermediate monitoring, designed for the variability of the waste gas streams they control, with a fire box or fire tube designed to maintain a temperature above 1,400 degrees Fahrenheit (F) for 0.5 seconds, residence time; or designed to meet the parameters of a flare with minimum heating values of waste gas, maximum tip velocity, and pilot flame monitoring as found in 40 CFR 60.18, but within a full or partial enclosure may claim a design destruction efficiency of 90 to 98%. Devices with enhanced monitoring and ports and platforms to allow stack testing may claim a 99% efficiency where the devices are designed for the variability of the waste gas streams they control, with a fire box or fire tube designed to maintain a temperature above 1,400 degrees F for 0.5 seconds, residence time. The devices that can claim 99% destruction efficiency may claim 99.9% destruction efficiency if stack testing is conducted and confirms the efficiency and the enhanced monitoring is adjusted to ensure the continued efficiency. Temperature and residence time requirements may be modified if stack testing is conducted to confirm efficiencies. (f) Registration, Revision, and Renewal Requirements (1) For all previous claims of this standard permit (or any previous version of this standard permit) existing authorized facilities, or group of facilities, are not required to meet the requirements of this standard permit, with the exception of planned MSS, until a renewal under the standard permit is submitted after December 31, 2015. (2) If no other changes except for authorizing planned MSS occurs at an existing OGS under this standard permit, or any previous version of this standard permit, (b)(7) applies. (A) Records demonstrating compliance with paragraph (i) must be kept; (B) If the OGS must certify emissions to establish nonapplicability of prevention of significant deterioration (PSD), nonattainment new source review (NNSR), or the federal operating permit programs, this certification may be filed using Form APD-CERT. No fee is required for this certification. (C) Planned MSS shall be incorporated at the next revision or update to a registration under this standard permit after January 5, 2012, and no later than any renewal submitted after December 31, 2015. Page 11 of 67 (3) Facilities, groups of facilities or planned MSS from facilities registered under this standard permit cannot also be authorized by a permit under 30 TAC 116.111, General Application. (4) Prior to construction or implementation of changes for any project which meets this standard permit a notification shall be submitted through the e-Permits system. This notification shall include the following: (A) Identifying information (Core Data) and a general description of the project must be submitted through e-Permits (or if not available, hard-copy) using the "APD OGS New Project Notification." (B) A fee of $25 for small businesses as defined in 30 TAC 106.50, or $50 for all others must be submitted through the commission's e-Pay system. (5) For any registration which meets the emission limitations of this standard permit must meet the following: (A) Within 90 days after start of operation or implemented changes (whichever occurs first), the facilities must be registered with a PI-1S Standard Permit Application. (B) This registration shall include a detailed summary of maximum emissions estimates based on: site-specific or defined representative gas and liquid analysis; equipment design specifications and operations; material type and throughput; and other actual parameters essential for accuracy for determining emissions and compliance with all applicable requirements of this standard permit. (C) The fee for this registration shall be $475 for small businesses, or $850 for all others. (D) Construction may begin any time after receipt of written notification to the executive director. Operations may continue after receipt of registration if there are no objections or 45 days after receipt by the executive director of the registration, whichever occurs first. (6) If an OGS emissions increase, either through a change in production or addition of facilities, the site may change authorization (Level 1 or Level 2 PBR in 30 TAC 106.352 or Standard Permit) in the following circumstances: (A) Within 90 days from the initial notification of construction of an oil and gas facility, a registration can update the authorization mechanism by submitting an initial registration or revision to the PBR or Standard Permit. (B) Within 90 days of the change of production or installation of additional equipment, by submitting an initial registration or revision to the PBR or Standard Permit. Page 12 of 67 (7) All registrations, registration revisions, and renewals shall be submitted to the commission through a PI-1S Standard Permit Registration Form. Fee requirements do not apply when there are changes in representations with no increase in emissions within 6-months after a standard permit registration has been issued. (g) Any claim under this standard permit must comply with all applicable requirements of 30 TAC 116.610; 116.611, Registration to Use a Standard Permit; 116.614, Standard Permit Fees; and 116.615, General Conditions. This standard permit supersedes: the notification requirements of 30 TAC 116.615, General Conditions; and the emission limitations of 30 TAC 116.610(a)(1), Applicability. (h) Emission Limitations. Total maximum estimated registered or certified emissions shall meet the most stringent of the following. All emissions estimates must be based on representative worst-case operations and planned MSS activities. (1) Total maximum estimated annual emissions of any air contaminant shall not exceed the applicable limits for a major stationary source or major modification for PSD and NNSR as specified in 30 TAC 116.12. (2) Emissions must meet the limitations established in paragraph (k) of this standard permit. (3) Maximum emissions are limited to less than the following after any operator limitations or controls: Air contaminant steady-state or < 30 psig SVLJSHULRGLF periodic releases lb/hr lb/hr up to 600 hr/yr Total tpy Total VOC* 250 Total crude oil or condensate VOC* 145 318 Total natural gas VOC* 750 1635 Benzene 7 15.4 10.2 Hydrogen sulfide 10.8 Sulfur dioxide 93.2 Nitrogen oxides 121 Carbon monoxide 104 PM10 and PM2.5 28 9.8 47 250 250 250 15 * VOC is defined in 101.1(115) and does not include methane and ethane Page 13 of 67 (i) Planned Maintenance, Start-ups and Shutdowns (MSS). For any facility, group of facilities or site using this standard permit or previous versions of this standard permit, the following shall apply: (1) Prior to January 5, 2012, representations and registration of planned MSS is voluntary, but if represented must meet the applicable limits of this standard permit. After January 5, 2012, all emissions from planned MSS activities and facilities must be considered for compliance with applicable limits of this standard permit unless otherwise specified in (b)(7). This standard permit may not be used at a site or for facilities authorized under 30 TAC 116.111 if planned MSS has already been authorized under that permit. (2) As specified, releases of air contaminants during, or as result of, planned MSS must be quantified and meet the emission limits in this standard permit, as applicable. This analysis must include: (A) Alternate operational scenarios or redirection of vent streams; (B) Pigging, purging, and blowdowns; (C) Temporary facilities if used for degassing or purging of tanks, vessels, or other facilities; (D) Degassing or purging of tanks, vessels, or other facilities; and (E) Management of sludge from pits, ponds, sumps, and water conveyances. (3) Other planned MSS activities authorized by this standard permit are limited to the following. These planned MSS activities require only recordkeeping of the activity. (A) Routine engine component maintenance including filter changes, oxygen sensor replacements, compression checks, overhauls, lubricant changes, spark plug changes, and emission control system maintenance. (B) Boiler refractory replacements and cleanings. (C) Heater and heat exchanger cleanings. (D) Turbine hot standard permit swaps. (E) Pressure relief valve testing, calibration of analytical equipment; Instrumentation/analyzer maintenance; replacement of analyzer filters and screens. (4) Engine/compressor start-ups associated with preventative system shutdown activities have the option to be authorized as part of typical operations if: (A) Prior to operation, alternative operating scenarios to divert gas or liquid streams are registered and certified with all supporting documentation; (B) Engine/compressor shutdowns shall result in no greater than 4 lbs/hr of natural gas emissions; and (C) Emissions which result from subsequent compressor start-up activities are controlled to a minimum of 98% efficiency for VOC and H2S. Page 14 of 67 (j) Records, Sampling and Monitoring. The following records shall be maintained at a site in written or electronic form and be readily available to the agency or local air pollution control program with jurisdiction upon request. All required records must be kept at the facility site. If the facility normally operates unattended, records must be maintained at an office within Texas having day-to-day operational control of the plant site. Other requirements, including but not limited to, federal recordkeeping or testing requirements, can be used to demonstrate compliance if the other requirements are at least as stringent as the associated requirements in the table below. Any documentation that is already being kept for other purposes will suffice for demonstrating requirements. If a control or method is not relied upon to meet this standard permit, then the associated sampling, monitoring, and records are not applicable. (1) Sampling and demonstrations of compliance shall include the requirements listed in Table 7 in paragraph (m) of this standard permit. (2) Monitoring and records for demonstrations of compliance shall include the requirements listed in Table 8 in paragraph (m) of this standard permit. (k) Emission Limits Based on Impacts Evaluation. (1) All impacts evaluations must be completed on a contaminant-bycontaminant basis for only any net emissions increases resulting from a project and must meet the following as appropriate: (A) Compliance with state or federal ambient air standards shall be demonstrated for NO2, SO2, and H2S at any property-line within one mile of a project. (B) Compliance with hourly effects screening levels (ESLs) for benzene and annual ESL for benzene, shall be demonstrated at the nearest receptor within 1 mile of a project. (2) Distance measurements shall be determined using the following: (A) For each facility or group of facilities, the shortest corresponding distance from any emission point, vent, or fugitive component to the nearest receptor must be used with the appropriate compliance determination method with the published ESLs as found through the TCEQ internet webpage. (B) For each facility or group of facilities, the shortest corresponding distance from any emission point, vent, or fugitive component to the nearest property line must be used with the appropriate compliance determination method with any applicable state or federal ambient air quality standard. (3) Impacts evaluations are not required under the following cases: (A) If there is no receptor within 1 mile of a registration no further ESL review is required. (B) If there is no property line within 1 mile of a registration no further ambient air quality review is required. Page 15 of 67 (C) If the project total emissions are less than any of the following rates, no additional analysis or demonstration of the specified air contaminant is required: Air contaminant Benzene Hydrogen sulfide Sulfur dioxide Nitrogen oxides lb/hr 0.039 0.025 2 4 (4) Evaluation of emissions shall meet the following. (A) For all evaluations of NOX to NO2 a conversion factor of 0.20 for 4 stroke rich and lean burn engines and 0.50 for 2-stroke engines may be used. (B) The maximum predicted concentration or rate at the property boundary or receptor, whichever is appropriate, must not exceed a state or federal ambient air standard or ESL. (5) The impacts analysis shall be based on the following facility emissions: (A) The following shall be met for ESL reviews: (i) If a project's air contaminant maximum predicted concentrations are equal to or less than 10% of the appropriate ESL, no further review is required; (ii) If a project's air contaminant maximum predicted concentrations combined with project increases for that contaminant over a rolling 60-month period after the effective date of this revised standard permit are equal to or less than 25% of the appropriate ESL, no further review is required. (iii) In all other cases, all facility emissions at an OGS, regardless of authorization type, located within 1 mile of a project requiring registration under this standard permit shall be evaluated. (B) The following shall be met for state and federal ambient air quality standard reviews: (i) If a project's air contaminant maximum predicted concentrations are equal to or less than 10% the significant impact level (SIL) (also known as de minimis impact in 30 TAC 101, General Rules), no further review is required; (ii) In all other cases, all facility emissions at an OGS, regardless of authorization type, located within 1 mile of a project requiring registration under this standard permit shall be evaluated. Page 16 of 67 (6) Evaluation must comply with one of the methods listed with no changes or exceptions: (A) Tables. (i) Emission impact Tables 2 - 5F in paragraph (m) of this standard permit may be used in accordance with the limits and descriptions in Table 1 in paragraph (m). (ii) Values in Tables 2 - 5F in paragraph (m) of this standard permit may be used with linear interpolation between height and distance points. A distance of less than 50 feet or greater than 5,500 feet may not be used. Release heights may not be extrapolated beyond the limits of any table and instead the minimum or maximum height will be used. If distances and release heights are not interpolated, the next lowest height and lesser distances shall be used for determination of maximum acceptable emissions. All facilities exempted from the distance to the property line restriction in paragraph (e)(2) of this standard permit must use 50 feet as the distance to the property line for those ambient standards based on property line. (B) Screening Modeling. A screening model may be used to demonstrate acceptable emissions from an OGS under this standard permit if all of the parameters in the screening modeling protocol provided by the commission are met. (C) Dispersion Modeling. A refined dispersion model may be used to demonstrate acceptable emissions from an OGS under this standard permit if all of the parameters in the refined dispersion modeling protocol provided by the commission are met. (l) Existing, Unchanged Facilities and Projects Before Effective Date. The requirements in 30 TAC 116.620 are applicable to existing unchanged facilities and new or changing facilities as specified in paragraph (a)(1) of this standard permit. (m) The following Tables shall be used as required by this standard permit. Table 1 Emission Impact Tables Limits and Descriptions; Table 2 Generic Modeling Results for Fugitives & Process Vents; Table 3 Generic Modeling Results for Flares and Thermal Destruction Devices Table 4 Generic Modeling Results for Blowdowns, Purging, and Pigging Table 5A Generic Modeling Results for Engines Less Than or Equal to 250 hp Table 5B Generic Modeling Results for Engines Greater Than 250 hp to Less Than or Equal to 500 hp Table 5C Generic Modeling Results for Engines Greater Than 500 hp to Less Than or Equal to 1000 hp Page 17 of 67 Table 5D Generic Modeling Results for Engines Greater Than 1000 hp to Less Than or Equal to 1500 hp Table 5E Generic Modeling Results for Engines Greater Than 1500 hp to Less Than or Equal to 2000 hp Table 5F Generic Modeling Results for Engines Greater Than 2000 hp Table 6 Engine and Turbine Emission and Operational Standards Table 7 Sampling and Demonstrations of Compliance; Table 8 Monitoring and Records Demonstrations; Table 9 Fugitive Component Leak Detection and Repair (LDAR) Control Program; and Table 10 Best Available Control Technology (BACT) Requirements Page 18 of 67 Table 1 Emission Impact Tables Limits and Descriptions Topic Description Details Variables EMAX HOURLY the maximum acceptable hourly (lb/hr) emissions for a specific air contaminant EMAX ANNUAL the maximum acceptable annual (tpy) emissions for a specific air contaminant P ambient air standard for a specific air contaminant (g/m3 ) ESL current published effects screening level for a specific air contaminant (g/m3) G the most stringent of any applicable generic value from the Generic Modeling Results Tables at the emission point's release height and distance to property line (g/m3/lb/hr) Single releases or colocated groups of similar releases WREPNx= hourly ambient air standard weighted ratio of emissions of a specific air contaminant for each EPN divided by the sum of total emissions for all EPNs that emit that contaminant or (EEPNx/Etotal) emissions are determined by: EMAX HOURLY = P/G hourly health effects emissions are determined by: EMAX HOURLY = ESL/G review annual ambient air standard annual health effects review emissions are determined by: EMAX ANNUAL = (8760/2000) P/(0.08*G) emissions are determined by: EMAX ANNUAL = (8760/2000) ESL/(0.08*G) Multiple release points Limits hourly ambient air standard hourly health effects review annual ambient air standard annual health effects review If weighted ratios are not used, the total quantity of emissions shall be assumed to be released from the most conservative applicable G value at the site. emissions are determined by: EMAX HOURLY = (WREPN1) (P / GEPN1) + (WREPN2) (P / GEPN2) + (WREPNx) (P / GEPNx) emissions are determined by: EMAX HOURLY = (WREPN1) (ESL /GEPN1) + (WREPN2) (ESL/GEPN2) + (WREPNx) (ESL / GEPNx) emissions are determined by: EMAX ANNUAL = (8760/2000) [(WREPN1) (P / 0.08*GEPN1) + (WREPN2) (P / 0.08*GEPN2) + .... (WREPNx) (P / 0.08*GEPNx)] emissions are determined by: EMAX ANNUAL = (8760/2000) [(WREPN1) (ESL /0.08*GEPN1]) + (WREPN2) (ESL/0.08*GEPN2) + WREPNx) (ESL / 0.08*GEPNx)] Page 19 of 67 Table 2: Fugitives and Process Vents Distance Fugitive 3ft height Loading 10 ft height Ghourly (g/m)/ Ghourly (g/m)/ (ft) (lb/hr) (lb/hr) 50 4375 1232 100 4375 1232 150 3907 1232 200 3089 1232 300 1911 1193 400 1269 1048 500 901 858 600 674 698 700 525 574 800 423 479 900 349 406 1000 293 348 1100 250 302 1200 217 264 1300 189 233 1400 167 208 1500 149 186 1600 134 168 1700 121 153 1800 110 139 1900 100 128 2000 92 117 2100 85 108 2200 78 101 Tank Vents 20 ft height Ghourly (g/m)/ (lb/hr) 305 305 305 305 294 291 274 271 271 261 244 226 208 191 176 161 149 137 127 117 109 102 95 89 Process Vessel 10 ft Process Vessel 20 Process Vessel Vent ft Vent 30 ft Vent Process Vessel 40 ft Vent Process Vessel 50 ft Vent Process Vessel 60 ft Vent Ghourly (g/m) /(lb/hr) Ghourly (g/m)/ (lb/hr) Ghourly Ghourly Ghourly Ghourly (g/m)/(lb/hr) (g/m)/(lb/hr) (g/m)/(lb/hr) (g/m)/(lb/hr) 469 168 90 70 65 28 469 168 90 70 65 28 469 168 90 70 65 28 440 168 90 70 65 28 412 168 90 70 65 28 319 168 90 70 65 28 243 157 90 70 65 28 189 138 89 70 65 28 150 120 88 70 65 28 124 105 85 70 65 28 105 93 81 70 65 28 91 84 77 69 65 26 90 77 72 67 63 25 89 70 68 64 61 24 88 65 64 61 58 24 87 61 60 58 55 24 84 57 57 55 53 24 82 54 53 52 50 23 79 51 51 49 47 23 76 50 48 47 45 22 73 49 46 44 43 22 70 49 44 42 41 21 67 48 42 41 39 21 64 47 40 39 38 20 Page 20 of 67 Table 2: Fugitives and Process Vents continued Distance Fugitive 3ft height Loading 10 ft height Tank Vents 20 ft height Ghourly (g/m)/ Ghourly (g/m)/ Ghourly (g/m)/ (ft) (lb/hr) (lb/hr) (lb/hr) 2300 73 94 83 2400 68 88 78 2500 64 82 74 2600 60 77 70 2700 56 73 66 2800 53 69 63 2900 50 65 60 3000 48 62 57 3500 37 49 46 4000 30 40 38 4500 25 33 32 5000 22 28 27 5500 19 25 24 Process Vessel 10 ft Process Vessel 20 Process Vessel Vent ft Vent 30 ft Vent Process Vessel 40 ft Vent Process Vessel 50 ft Vent Process Vessel 60 ft Vent Ghourly (g/m) /(lb/hr) Ghourly (g/m)/ (lb/hr) Ghourly Ghourly Ghourly Ghourly (g/m)/(lb/hr) (g/m)/(lb/hr) (g/m)/(lb/hr) (g/m)/(lb/hr) 61 46 39 37 36 19 59 45 37 36 35 19 56 43 36 35 34 18 54 42 34 33 32 18 52 41 33 32 31 17 50 40 32 31 30 17 48 39 31 30 29 16 46 37 30 29 28 16 38 32 26 25 25 14 32 28 24 23 22 12 28 25 21 20 20 11 24 22 19 18 18 10 21 19 17 17 16 9 Page 21 of 67 Table 3: Flares and Thermal Destruction Devices Generic Modeling Results Distance 20 ft height 30 ft height (ft) 50 100 150 200 300 400 500 600 700 800 900 1000 1100 1200 1300 Ghourly (g/m)/(lb/hr) 58 58 58 58 58 58 58 56 52 47 45 44 42 40 38 Ghourly (g/m)/(lb/hr) 43 43 43 43 43 43 43 43 43 43 43 43 41 40 38 40 ft height Ghourly (g/m)/ (lb/hr) 26 26 26 26 26 26 26 26 26 26 26 26 25 24 23 50 ft height Ghourly (g/m)/(lb/hr) 25 25 25 25 25 25 25 25 25 25 25 25 24 24 23 60 ft height Ghourly (g/m)/(lb/hr) 23 23 23 23 23 23 23 23 23 23 23 23 23 22 21 Page 22 of 67 Table 3: Flares and Thermal Destruction Devices continued Generic Modeling Results Distance 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3500 20 ft height 36 34 32 31 29 28 26 25 24 23 22 22 21 20 19 19 18 16 30 ft height 36 34 32 31 29 28 26 25 24 23 22 22 21 20 19 19 18 16 40 ft height 23 23 22 22 22 22 21 21 20 20 20 19 19 18 18 17 17 15 50 ft height 21 21 21 21 20 20 20 20 20 19 19 18 18 17 17 16 16 14 60 ft height 21 20 20 20 20 20 19 19 19 19 18 18 17 17 16 16 16 14 Page 23 of 67 Table 3: Flares and Thermal Destruction Devices continued Generic Modeling Results Distance 4000 4500 5000 5500 20 ft height 14 13 11 11 30 ft height 14 13 11 11 40 ft height 13 12 11 10 50 ft height 12 11 10 9 60 ft height 12 11 10 9 Page 24 of 67 Table 4: Blowdowns, Purging, and Pigging Generic Modeling Results Distance < 30 psig; 3 ft height < 30 psig; 10 ft height < 30 psig; 20 ft height (ft) 50 100 150 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 Ghourly (g/m)/(lb/hr) 4304 4304 4250 3621 2367 1607 1156 871 682 551 456 384 328 284 249 220 196 176 159 145 ~ Ghourly (g/m)/(lb/hr) 791 791 777 763 750 737 671 581 498 427 368 320 281 248 221 198 178 162 147 135 Ghourly (g/m)/(lb/hr) 244 244 244 244 225 225 224 218 212 210 204 194 182 170 159 147 137 127 118 110 SVLJIWKHLJKW Ghourly (g/m)/(lb/hr) 51 51 51 51 51 51 51 48 44 40 36 33 30 28 27 27 27 27 27 27 SVLJIWKHLJKW Ghourly (g/m)/(lb/hr) 25 25 25 25 25 25 25 25 25 24 23 21 20 18 17 16 15 14 13 13 Page 25 of 67 Table 4: Blowdowns, Purging, and Pigging Generic Modeling Results continued Distance < 30 psig; 3 ft height < 30 psig; 10 ft height < 30 psig; 20 ft height SVLJIW height Ghourly Ghourly Ghourly (ft) Ghourly (g/m)/(lb/hr) (g/m)/(lb/hr) (g/m)/(lb/hr) (g/m)/(lb/hr) 1900 132 124 103 27 2000 121 114 96 27 2100 112 106 90 27 2200 103 98 85 27 2300 96 91 80 27 2400 90 86 75 27 2500 84 81 71 27 2600 79 76 68 27 2700 74 72 64 26 2800 70 68 61 26 2900 67 64 58 26 3000 63 61 55 25 3500 50 48 45 23 4000 40 39 37 21 4500 34 33 31 19 5000 29 28 27 17 5500 25 24 23 16 SVLJIWKHLJKW Ghourly (g/m)/(lb/hr) 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 12 11 Page 26 of 67 Table 5A Engines Less Than or Equal to 250 hp Generic Modeling Results Distance 8 ft height 10 ft height 12 ft height 14 ft height Ghourly Ghourly Ghourly Ghourly (g/m)/ (g/m)/ (g/m) (g/m)/ (ft) (lb/hr) (lb/hr) /(lb/hr) (lb/hr) 50 97 85 83 81 100 97 85 83 81 150 97 85 83 81 200 93 85 83 81 300 92 85 83 81 400 91 85 83 81 500 88 85 83 81 600 80 79 78 78 700 78 77 76 76 800 76 75 74 74 900 74 73 72 72 1000 72 71 71 71 1100 69 69 69 69 1200 66 66 66 65 1300 62 62 62 62 1400 59 59 59 59 1500 56 56 56 56 16 ft height Ghourly (g/m)/ (lb/hr) 81 81 81 81 81 81 81 78 71 64 58 53 49 45 42 39 37 18 ft height Ghourly (g/m) /(lb/hr) 71 71 71 71 71 71 71 70 68 63 58 53 49 45 42 39 37 20 ft height Ghourly (g/m) (lb/hr) 58 58 58 58 58 58 58 56 52 47 45 44 42 40 38 36 34 25 ft height Ghourly (g/m) /(lb/hr) 44 44 44 44 44 44 44 44 44 44 44 43 42 40 38 36 34 30 ft height Ghourly (g/m)/ (lb/hr) 43 43 43 43 43 43 43 43 43 43 43 43 41 40 38 36 34 35 ft height Ghourly (g/m)/ (lb/hr) 36 36 36 36 36 36 36 36 36 36 36 36 35 35 33 32 30 40 ft height Ghourly (g/m)/ (lb/hr) 26 26 26 26 26 26 26 26 26 26 26 26 25 24 23 23 23 Page 27 of 67 Table 5A Engines Less Than or Equal to 250 hp continued Generic Modeling Results Distance (ft) 8 ft height Ghourly (g/m)/ (lb/hr) 10 ft height Ghourly (g/m)/ (lb/hr) 12 ft height Ghourly (g/m) /(lb/hr) 14 ft height Ghourly (g/m)/ (lb/hr) 16 ft height Ghourly (g/m)/ (lb/hr) 1600 53 53 53 53 35 1700 50 50 50 50 33 1800 48 48 48 48 31 1900 46 46 46 46 30 2000 44 44 44 44 28 2100 42 42 42 42 27 2200 40 40 40 40 26 2300 38 38 38 38 25 2400 37 37 37 37 24 2500 36 36 36 36 23 2600 34 34 34 34 22 2700 33 33 33 33 21 2800 32 32 32 32 21 2900 31 31 31 31 20 3000 30 30 30 30 19 3500 26 26 26 26 17 4000 23 23 23 23 15 18 ft height Ghourly (g/m) /(lb/hr) 35 33 31 30 28 27 26 25 24 23 22 21 21 20 19 17 15 20 ft height Ghourly (g/m) (lb/hr) 32 31 29 28 26 25 24 23 22 22 21 20 19 19 18 16 14 25 ft height Ghourly (g/m) /(lb/hr) 32 31 29 28 26 25 24 23 22 22 21 20 19 19 18 16 14 30 ft height Ghourly (g/m)/ (lb/hr) 32 31 29 28 26 25 24 23 22 22 21 20 19 19 18 16 14 35 ft height Ghourly (g/m)/ (lb/hr) 29 28 26 25 24 23 22 21 20 20 19 18 18 17 17 15 13 40 ft height Ghourly (g/m)/ (lb/hr) 22 22 22 22 21 21 20 20 20 19 19 18 18 17 17 15 13 Page 28 of 67 Table 5A Engines Less Than or Equal to 250 hp continued Generic Modeling Results Distance (ft) 8 ft height Ghourly (g/m)/ (lb/hr) 10 ft height Ghourly (g/m)/ (lb/hr) 12 ft height Ghourly (g/m) /(lb/hr) 14 ft height Ghourly (g/m)/ (lb/hr) 16 ft height Ghourly (g/m)/ (lb/hr) 4500 21 21 21 21 13 5000 19 19 19 19 12 5500 17 17 17 17 11 18 ft height Ghourly (g/m) /(lb/hr) 13 12 11 20 ft height Ghourly (g/m) (lb/hr) 13 11 11 25 ft height Ghourly (g/m) /(lb/hr) 13 11 11 30 ft height Ghourly (g/m)/ (lb/hr) 13 11 11 35 ft height Ghourly (g/m)/ (lb/hr) 12 11 10 40 ft height Ghourly (g/m)/ (lb/hr) 12 11 10 Page 29 of 67 Table 5B: Engines Greater Than 250 and Less Than or Equal to 500 hp continued Generic Modeling Results Distance 8 ft height 10 ft height 12 ft height 14 ft height 16 ft height 18 ft height 20 ft height 25 ft height 30 ft height 35 ft height 40 ft height (ft) 50 100 150 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 G Ghourly (g/m)/(lb/ hr) G hourly (g/m)/(lb/ hr) G hourly (g/m)/(lb/ hr) G hourly (g/m)/(lb/ hr) G hourly (g/m)/(lb/ hr) G hourly (g/m)/(lb/ hr) G hourly (g/m)/(lb/ hr) G hourly (g/m)/(lb/ hr) G hourly (g/m)/(lb/ hr) G hourly (g/m)/(lb/ hr) hourly (g/m)/(lb/ hr) 60 59 54 43 43 34 34 24 21 20 17 60 59 54 43 43 34 34 24 21 20 17 60 59 54 43 43 34 34 24 21 20 17 60 59 54 43 43 34 34 24 21 20 17 60 59 54 43 43 34 34 24 21 20 17 60 59 54 43 43 34 34 24 21 20 17 60 59 54 43 43 34 34 24 21 20 17 57 57 52 41 41 34 34 24 21 20 17 52 52 47 38 38 31 31 24 21 20 17 47 47 43 34 34 28 28 24 21 20 17 42 42 39 31 31 26 26 23 20 20 17 39 39 35 28 28 23 23 21 20 20 17 37 36 32 26 26 23 23 20 20 19 17 35 35 30 25 24 23 23 20 20 18 17 34 34 28 24 23 23 23 20 20 18 16 32 32 26 24 23 23 23 20 20 17 16 31 31 24 23 23 23 23 20 20 16 16 Page 30 of 67 Table 5B: Engines Greater Than 250 and Less Than or Equal to 500 hp continued Generic Modeling Results Distance (ft) 8 ft height Ghourly (g/m)/(lb/ hr) 10 ft height Ghourly (g/m)/(lb/ hr) 12 ft height Ghourly (g/m)/(lb/ hr) 14 ft height Ghourly (g/m)/(lb/ hr) 16 ft height Ghourly (g/m)/(lb/ hr) 18 ft height Ghourly (g/m)/(lb/ hr) 20 ft height Ghourly (g/m)/(lb/ hr) 25 ft height Ghourly (g/m)/(lb/ hr) 30 ft height Ghourly (g/m)/(lb/ hr) 35 ft height Ghourly (g/m)/(lb/ hr) 40 ft height Ghourly (g/m)/(lb/ hr) 1600 29 29 23 23 23 23 23 19 19 16 16 1700 28 28 23 23 23 23 22 19 19 16 15 1800 27 27 22 22 22 22 22 19 19 16 15 1900 25 25 22 22 22 21 21 18 18 16 15 2000 24 24 22 22 22 21 21 17 17 16 15 2100 23 23 21 21 21 20 20 17 17 16 15 2200 22 22 21 21 21 19 19 17 17 15 15 2300 21 21 20 20 20 19 19 17 16 15 14 2400 21 21 20 20 20 19 18 16 16 15 14 2500 20 20 19 19 19 18 18 16 16 14 14 2600 19 19 19 19 19 18 17 16 16 14 13 2700 18 18 18 18 18 17 17 15 15 14 13 2800 18 18 18 18 18 17 16 15 15 13 13 2900 17 17 17 17 17 16 16 15 15 13 13 3000 17 17 17 17 17 16 15 15 15 13 13 3500 15 15 15 15 15 14 14 13 13 12 11 4000 13 13 13 13 13 13 12 12 12 11 10 Page 31 of 67 Table 5B: Engines Greater Than 250 and Less Than or Equal to 500 hp continued Generic Modeling Results Distance 8 ft height 10 ft height 12 ft height 14 ft height 16 ft height 18 ft height 20 ft height 25 ft height 30 ft height 35 ft height 40 ft height Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (ft) r) r) r) r) r) r) r) r) r) r) r) 4500 12 12 12 12 12 11 11 10 10 10 9 5000 11 11 11 11 11 10 10 10 10 9 9 5500 10 10 10 10 10 9 9 9 9 8 8 Table 5C: Engines Greater Than 500 and Less Than or Equal to 1,000 hp Generic Modeling Results Distance 8 ft height 10 ft height 12 ft height 14 ft height 16 ft height 18 ft height 20 ft height 25 ft height 30 ft height 35 ft height 40 ft height Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (ft) r) r) r) r) r) r) r) r) r) r) r) 50 26 25 25 25 18 18 17 13 11 11 10 100 26 25 25 25 18 18 17 13 11 11 10 150 26 25 25 25 18 18 17 13 11 11 10 200 26 25 25 25 18 18 17 13 11 11 10 300 26 25 25 25 18 18 17 13 11 11 10 400 26 25 25 25 18 18 17 13 11 11 10 500 26 25 25 25 18 18 17 13 11 11 10 600 26 25 25 25 18 18 17 13 11 11 10 700 26 25 25 25 18 18 17 13 11 11 10 800 24 24 24 24 18 18 17 13 11 11 10 900 23 23 23 23 18 18 17 13 11 11 10 1000 21 21 21 21 17 17 17 13 11 11 10 1100 20 20 20 20 17 17 16 13 11 11 10 1200 18 18 18 18 16 16 16 12 11 11 10 1300 17 17 17 17 15 15 15 12 11 10 10 1400 17 17 17 17 14 14 14 11 11 10 10 Page 32 of 67 Table 5C: Engines Greater Than 500 and Less Than or Equal to 1,000 hp Generic Modeling Results Distance 8 ft height 10 ft height 12 ft height 14 ft height 16 ft height 18 ft height 20 ft height 25 ft height 30 ft height 35 ft height 40 ft height Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (ft) r) r) r) r) r) r) r) r) r) r) r) 50 26 25 25 25 18 18 17 13 11 11 10 100 26 25 25 25 18 18 17 13 11 11 10 150 26 25 25 25 18 18 17 13 11 11 10 200 26 25 25 25 18 18 17 13 11 11 10 300 26 25 25 25 18 18 17 13 11 11 10 400 26 25 25 25 18 18 17 13 11 11 10 500 26 25 25 25 18 18 17 13 11 11 10 600 26 25 25 25 18 18 17 13 11 11 10 700 26 25 25 25 18 18 17 13 11 11 10 800 24 24 24 24 18 18 17 13 11 11 10 900 23 23 23 23 18 18 17 13 11 11 10 1500 17 17 16 16 13 13 13 11 11 10 9 1600 17 17 16 16 13 13 13 11 11 10 9 1700 16 16 15 15 13 12 12 11 11 9 9 1800 16 16 15 15 13 12 12 11 11 9 9 1900 15 15 14 14 13 12 12 11 10 9 9 2000 15 15 14 14 13 12 12 11 10 9 9 2100 14 14 13 13 12 12 12 11 10 9 9 2200 14 14 13 13 12 12 12 10 10 9 9 2300 13 13 12 12 12 11 11 10 10 9 8 2400 13 13 12 12 12 11 11 10 9 9 8 2500 12 12 12 12 11 11 11 10 9 9 8 2600 12 12 11 11 11 11 11 10 9 9 8 Page 33 of 67 Table 5C: Engines Greater Than 500 and Less Than or Equal to 1,000 hp Generic Modeling Results Distance 8 ft height 10 ft height 12 ft height 14 ft height 16 ft height 18 ft height 20 ft height 25 ft height 30 ft height 35 ft height 40 ft height Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (ft) r) r) r) r) r) r) r) r) r) r) r) 50 26 25 25 25 18 18 17 13 11 11 10 100 26 25 25 25 18 18 17 13 11 11 10 150 26 25 25 25 18 18 17 13 11 11 10 200 26 25 25 25 18 18 17 13 11 11 10 300 26 25 25 25 18 18 17 13 11 11 10 400 26 25 25 25 18 18 17 13 11 11 10 500 26 25 25 25 18 18 17 13 11 11 10 600 26 25 25 25 18 18 17 13 11 11 10 700 26 25 25 25 18 18 17 13 11 11 10 800 24 24 24 24 18 18 17 13 11 11 10 900 23 23 23 23 18 18 17 13 11 11 10 2700 12 12 11 11 11 10 10 10 9 8 8 2800 11 11 11 11 11 10 10 9 9 8 8 2900 11 11 10 10 10 10 10 9 9 8 8 3000 11 11 10 10 10 10 10 9 9 8 8 3500 9 9 9 9 9 9 9 8 8 7 7 4000 8 8 8 8 8 8 8 7 7 7 6 4500 7 7 7 7 7 7 7 7 6 6 6 5000 7 7 7 7 6 6 6 6 6 6 5 5500 6 6 6 6 6 6 6 6 5 5 5 Page 34 of 67 Table 5D: Engines Greater Than 1,000 and Less Than or Equal to 1,500 hp Generic Modeling Results Distance 8 ft height 10 ft height 12 ft height 14 ft height 16 ft height 18 ft height 20 ft height 25 ft height 30 ft height 35 ft height 40 ft height Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (ft) r) r) r) r) r) r) r) r) r) r) r) 50 17 13 12 10 10 10 10 9 8 8 7 100 17 13 12 10 10 10 10 9 8 8 7 150 17 13 12 10 10 10 10 9 8 8 7 200 17 13 12 10 10 10 10 9 8 8 7 300 17 13 12 10 10 10 10 9 8 8 7 400 17 13 11 10 10 10 10 9 8 8 7 500 17 13 11 10 10 10 10 9 8 8 7 600 17 12 11 10 10 10 10 9 8 8 7 700 17 11 11 10 10 10 10 9 8 8 7 800 17 11 11 10 10 10 10 9 8 8 7 900 17 11 11 10 10 10 10 9 8 8 7 1000 17 11 11 10 10 10 10 9 8 8 7 1100 16 11 11 10 10 10 10 9 8 8 7 1200 15 10 10 10 9 9 9 9 8 7 7 1300 15 10 10 10 9 9 9 8 8 7 7 1400 14 10 10 10 9 9 8 8 8 7 7 1500 13 10 10 10 8 8 8 8 8 7 6 Page 35 of 67 Table 5D: Engines Greater Than 1,000 and Less Than or Equal to 1,500 hp continued Generic Modeling Results Distance 8 ft height 10 ft height 12 ft height 14 ft height 16 ft height 18 ft height 20 ft height 25 ft height 30 ft height 35 ft height 40 ft height Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (ft) r) r) r) r) r) r) r) r) r) r) r) 1600 12 10 10 10 8 8 8 8 8 7 6 1700 12 10 10 10 8 8 8 8 8 7 6 1800 11 10 10 10 8 8 8 8 8 7 6 1900 11 10 9 9 8 8 8 7 7 7 6 2000 10 9 9 9 8 8 8 7 7 7 6 2100 10 9 9 9 8 8 8 7 7 6 6 2200 10 9 9 9 8 8 8 7 7 6 6 2300 9 9 8 8 8 8 8 7 7 6 6 2400 9 9 8 8 7 7 7 7 7 6 6 2500 9 8 8 8 7 7 7 7 6 6 5 2600 8 8 8 8 7 7 7 7 6 6 5 2700 8 8 8 8 7 7 7 7 6 6 5 2800 8 8 7 7 7 7 7 6 6 6 5 2900 8 7 7 7 7 7 7 6 6 6 5 3000 7 7 7 7 7 7 6 6 6 5 5 3500 7 6 6 6 6 6 6 6 5 5 5 4000 6 6 6 6 5 5 5 5 5 4 4 4500 5 5 5 5 5 5 5 5 4 4 4 5000 5 5 5 5 5 5 4 4 4 4 4 5500 5 4 4 4 4 4 4 4 4 4 3 Page 36 of 67 Table 5E: Engines Greater Than 1,500 and Less Than or Equal to 2,000 hp Generic Modeling Results Distance 8 ft height 10 ft height 12 ft height 14 ft height 16 ft height 18 ft height 20 ft height 25 ft height 30 ft height 35 ft height 40 ft height Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (ft) r) r) r) r) r) r) r) r) r) r) r) 50 10 9 8 8 8 7 7 7 6 5 5 100 10 9 8 8 8 7 7 7 6 5 5 150 10 9 8 8 8 7 7 7 6 5 5 200 10 9 8 8 8 7 7 7 6 5 5 300 10 9 8 8 8 7 7 7 6 5 5 400 10 9 8 8 8 7 7 7 6 5 5 500 10 9 8 8 8 7 7 7 6 5 5 600 10 9 8 8 8 7 7 7 6 5 5 700 9 8 8 8 8 7 7 7 6 5 5 800 9 8 8 8 8 7 7 7 6 5 5 900 9 8 8 8 8 7 7 7 6 5 5 1000 9 8 8 8 8 7 7 7 6 5 5 1100 9 8 8 8 8 7 7 7 6 5 5 1200 8 8 7 7 7 7 7 7 6 5 5 1300 8 8 7 7 7 7 7 6 6 5 5 1400 8 8 7 7 7 7 7 6 6 5 5 1500 8 8 7 7 7 7 7 6 5 5 5 Page 37 of 67 Table 5E: Engines Greater Than 1,500 and Less Than or Equal to 2,000 hp continued Generic Modeling Results Distance 8 ft height 10 ft height 12 ft height 14 ft height 16 ft height Ghourly Ghourly Ghourly Ghourly Ghourly (g/m)/ (g/m)/ (g/m)/ (g/m)/ (g/m)/ (ft) (lb/hr) (lb/hr) (lb/hr) (lb/hr) (lb/hr) 1600 8 8 7 7 7 1700 8 8 7 7 7 1800 8 8 7 7 7 1900 7 7 7 7 7 2000 7 7 7 7 7 2100 7 7 6 6 6 2200 7 7 6 6 6 2300 7 7 6 6 6 2400 7 7 6 6 6 2500 6 6 6 6 6 2600 6 6 6 6 6 2700 6 6 6 6 6 2800 6 6 6 6 5 2900 6 6 5 5 5 3000 6 5 5 5 5 3500 5 5 5 5 5 4000 4 4 4 4 4 4500 4 4 4 4 4 5000 4 4 4 3 3 5500 3 3 3 3 3 18 ft height Ghourly (g/m)/ (lb/hr) 7 7 7 7 7 6 6 6 6 6 6 5 5 5 5 4 4 4 3 3 20 ft height Ghourly (g/m)/ (lb/hr) 7 7 7 6 6 6 6 6 6 6 5 5 5 5 5 4 4 4 3 3 25 ft height Ghourly (g/m)/ (lb/hr) 6 6 6 6 6 6 6 6 5 5 5 5 5 5 5 4 4 3 3 3 30 ft height Ghourly (g/m)/ (lb/hr) 5 5 5 5 5 5 5 5 5 5 5 5 4 4 4 4 4 3 3 3 35 ft height Ghourly (g/m)/ (lb/hr) 5 5 5 5 5 5 5 5 5 4 4 4 4 4 4 4 3 3 3 3 40 ft height Ghourly (g/m)/ (lb/hr) 5 5 5 5 5 5 4 4 4 4 4 4 4 4 4 3 3 3 3 3 Page 38 of 67 Table 5F: Engines Greater Than 2,000 hp Generic Modeling Results Distance 8 ft height 10 ft height 12 ft height 14 ft height 16 ft height 18 ft height 20 ft height 25 ft height 30 ft height 35 ft height 40 ft height Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (ft) r) r) r) r) r) r) r) r) r) r) r) 50 7 6 6 6 5 5 5 5 4 4 4 100 7 6 6 6 5 5 5 5 4 4 4 150 7 6 6 6 5 5 5 5 4 4 4 200 7 6 6 6 5 5 5 5 4 4 4 300 7 6 6 6 5 5 5 5 4 4 4 400 7 6 6 6 5 5 5 5 4 4 4 500 7 6 6 6 5 5 5 5 4 4 4 600 7 6 6 6 5 5 5 5 4 4 4 700 7 6 6 6 5 5 5 5 4 4 4 800 6 6 6 6 5 5 5 5 4 4 4 900 6 6 6 6 5 5 5 5 4 4 4 1000 6 6 6 6 5 5 5 5 4 4 4 1100 6 6 6 6 5 5 5 5 4 4 4 1200 6 6 6 6 5 5 5 5 4 4 4 1300 6 6 6 6 5 5 5 5 4 4 4 1400 6 6 6 6 5 5 5 5 4 4 4 1500 6 6 6 6 5 5 5 5 4 4 4 1600 6 6 6 6 5 5 5 5 4 4 4 1700 6 6 6 6 5 5 5 5 4 4 4 1800 6 6 6 6 5 5 5 5 4 4 4 1900 6 6 6 5 5 5 5 5 4 4 4 2000 6 6 6 5 5 5 5 5 4 4 3 2100 5 5 5 5 5 5 5 5 4 4 3 2200 5 5 5 5 5 5 5 4 4 4 3 2300 5 5 5 5 5 5 4 4 4 4 3 Page 39 of 67 Table 5F: Engines Greater Than 2,000 hp Generic Modeling Results Distance 8 ft height 10 ft height 12 ft height 14 ft height 16 ft height 18 ft height 20 ft height 25 ft height 30 ft height 35 ft height 40 ft height Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly Ghourly (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (g/m)/(lb/h (ft) r) r) r) r) r) r) r) r) r) r) r) 50 7 6 6 6 5 5 5 5 4 4 4 100 7 6 6 6 5 5 5 5 4 4 4 150 7 6 6 6 5 5 5 5 4 4 4 200 7 6 6 6 5 5 5 5 4 4 4 300 7 6 6 6 5 5 5 5 4 4 4 400 7 6 6 6 5 5 5 5 4 4 4 500 7 6 6 6 5 5 5 5 4 4 4 600 7 6 6 6 5 5 5 5 4 4 4 700 7 6 6 6 5 5 5 5 4 4 4 800 6 6 6 6 5 5 5 5 4 4 4 900 6 6 6 6 5 5 5 5 4 4 4 1000 6 6 6 6 5 5 5 5 4 4 4 1100 6 6 6 6 5 5 5 5 4 4 4 1200 6 6 6 6 5 5 5 5 4 4 4 1300 6 6 6 6 5 5 5 5 4 4 4 1400 6 6 6 6 5 5 5 5 4 4 4 1500 6 6 6 6 5 5 5 5 4 4 4 2400 5 5 5 5 5 5 4 4 4 4 3 2500 5 5 5 5 4 4 4 4 4 4 3 2600 5 5 5 5 4 4 4 4 4 3 3 2700 5 5 5 5 4 4 4 4 4 3 3 2800 5 5 5 4 4 4 4 4 4 3 3 2900 4 4 4 4 4 4 4 4 4 3 3 3000 4 4 4 4 4 4 4 4 3 3 3 3500 4 4 4 4 4 4 3 3 3 3 3 4000 3 3 3 3 3 3 3 3 3 3 3 4500 3 3 3 3 3 3 3 3 3 2 2 5000 3 3 3 3 3 3 3 2 2 2 2 5500 3 3 3 3 3 2 2 2 2 2 2 Page 40 of 67 Table 6 Engine and Turbine Emission and Operational Standards Engine Type Engine Size Manufacture Date NOx (g/bhp-hr) CO (g/bhp- VOC hr) (g/bhp-hr) Rich Burn, Nonemergency, Sparkignited less than 100 All dates hp greater than or equal to 100 hp Before January 1, 2011 no standard 2 no standard no standard 3 no standard greater than or equal to 100 hp After January 1, 2011 1 3 1 After January 1, 2015, regardless of manufacture date, no rich burn engine greater than or equal to 240 hp authorized by this permit shall emit NOx in excess of 0.5 g/bhp-hr. After January 1, 2018, regardless of manufacture date, no rich burn engine greater than or equal to 100 hp authorized by this permit shall emit NOx in excess of 0.5 g/bhp-hr. If an authorization or authorizations is issued for a spark ignited rich burn engine under this standard permit after the applicable date of January 1, 2015 or January 1, 2018, NOx emissions from that engine shall not exceed 0.5 g/bhp-hr, except that the standard permit holder shall have a one year grace period from the date of the initial authorization under this standard permit to comply with the limit of 0.5 g/bhp-hr for NOx. The commission reserves the right to re-evaluate the upgrade requirement if EPA promulgates any standards for existing engines. Lean Burn, 2SLB Nonemergency, Sparkignited less than 500 All dates hp greater than or equal to 500 hp Before September 23, 1982 Before June 18, 1992 and rated less than 825 hp no standard 8 8 no standard no standard 3 no standard 3 no standard After September 23, 1982, but 5 prior to June 18, 1992 and rated 825 hp or greater 3 no standard After June 18, 1992 but prior to July 1, 2010 2.0 except under reduced speed, 80-100% of full torque conditions may be 5.0 3 no standard On or after July 1, 2010 1 3 1 Lean Burn, 4SLB, Nonemergency, Sparkignited, and Dual-fuel less than 500 Before July 1, 2008 hp On or after July 1, 2008 greater than or equal to 500 hp Before September 23, 1982 Before June 18, 1992 and rated less than 825 hp no standard 2 5.0 except under reduced speed, 80-100% of full torque conditions may be 8.0 5.0 except under reduced speed, 80-100% of full torque conditions may be 8.0 no standard 3 3 3 no standard 1 no standard no standard After September 23, 1982, but 5 prior to June 18, 1992 and rated 825 hp or greater 3 no standard After June 18, 1992 but prior to July 1, 2010 2.0 except under reduced speed, 80-100% of full torque conditions, may be 5.0 3 no standard On or after July 1, 2010 1 3 1 After January 1, 2020, no spark ignited 4-stroke lean burn engine authorized by this standard permit that existed on-site on January 1, 2012, shall emit NOx in excess of 2.0 g/bhp-hr. If an oil and gas standard permit authorization or authorizations are is issued for a spark ignited 4-stroke lean burn engine after January 1, 2012, NOx emissions from that engine shall not exceed 2.0 g/bhp-hr after January 1, 2015. However, if the date of the initial authorization is after January 1, 2015, the standard permit holder shall have a three year grace period from the date of the initial authorization under the oil and gas standard permit to comply with the limit of 2.0 g/bhp-hr for NOx. The commission reserves the right to re-evaluate the upgrade requirement if EPA promulgates any standards for existing engine Turbines Turbines shall not emit greater than 25 ppmvd @ 15% O2 for NOX and 50 ppmvd @ 15% O2 for CO. Page 41 of 67 Table 7 Sampling and Demonstrations of Compliance Category Description Specifications and Expectations Exclusions Control Systems Control device monitoring and records are required only where the device is necessary for the site to meet emission rate limits Sampling General When Applicable Ports & Platforms, Methods, Notifications and Timing (A)If necessary, sampling ports and platforms shall be incorporated into the design of all exhaust stacks according to the specifications set forth in "Chapter 2, Stack Sampling Facilities." Engines and other facilities which are physically incapable of having platforms are excluded from this requirement. For control devices with effectiveness requirements only, appropriate sampling ports shall also be installed upstream of the inlet to control devices or controlled recovery systems with control efficiency requirements. Alternate sampling facility designs may be submitted for written approval by the Texas Commission on Environmental Quality (TCEQ) Regional Director or his designee. (B) Where stack testing is required, Sampling shall be conducted within 180 days of the change that required the registration, in accordance with the appropriate procedures of the TCEQ Sampling Procedures Manual and in accordance with the appropriate EPA Reference Methods. Unless otherwise specified, each performance test shall consist of three separate runs using the applicable test method. Each run shall be conducted for the time and under the conditions specified in the applicable standard. Where appropriate, sampling shall occur as three one-hour test runs and then averaged to demonstrate compliance with the limits of this authorization. Any deviations from those procedures must be approved in writing by the TCEQ Regional Director or his designee prior to sampling. (C) The Regional Office shall be afforded the opportunity to observe all such sampling. (D) The holder of this authorization is responsible for providing sampling and testing facilities and conducting the sampling and testing operations at his expense. (E) The TCEQ Regional Office that has jurisdiction over the site shall be contacted as soon as any testing is scheduled, but not less than 30 days prior to sampling. The region shall have discretion to amend the 30 day prior notification. Except for engine testing and liquid/gas analysis sampling, all other sampling shall include an opportunity for the appropriate regional office to schedule a pretest meeting. The notice shall include: (i) Date for pretest meeting, if required; (ii)Date sampling will occur; (iii) Name of firm conducting sampling; (iv)Type of sampling equipment to be used; (v) Method or procedure to be used in sampling; (vi)Procedure used to determine operating rates or other relevant parameters during the sampling period; (vii) parameters to be documented during the sampling event; (viii) any proposed deviations to the prescribed sampling methods. If held, the purpose of the pretest meeting is to review the necessary sampling and testing procedures, to provide the proper data forms for recording pertinent data, and to review the format procedures for submitting the test reports. (F) Within 60 days after the completion of the testing and sampling required herein, one original and one copy of the sampling reports shall be sent to the Regional Office. (G) When sampling is required, all Quality Assurance/Quality Control shall follow 30 TAC Ch 25 National Environmental Laboratory Accreditation Conference accreditation requirements. Fugitive monitoring Analyzers and LDAR An approved gas analyzer or other approved detection monitoring device used for the volatile organic compound fugitive inspection and repair requirement is a device that conforms to the requirements listed in Title 40 CFR '60.485(a) and (b), or is otherwise approved by the Environmental Protection Agency as a device to monitor for VOC fugitive emission leaks. Approved gas analyzers shall conform to requirements listed in Method 21 of 40 CFR Part 60, Appendix A. The gas analyzer shall be calibrated with methane. In addition, the response factor of the instrument for a specific VOC of interest shall be determined and meet the requirements of Standard permit 8 of Method 21. If a mixture of VOCs is being monitored, the response factor shall be calculated for the average composition of the process fluid. If a response factor less than 10 cannot be achieved using methane, then the instrument may be calibrated with one of the VOC to be measured or any other VOC so long as the instrument has a response factor of less than 10 for each of the VOC to be measured. In lieu of using a hydrocarbon gas analyzer and EPA Method 21, the owner or operator may use the Alternative Work Practice in 40 CFR Part 60, 60.18(g) - (i). The optical gas imaging instrument must meet all requirements specified in 40 CFR 60.18(g) (i), except the annual Test Method 21 requirement in 40 CFR 60.18(h)(7) and the reporting requirement in 40 CFR 60.18(i)(5) do not apply. Page 42 of 67 Table 7 Sampling and Demonstrations of Compliance Category Description Specifications and Expectations Verify composition All site-specific Reports necessary to verify composition (including hydrogen sulfide (H2S) at any of materials gas or liquid point in the process. All analyses shall be site specific or a representative sample may analyses be used to estimate emissions if all of the parameters in the gas and liquid analysis protocol provided by the commission are met. A site-specific or define representative analysis shall be performed within 90 days of initial start of operation or implementation of a change which requires registration. When new streams are added to the site and the character or composition of the streams change and cause an increase in authorized emissions, or upon request of the appropriate Regional office or local air pollution control program with jurisdiction, a new analysis will need to be performed. Analysis techniques may include, but are not limited to, Gas Chromatography (GC), Tutweiler, stain tube analysis, and sales oil/condensate reports. These records will document the following: (A) H2S content; (B) flow rate; (C) heat content; or (D) other characteristic including, but not limited to: (i) American Petroleum Institute gravity and Reid vapor pressure (RVP);(ii) sales oil throughput; or (iii) condensate throughput. Engines & Turbines Engines Initial Sampling of (i)Any engine greater than 500 horsepower; (ii) Any turbine Periodic Evaluation Laboratory extended VOC GC analysis at a minimum to C10+ and H2S analysis for gas and liquids for the following shall be performed and used for emission compliance demonstrations:(A) Separator at the inlet; (B) Dehydration Unit / Glycol Contactor prior to dehydrator;(C) Amine Unit prior to sweetening unit; (D) Separator dumping to gunbarrel or storage tank; (E) Tanks for liquids and vapors; or (F) P Perform stack sampling and other testing as required to establish the actual quantities of air contaminants being emitted into the atmosphere (including but not limited to nitrogen oxide (NOX), carbon monoxide (CO), and oxygen (O2). Each combustion facility shall be tested at a minimum of 50% of the design maximum firing rate of the facility. Each tested firing rate shall be identified in the sampling report. Sampling shall occur within 180 days after initial start-up of each unit. Additional sampling shall occur as requested by the TCEQ Regional Director. If there are multiple engines at an oil and gas sites (OGS) of identical model, year, and control system, sampling may be performed on 50% of the units and used for compliance demonstration of all identical units at the OGS. The remaining 50% of the units not initially tested must be tested during the next biennial testing period. This sampling is not required upon initial installation at any location if the engine or turbine was previously installed and tested at any location in the United States and the test conformed with EPA Reference Methods. Regardless of engine location, records of performance testing, or relied upon sampling reports, must remain with each specific engine for a minimum of five years unless records are unavailable and the permit holder performs the initial sampling on-site. No one may claim records are unavailable for the time period in which an engine is at the site which is authorized by this standard permit. This testing is not required for emergency engines unless requested by the TCEQ Regional Director. Idle engines do not need to be re-started only for the purpose of completing required testing. If biennial testing is required for an engine that is re-started for production purposes, the biennial testing is required within 30 days after re-starting the engine. The following is applicable to sites with federal operating permits only: (A) For any engine with a NOx standard under Table 6, conduct evaluations of each engine performance quarterly after initial compliance testing by measuring the NOx and CO content of the exhaust. Tests shall occur more than 30 days apart. Individual engines shall be subject to the quarterly performance evaluation if they were in operation for 1000 hours or more during the quarter period. If an engine is not operating, the permit holder may delay the test until such time as the engine is expected to run for more than fourteen days. Idled engines do not need to be re-started only for the purpose of completing required testing. Page 43 of 67 Table 7 Sampling and Demonstrations of Compliance (continued) Category Description Specifications and Expectations Engines (continued) Periodic Evaluation (continued) (B) The use of portable analyzers specifically designed for measuring the concentration of each contaminant in parts per million by volume is acceptable for these evaluations. The portable analyzer shall be operated at minimum in accordance with the manufacturer's instructions. The operator may modify the procedure if it does not negatively alter the accuracy of the analyzer. Also, colorimetric testing (stain tubes) maybe used in these periodic evaluations. The NOx and CO emissions then shall be converted into units of grams per horsepower-hour and pounds per hour. (C) Emissions shall be measured and recorded in the as-found operating condition, except no compliance determination shall be established during start-up, shutdown, or under breakdown conditions. (D) In lieu of the above mentioned periodic monitoring for engines and biennial testing, the holder of this permit may install, calibrate, maintain, and operate a continuous emission monitoring system (CEMS) to measure and record the concentrations of NOx and CO from any engine, turbine, or other external combustion facility. Diluents to be measured include O2 or CO2. Except for system breakdowns, repairs, calibration checks, zero and span adjustments, and other quality assurance tests, the Continuous Emission Monitoring Systems (CEMS) shall be in continuous operation and shall record a minimum of four, and normally 60, approximately equally spaced data points for each full hour. The NOx and diluents CEMS shall be operated according to the methods and procedures as set out in 40 CFR Part 60, Appendix B, Performance Specifications 2 and 3. The CO CEMS shall be operated according to the methods and procedures as set out in 40 CFR Part 60, Appendix B, Performance Specifications 4, 4A, or 4B. CEMS shall follow the quality assurance requirements of Appendix F except that Cylinder Gas Audits may be conducted in all four calendar quarters in lieu of the annual Relative Accuracy Test Audit. A CEMS with downtime due to breakdown or repair of more than 10% of the facility operating time for any calendar shall be considered as a defective CEMS and the CEMS shall be replaced within 2 weeks. Engines & Turbines Biennial Testing Every two years starting from the completion date of the Initial Compliance Testing, Any engine greater any engine greater than 500 horsepower or any turbine shall be retested according to than 500 the procedures of the Initial Compliance Testing. horsepower or any Retesting shall occur within 90 days of the two year anniversary date. If a facility has turbine been operated for less than 2000 hours during the two year period, it may skip the retesting requirement for that period. After biennial testing, any engine retested under the above requirements shall resume periodic evaluations within the next 6 calendar months (January to June or July to December). If biennial testing is required for an engine that is re-started for production purposes, the biennial testing shall be performed within 45 days after re-starting the engine. Oxidation or Initial Sampling Stack testing, when a company wants to establish efficiencies of 99% or greater, must Combustion and Monitoring be coordinated and approved. Sampling is required for VOC, benzene and H2S at Control Device for performance Region's discretion. The thermal oxidizer (TO) must have proper monitoring and for VOC, Benzene, sampling ports installed in the vent stream and the exit to the combustion chamber, and H2S to monitor and test the unit simultaneously. The temperature and oxygen measurement devices shall reduce the temperature and oxygen concentration readings to an averaging period of 6 minutes or less and record it at that frequency. The temperature measurement device shall be installed, calibrated, and maintained according to accepted practice and the manufacturer's specifications. The device shall have an accuracy of the greater of 0.75% of the temperature being measured expressed in degrees Celsius or 2.5C. The oxygen or carbon monoxide analyzer shall be zeroed and spanned daily and corrective action taken when the 24-hour span drift exceeds two times the amounts specified Performance Specification No. 3 or 4A, 40 CFR Part 60, Appendix B. Zero and span is not required on weekends and plant holidays if instrument technicians are not normally scheduled on those days. The oxygen or carbon monoxide analyzer shall be quality-assured at least semiannually using cylinder gas audits (CGAs) in accordance with 40 CFR Part 60, Appendix F, Procedure 1, 5.1.2, with the following exception: a relative accuracy test audit is not required once every four quarters (i.e., two successive semiannual CGAs may be conducted). An equivalent quality-assurance method approved by the TCEQ may also be used. Successive semiannual audits shall occur no closer than four months. Necessary corrective action shall be taken for all CGA exceedances of 15 percent accuracy and any continuous emissions monitoring system downtime in excess of 5% of the incinerator operating time. Page 44 of 67 Table 7 Sampling and Demonstrations of Compliance (continued) Category Description Specifications and Expectations Oxidation or Initial Sampling (continued) Combustion and Monitoring These occurrences and corrective actions shall be reported to the appropriate TCEQ Control Device (continued) for performance for VOC, Benzene, Regional Director on a quarterly basis. Supplemental stack concentration measurements may be required at the discretion of the appropriate TCEQ Regional and H2S (continued) Director. Quality assured or valid data of oxygen or carbon monoxide analyzer must be generated when the TO is operating except during the performance of a daily zero and span check. Loss of valid data due to periods of monitor break down, inaccurate data, repair, maintenance, or calibration may be exempted provided it does not exceed 5% of the time (in minutes) that the oxidizer operated over the previous rolling 12 month period. The measurements missed shall be estimated using engineering judgment and the methods used recorded. Page 45 of 67 Table 8 Monitoring and Records Demonstrations Category Description Record Information Site Production or Collection Equipment and facility summary Equipment specifications natural gas, oil, condensate, and water production records Current process description Process units, tanks, vapor recovery systems; flares; thermal oxidizers; and reboiler control devices Site inlet and outlet gas volume and sulfur concentration, daily gas/liquid production and load-out from tanks Accurate and detailed plot plan with property line, off-site receptors, and all equipment on-site or drawings with sufficient detail to confirm all authorized facilities to confirm emission estimates, impact review, and registration scope A copy of the registration and emission calculations including the fixed equipment sizes or capacities and manufacturer's specifications and programs to maintain performance, with the plan and records for routine inspection, cleaning, repair and replacement. Physical Inspection Voluntary LDAR Program Leaks in piping, fugitive components and process vessels Fugitive Component Check Details of fugitive component monitoring plan, and LDAR results, including QA, QC If a leak has been found and determined that there would be less emissions from the repair by delaying repair until the next shutdown, then a record of the calculation showing that the emissions would be less shall be kept. A record of the component count shall be maintained. A record of the date each quarterly inspection was made and the date components found leaking were repaired or the date of the planned shutdown. The following records are required where a company uses an LDAR program to reduce the potential fugitive emissions from the site to meet emission limitations or certify fugitive emissions. (A) A monitoring program plan must be maintained that contains, at a minimum, the following information: (i) an accounting of all the fugitive components by type and service at the site with the total uncontrolled fugitive potential to emit estimate; (ii) identification of the components at the site that are required to be monitored with an instrument or are exempt with the justification, note the following can be used for this purpose: (a) piping and instrumentation diagram (PID); or (b) a written or electronic database.; (iii) the monitoring schedule for each component at the site with difficult-to-monitor and unsafe-to-monitor valves, as defined by Title 30 Texas Administrative Code Chapter 115 (30 TAC Chapter 115), identified and justified, note if an unsafe-to-monitor component is not considered safe to monitor within a calendar year, then it shall be monitored as soon as possible during safe-to-monitor times and a record of the plan to monitor shall be maintained; and (iv) the monitoring method that will be used (audio, visual, or olfactory (AVO) means; Method 21; the Alternative Work Practice in 40 CFR 60.18(g) - (i)); (v) for components where instrument monitoring is used, information clarifying the adequacy of the instrument response; (vi) the plan for hydraulic or pressure testing or instrument monitoring new and reworked components. (B) Records must be maintained of all monitoring instrument calibrations. (C) Records must be maintained for all monitoring and inspection data collected for each component required to be monitored with a Method 21 portable analyzer that include the type of component and the monitoring results in ppmv regardless if the screening value is above or below the leak definition.. (D) Leaking components must be tagged and a leaking-components monitoring log must be maintained for all leaks greater than the applicable leak definition (i.e.10,000 ppmv, 2000 ppmv, or 500 ppmv) of VOC detected using Method 21, all leaks detected by AVO inspection, and all leaks found using Alternative Work Practice specified in 40 CFR 60.18(g)-(i). The log must contain, at a minimum, the following: (i) the method used to monitor the leaking component (audio, visual, or olfactory inspection; Method 21; or the Alternative Work Practice in 40 CFR 60.18(g) - (i)); (ii) the name of the process unit or other appropriate identifier where the component is located; (iii) the type (e.g., valve or seal) and tag identification of component; (iv) the results of the monitoring (in ppmv if a Method 21 portable analyzer was used); (v) the date the leaking component was discovered;(vi) the date that a first attempt at repair was made to a leaking component; (vii) the date that a leaking component is repaired; (viii) the date and instrument reading of the recheck procedure after a leaking component is repaired; and (ix) the leaks that cannot be repaired until turnaround and the date that the leaking component is placed on the shutdown list. (E) If the owner or operator is using the Alternative Work Practice specified in 40 CFR 60.18(g) - (i), the records required by 40 CFR 60.18(i)(4). Page 46 of 67 Table 8 Monitoring and Records Demonstrations (continued) Category Description Record Information Voluntary LDAR Program (continued) Details of fugitive component monitoring plan, and LDAR results, including QA, QC (continued) (F) A record of the monitored value any open-ended line or valve for which is a repair or replacement is not completed within 72 hours and monitoring in lieu of covering is chosen. (G) Any open-ended line or valve caused by a repair or replacement not completed within 72 hours shall be monitored as specified in table 10 and the checks and any corrective actions taken shall be recorded. (H) Weekly audio, visual and olfactory inspections shall be noted in a log (I) A check of the reading for any pressure-sensing device to verify rupture disc integrity shall be performed weekly and noted in a log. Minor Changes Equipment Replacement Process Units Additions, changes or replacement Like-Kind replacement Glycol Dehydration Units Amine Units Boilers, Reboilers, Heater-Treaters, and and Process Heaters Combustion Internal Combustion Engines Combustion Gas Fired Turbines Combustion Fuel Records VOC and Sulfur Content Tanks/Vessels Color/Exterior Records showing all replacements and additions, including summary of emission type and quantities, for a rolling 6-month period of time. Records on equipment specifications and operations, including summary of emissions type and quantity. For emission estimates, the worst-case combination of parameters resulting in the greatest emission rates must be used. If worst-case parameters are not used, then glycol dehydrator unit monitoring records include dry gas flow rate, absorber pressure and temperature, glycol type, and circulation rate recorded weekly. If worst-case parameters are not used, then in addition to weekly unit monitoring, where control of flash tank or reboiler emissions are required to meet the emission limitations of the section and emissions are certified, the following control monitoring requirements apply weekly: flash tank temperature and pressure, any reboiler stripping gas flow rate, and condenser outlet temperature. VRU, flare, or thermal oxidizer control or reboiler fire box used for control must comply with the monitoring and recordkeeping for those devices. Where all emissions from the flash tank and the reboiler or reboiler condenser vent are directed to a VRU, flare, or thermal oxidizer designed to be on-line at all times the glycol dehydrator is in operation, the control system monitoring for the glycol dehydrator is not required. Amine units may simply retain site production or inlet gas records if all sulfur compounds in the inlet are assumed to be emitted. Where only partial removal of the inlet sulfur is assumed, for emission estimates, the worst-case combination of parameters resulting in the greatest emission rates must be used. If worst-case parameters are not used, then records of the amine solution, contactor pressure, temperature and pump rate shall be maintained. Where the waste gas is vented to combustion control, the requirements of the control device utilized should be noted. Records of Operational Monitoring and Testing Records Records of the hours of operation of every combustion device of any size by the use of a process monitor such as a run time meter, fuel flow meter, or other process variable that indicates a unit is running unless, in the registration for the facility, the emissions from the facility were calculated using full year operation at maximum design capacity in which case no hours of operation records must be kept. Records of Appropriate Operational Monitoring and Testing Records Records of the hours of operation of every combustion device and engine of any size by the use of a process monitor such as a run time meter, fuel flow meter, or other process variable that indicates a unit is running. The owner or operator may test and retest at the most frequent intervals identified in Table 7 in lieu of installing a process monitor and recording the hours of operation. If an engine has no testing requirements in Table 7, no records of the hours of operation must be kept. See fuel records below Records of Appropriate Operational Monitoring and Testing Records Records of the hours of operation of every turbine greater than 500 hp by the use of a process monitor such as a run time meter, fuel flow meter, or other process variable that indicates a unit is running unless the permit holder determined emissions from the facility assuming full year operation at maximum design capacity in which case no hours of operation records must be kept. A fuel flow meter is not required if emissions are based on maximum fuel usage for 8,760 hr/yr. There are no specific requirements for allowable VOC content of fuel. If field gas contains more than 1.5 grains (24 ppmv) of H2S or 30 grains total sulfur compounds per 100 dry standard cubic feet, the operator shall maintain records, including at least quarterly measurements of fuel H2S and total sulfur content, which demonstrate that the annual SO2 emissions do not exceed limitations Records demonstrating design, inspection, and maintenance of paint color and vessel integrity. Page 47 of 67 Table 8 Monitoring and Records Demonstrations (continued) Category Description Record Information Tanks/Vessels Truck Loading Control Devices Emission and emission potential All Types Vacuum Trucks Controlled Loading Vapor Capture and Recovery Maintain a record of the material stored in each tank/vessel that vents to the atmosphere and the maximum vapor pressure used to establish the maximum potential short-term emission rate. Where pressurized liquids can flash in the tank/vessel monitor and record weekly the maximum fluid pressure that can enter the tank / vessel. Records that tank / vessel hatches and relief valves are properly sealed when tank /vessel is directed to control and after loading events (as needed). Records indicating type of material loaded, amount transferred, method of transfer, condition of tank truck before loading. Note loading with an air mover or vacuum. No additional record is needed where a vacuum truck uses only an on-board or portable pump to push material into the truck. Where control is required note the control that is utilized. Records of hours of use are required for all units and on-line time must be considered when emission estimates and actual emissions inventories are calculated. mVRU Basic Design Function Record: Record demonstrating the unit captures vapor and includes a sensing device set to capture this vapor at peak intervals. Additional Design Parameter Record: Record demonstrating additional design parameters are utilized such as additional sensing equipment, a properly designed bypass system, an appropriate gas blanket, an adequate compressor selection, and the ability to vary the drive speed for units utilizing electric driven compressors mVRUs that are used at oil and gas sites to control emissions may claim up to 100% control efficiency provided records of basic and additional design functions and parameters of a VRU along with appropriate records listed in Table 8 are satisfied. mVRUs may claim up to 99% control efficiency for units where records of basic and additional design functions are satisfied and parameters listed in Table 8 are not satisfied. mVRUs may claim up to 95% control efficiency for units where records listed in Table 8 are not satisfied. lVRU The record of proper design must be kept to demonstrate how the unit was designed and for what capacity. The record of liquid replacement must be kept, along with the calculations for demonstrating that the VOC to liquid ratio has been maintained. Additionally, the system must be tested to demonstrate the efficiency. This testing needs to be performed and results recorded to receive 95% control efficiency no longer than: vacuum truck emissions: after 20 loads have been pulled through the lVRU, for tanks: Produced Water - Monthly, Crude - Bi-Monthly, Condensate - Weekly. This testing needs to be performed and results recorded to receive 98% control efficiency no longer than: vacuum truck emissions: after 15 loads have been pulled through the lVRU, for tanks: Produced Water - 3 weeks, Crude - 10 days, Condensate - 5 days. All valves must be designed and maintained to prevent leaks. All hatches and openings must be properly gasketed and sealed with the unit properly connected. Downtime is limited to a rolling 12 month average of 5% or 432 hr/per rolling 12 months and waste vents shall be redirected to an appropriate control device if possible during down time unless otherwise registered for alternate operating hours. Cooling Tower Design data Records shall be kept of maximum cooling water circulation rate and basis, maximum total dissolved solids allowed as maintained through blowdown, and towers design drift rate. These records are only required if the cooling system is used to cool process VOC streams or control from drift eliminators or minimizing solids content is needed to meet particulate matter emission limits. Page 48 of 67 Table 8 Monitoring and Records Demonstrations (continued) Category Description Record Information Planned Maintenance, Start-up, and Shutdown (MSS) Planned MSS Planned MSS Planned MSS Planned MSS Particulate Monitoring, Maintenance and Repair. Alternate Operational Scenarios and Redirection of Vent Streams Pigging, Purging and Blowdowns Temporary Facilities for Bypass, and Degassing and Purging Management of Sludge from Pits, Ponds, Sumps and Water Conveyances Degassing or Purging of Tanks, Vessels, or Other Facilities Inspect and record integrity of drift eliminators annually, repairing as necessary. If a maximum solids content must be maintained through blowdowns to meet particulate emission rate limits, cooling water shall be sampled for total dissolved solids (TDS) once a month at prior to any periodic blow downs and maintain records of the monitoring results and all corrective actions. Cooling water VOC concentrations above 0.08 parts per million by volume (ppmv) indicate faulty equipment. Equipment shall be maintained so as to minimize VOC emissions into the cooling water. Faulty equipment shall be repaired at the earliest opportunity but no later than the next scheduled shutdown of the process unit in which the leak occurs. Records must be maintained of all monitoring data and equipment repairs. Records of redirection of vent streams during primary operational unit or control downtime, including associated alternate controls, releases and compliance with emission limitations. Pigging records, including catcher design, date, emission estimate to atmosphere and to control, and when controlled, the control device. Note where a control device is necessary to meet emission limitations the device is subject to the requirements of standard permit (e) and record requirements of this table. Purging and blowdown records, including the volume and pressure and a description of the piping and equipment involved, the date, emission estimate to atmosphere and to control, and when controlled, the control device. Where purging to control to meet a lower concentration before purging to atmosphere is conducted the concentrations of VOC, BTEX or H2S as appropriate must be measured and recorded prior to purging to atmosphere. Note where a control device is necessary to meet emission limitations the device is subject to the requirements of standard permit (e) and record requirements of this table. Temporary facility records, including a description and estimate of potential fugitive emissions from temporary piping, size and design of facilities (eg. tanks or pan volume, fill method, and throughput; engine horse power, fuel and usage time, flare tip area, ignition method, and heating value assurance method; etc.) and the date and emission estimate to atmosphere and to control for their use Records including the source identification, removal plan, emission estimate direct to atmosphere and through control. Note where a control device is necessary to meet emission limitations the device is subject to the requirements of standard permit (e) and record requirements of this table. Records including: a) the EPN and description of vessels and equipment degassed or purged; b) the material, volume and pressure (if applicable); c) the volume of purge gas used; d) a description of the piping and equipment involved; e) clarifying estimates for a coated surface or heel; f) the date; g) emission estimate to atmosphere and to control; h) when controlled, the control device; and i) where purging to a control device to reduce concentrations before purging to atmosphere, the concentrations of VOC, BTEX or H2S as appropriate must be measured and recorded prior to purging to atmosphere. Planned MSS Records Records or copies of work orders, contracts, or billing by contractors for the following activities shall be kept at the site, or nearest manned site, and made available upon request: x Routine engine component maintenance including filter changes, oxygen sensor replacements, compression checks, overhauls, lubricant changes, spark plug changes, and emission control system maintenance; x Boiler refractory replacements and cleanings; x Heater and heat exchanger cleanings; x Turbine hot standard permit swaps; x Pressure relief valve testing, calibration of analytical equipment; instrumentation/analyzer maintenance; replacement of analyzer filters and screens. Page 49 of 67 Table 8 Monitoring and Records Demonstrations (continued) Category Description Record Information Control Devices Control Devices Flare Monitoring Thermal Oxidation and Vapor Combustion Performance Monitoring Basic Intermediate Enhanced Alternate Monitoring Basic monitoring requires the flare and pilot flame to be continuously monitored by a thermocouple or an infrared monitor. Where an automatic ignition system is employed, the system shall ensure ignition when waste gas is present. The time, date, and duration of any loss of flare, pilot flame, or auto-ignition shall be recorded. Each monitoring device shall be accurate to, and shall be calibrated at a frequency in accordance with, the manufacturer's specifications. A temporary, portable or backup flare used less than 480 hours per year is not required to be monitored. Records of hours of use are required for all units and on-line time must be considered when emission estimates and actual emissions inventories are calculated. Control device monitoring and records are required only where the device is necessary for the site to meet emission rate limits. Basic monitoring is a thermocouple or infrared monitor that indicates the device is working. Records of hours of use are required for all units and on-line time must be considered when emission estimates and actual emissions inventories are calculated. Intermediate monitoring and records include continuously monitoring and recording temperature to insure the control device is working when waste gas can be directed to the device and showing compliance with the 1400 degrees Fahrenheit if applicable. Enhanced monitoring requires continuous temperature and oxygen or carbon monoxide monitoring on the exhaust with six minute averages recorded to show compliance with the temperature requirement and the design oxygen range or a CO limit of 100 ppmv. Some indication of waste gas flow to the control device, like a differential pressure, flow monitoring or valve position indicator, must also be continuously recorded, if the flow to the control device can be intermittent. Records of stack testing and the monitored parameters during the testing shall be maintained to allow alternate monitoring parameters and limits. Control Devices Control with process combustion or heating devices (e.g. reboilers, heaters & furnaces) Basic monitoring is any continuous monitor that indicates when the flame in the device is on or off (other than partial operational use). The following are effective basic options: a fire box temperature monitor, rising or steady process temperature monitor, CO monitor, primary fuel flow monitor, fire box pressure monitor or equivalent. Enhanced monitoring for 91 to 99% control, where waste gas is not introduced as the primary fuel, must include the following monitors: continuous fire box or fire box exhaust temperature, and CO and O2 monitoring, with at least 6 minute averages recorded. Additionally, enhanced monitoring where the waste gas may be flowing when the control device is not firing must show continuous disposition of the waste gas streams, including continuous monitoring of flow or valve position through any potential by-pass to the control where more than 50% run time of control is claimed. [Basic monitoring is any continuous monitor that indicates when the flame in the device is on or off (other than partial operational use). The following are effective basic options: a fire box temperature monitor, rising or steady process temperature monitor, CO monitor, primary fuel flow monitor, fire box pressure monitor or equivalent. Enhanced monitoring for 91 to 99% control, where waste gas is not the primary fuel, must include the following monitors: continuous fire box or fire box exhaust temperature monitoring; and CO and O2 monitoring, with at least 6 minute averages recorded. Additionally, enhanced monitoring where the waste gas may be flowing when the control device is not firing must show continuous disposition of the waste gas streams. This includes continuous monitoring of flow or valve position through any potential by-pass to the control where more than 50% run time of the control is claimed.] Page 50 of 67 Table 9 Fugitive Component LDAR BACT Table Fugitive component Leak Detection and Repair (LDAR) Best Available Control Technology (BACT) Requirements Table Exceptions All fugitive components must meet the minimum design, monitoring, control and other emissions techniques listed in this Table unless the component's service meets one of the following exceptions: Additional Details Compliance with these requirements does not assure compliance with requirements of NSPS, NESHAPS or MACT, and does not constitute approval of alternate standards for these regulations. Total uncontrolled potential to emit from all FRPSRQHQWVWS\ Nitrogen lines No expectation to estimate emissions. Note this exemption does not include lines with nitrogen that has been used as a sweep gas. Steam lines (non contact) No expectation to estimate emissions. )OH[LEOHSODVWLFWXELQJLQFKHVLQGLDPHWHU unless it is subject to monitoring by other state or federal regulations. No expectation to estimate emissions, unless it is subject to monitoring by other state or federal regulations. The operating pressure is at least 5 kilopascals (0.725 psi) below ambient pressure No expectation to estimate emissions. Mixtures in streams where the VOC has an No expectation to estimate emissions. aggregate partial pressure of less than 0.002 psia at 68oF. Components containing only noble gases, inserts such as CO2 and water or air contaminants not typically listed on a MAERT such as methane, ethane, and Freon. No expectation to estimate emissions. Instrument monitoring is not required for pipeline quality sweet natural gas Uncontrolled Emissions should be estimated. Must meet pipeline quality specifications Instrument monitoring is not required when the aggregate partial pressure or vapor pressure is less than 0.044 psia at 68 1F or at maximum process operating temperature. Uncontrolled Emissions should be estimated. This applies at all times, unless a control efficiency is being claimed for instrument monitoring, in which case there must be a record supporting that the instrument could detect a leak. Instrument monitoring is not required for waste water lines containing less than 1% VOC by weight DQGRSHUDWHGDWSVLJ Uncontrolled Emissions should be estimated. Instrument monitoring is not required for cooling Emissions are estimated and associated water line components with the cooling tower Page 51 of 67 Table 9 Fugitive Component LDAR BACT Table (continued) Fugitive component Leak Detection and Repair (LDAR) Best Available Control Technology (BACT) Requirements Table (continued) Instrument monitoring is not required for CO2 lines after VOC is removed. This is referred to as Dry Gas lines in 40 CFR Part 60 Subpart KKK, and defined as a stream having a VOC weight percentage less than 4 %; a weighted average Effects Screening Level (ESL) of the combined VOC stream is > 3,500 )g/m3; and total uncontrolled emissions for all such sources is < 1 ton per year at any OGS. Uncontrolled Emissions should be estimated. The weighted average ESLx for process stream, X, with multiple VOC species will be determined by: ESLx = fa/ESLa + fb/ESLb + fc/ESLc + . + fn/ESLn Where: n =total number of VOC species in process stream; ESLn WKHHIIHFWVVFUHHQLQJOHYHOLQJP3 for the contaminant being evaluated (published in the most recent edition of the TCEQ ESL list); fn=the weight fraction of the appropriate VOC species in relation to all other VOC in process stream. At OGS sites where the total uncontrolled potential to emit from all components < 25 tpy, instrument monitoring is not required on components where the aggregate partial pressure or vapor pressure is less than 0.5 psia at 100 F or at maximum process operating temperature, unless the components are subject to monitoring by other state or federal regulations. Uncontrolled Emissions should be estimated. Minimum Design, Monitoring, Technique or Control for all fugitive components ZLWKXQFRQWUROOHGSRWHQWLDOWRHPLWRIWS\92&RUWS\+6 Requirements Additional Details Construction of new and reworked piping, valves, pump systems, and compressor systems shall conform to applicable American National Standards Institute (ANSI), American Petroleum Institute (API), American Society of Mechanical Engineers (ASME), or equivalent codes. To the extent that good engineering practice will permit, new and reworked valves and piping connections shall be so located to be reasonably accessible for leak-checking during plant operation. Page 52 of 67 Table 9 Fugitive Component LDAR BACT Table (continued) Fugitive component Leak Detection and Repair (LDAR) Best Available Control Technology (BACT) Requirements Table (continued) Minimum Design, Monitoring, Technique or Control for all fugitive components ZLWKXQFRQWUROOHGSRWHQWLDOWRHPLWRIWS\92&RUWS\+6 Requirements Additional Details New and reworked underground process pipelines shall contain no buried valves such that fugitive emission monitoring is rendered impractical. New and reworked piping connections shall be welded or flanged. Screwed connections are permissible only on piping smaller than two-inch diameter. Gas or hydraulic testing of the new and reworked piping connections at no less than operating pressure shall be performed prior to returning the components to service or they shall be monitored for leaks using an approved gas analyzer within 15 days of the components being returned to service. Where technically feasible new and reworked components may be screened for leaks with a soap bubble test within 8 hours of being returned to service in lieu of instrument testing. Adjustments shall be made as necessary to obtain leak-free performance. Each open-ended valve or line shall be equipped with an appropriately sized cap, blind flange, plug, or a second valve to seal the line so that no leakage occurs. Except during sampling, both valves shall be closed. If the removal of a component for repair or replacement results in an open ended line or valve, it is exempt from the requirement to install a cap, blind flange, plug, or second valve for 72 hours. If the repair or replacement is not completed within 72 hours, the permit holder must complete either of the following actions within that time period: the line or valve must have a cap, blind flange, plug, or second valve installed; or the open-ended valve or line shall be monitored once for leaks above background for a plant or unit turnaround lasting up to 45 days with an approved gas analyzer and the results recorded. For all other situations, the open-ended valve or line shall be monitored once at the end of the 72 hour period following the creation of the open ended line and monthly thereafter with an approved gas analyzer and the results recorded. For turnarounds and all other situations, leaks are indicated by readings 20 ppmv above background Page 53 of 67 Table 9 Fugitive Component LDAR BACT Table (continued) Fugitive component Leak Detection and Repair (LDAR) Best Available Control Technology (BACT) Requirements Table (continued) Minimum Design, Monitoring, Technique or Control for all fugitive components with XQFRQWUROOHGSRWHQWLDOWRHPLWRIWS\92&RUWS\+6 Requirements Additional Details and must be repaired within 24 hours or a cap, blind flange, plug, or second valve must be installed on the line or valve. Components shall be inspected by visual, audible, and/or olfactory means at least weekly by operating personnel walk-through. Accessible valves shall be monitored by leakchecking for fugitive emissions quarterly using an approved gas analyzer. Sealless/leakless valves (including, but not limited to, welded bonnet bellows and diaphragm valves) and relief valves equipped with a rupture disc upstream or venting to a control device are not required to be monitored. If an unsafe-to-monitor valve is not considered safe to monitor within a calendar year, then it shall be monitored as soon as possible during safe-to-monitor times. A difficult-to-monitor component for which quarterly monitoring is specified may instead be monitored annually. Sealless/leakless valves and relief valves equipped with rupture disc or venting to a control device and exempted from instrument monitoring are not counted in the fugitive emissions estimates. See Table 7 Sampling and Demonstrations of Compliance for Fugitive and LDAR Analyzer requirements. See Table 8, Monitoring and Records Demonstrations to identify Difficult-to-monitor and unsafe-to-monitor valves. For valves equipped with rupture discs, a pressure- All leaking discs shall be replaced at the sensing device shall be installed between the relief earliest opportunity but no later than the valve and rupture disc to monitor disc integrity. next process shutdown. All pump, compressor and agitator seals shall be monitored quarterly with an approved gas analyzer or be equipped with a shaft sealing system that prevents or detects emissions of VOC from the seal. Seal systems designed and operated to prevent emissions or seals equipped with an automatic seal failure detection and alarm system need not be instrument monitored. Seal systems that prevent emissions may include (but are not limited to) dual pump seals with barrier fluid at higher pressure than process pressure or seals degassing to vent control systems kept in good working order. Submerged pumps or sealless pumps (including, but not limited to, diaphragm, canned, or magnetic-driven pumps) may be used to satisfy the requirements of this condition and need not be monitored. Pumps compressor and agitator seals that prevent leaks or direct emissions from the seals to control and are exempt from instrument monitoring are not counted in the fugitive emissions estimates. Equipment equipped with alarms would still be counted. See Table 7 Sampling and Demonstrations of Compliance for Fugitive and LDAR Analyzer requirements. Page 54 of 67 Table 9 Fugitive Component LDAR BACT Table (continued) Fugitive component Leak Detection and Repair (LDAR) Best Available Control Technology (BACT) Requirements Table (continued) Minimum Design, Monitoring, Technique or Control for all fugitive components with XQFRQWUROOHGSRWHQWLDOWRHPLWRIWS\92&RUWS\+6 Requirements Additional Details For a site where the total uncontrolled potential to emit from all components is < 25 tpy; Components found to be emitting VOC in excess of 10,000 parts per million by volume (ppmv) using EPA Method 21, found by visual inspection to be leaking (e.g. whistling, dripping or blowing process fluids or emitting hydrocarbon or H2S odors) or found leaking using the Alternative Work Practice in 40 CFR 60.18(g) - (i) shall be considered to be leaking and shall be repaired, replaced, or tagged as specified. A first attempt to repair the leak must be made within 5 days. A leaking component shall be repaired as soon as practicable, but no later than 15 days after the leak is found. If the repair of a component would require a unit shutdown, the repair may be delayed until the next scheduled shutdown. All leaking components which cannot be repaired until a scheduled shutdown shall be identified for such repair by tagging. Components subject to routine instrument monitoring with an approved gas analyzer under this leak definition my claim a 75% emission reduction credit when evaluating controlled fugitive emission estimates. This reduction credit does not apply when evaluating uncontrolled emission or to any component not measured with an instrument quarterly, but is allowed for all components monitored by the Alternative Work Practice. See Table 7 Sampling and Demonstrations of Compliance for Fugitive and LDAR Analyzer requirements Components not subject to an instrument monitoring program but found to be emitting VOC in excess of 10,000 ppmv using EPA Method 21, found by audio, visual or olfactory inspection to be leaking (e.g. whistling, dripping or blowing process fluids or emitting hydrocarbon or H2S odors) shall be considered to be leaking and shall be repaired, replaced, or tagged as specified. All components are subject to monitoring when using the Alternative Work Practice in 40 CFR 60.18(g) (i). At the discretion of the TCEQ Executive Director or designated representative, early unit shutdown or other appropriate action may be required based on the number and severity of tagged leaks awaiting shutdown. Page 55 of 67 Table 9 Fugitive Component LDAR BACT Table (continued) Fugitive component Leak Detection and Repair (LDAR) Best Available Control Technology (BACT) Requirements Table (continued) Minimum Design, Monitoring, Technique or Control for all fugitive components with XQFRQWUROOHGSRWHQWLDOWRHPLWRIWS\RUWS\+6 For a site where the total uncontrolled potential to emit from all components is WS\; All the requirements for < 25tpy VOC above apply, except valves found to be emitting VOC in excess of 500 ppmv using EPA Method 21, found by audio, visual or olfactory inspection to be leaking (e.g. whistling, dripping or blowing process fluids or emitting hydrocarbon or H2S odors) or found leaking using the Alternative Work Practice in 40 CFR 60.18(g) (i) shall be considered to be leaking and shall be repaired, replaced, or tagged as specified and Pump, compressor, and agitator seals found to be emitting VOC in excess of 2,000 ppmv using EPA Method 21, found by audio, visual or olfactory inspection to be leaking (e.g. whistling, dripping or blowing process fluids or emitting hydrocarbon or H2S odors) or found leaking using the Alternative Work Practice in 40 CFR 60.18(g) - (i) shall be considered to be leaking and shall be repaired, replaced, or tagged as specified. Components subject to routine instrument monitoring under this leak definition my claim a 97% emission reduction credit for valves and an 85% emission reduction credit for pump, compressor and agitator seals when evaluating controlled fugitive emission estimates. This reduction credit does not apply when evaluating uncontrolled emission or to any component not measured with an instrument quarterly. See Table 7 Sampling and Demonstrations of Compliance for Fugitive and LDAR Analyzer requirements. LDAR Monitoring Options Any site may reduce the controlled fugitive emission estimates by including components not required to be monitored in the quarterly instrument monitoring program or applying the lower leak definition of the more stringent program as appropriate. Quarterly monitoring at a leak definition of 10,000 ppmv would equate to a 75% emission reduction credit when evaluating controlled fugitive emission estimates for the component. Quarterly monitoring at a leak definition of 500 ppmv would equate to a 97% emission reduction credit for valves, flanges and connectors, a 93% emission reduction credit for pumps, and a 95% emission reduction credit for compressor, agitator seals and other component groups when evaluating controlled fugitive emission estimates. This reduction credit does not apply when evaluating uncontrolled emission or to any component not measured with an instrument quarterly. See Table 7 Sampling and Demonstrations of Compliance for Fugitive and LDAR Analyzer requirements. Page 56 of 67 Table 9 Fugitive Component LDAR BACT Table (continued) Fugitive component Leak Detection and Repair (LDAR) Best Available Control Technology (BACT) Requirements Table (continued) Minimum Design, Monitoring, Technique or Control for all fugitive components ZLWKXQFRQWUROOHGSRWHQWLDOWRHPLWRIWS\RUWS\+6 Requirements Additional Details LDAR Monitoring Options After completion of the required quarterly inspections for a period of at least two years, the operator of the OGS facility may change the monitoring schedule as follows:(i)After two consecutive quarterly leak detection periods with the percent of valves leaking equal to or less than 2.0%, an owner or operator may begin to skip one of the quarterly leak detection periods for the valves in gas/vapor and light liquid service.(ii)After five consecutive quarterly leak detection periods with the percent of valves leaking equal to or less than 2.0%, an owner or operator may begin to skip three of the quarterly leak detection periods for the valves in gas/vapor and light liquid service. If the owner or operator is using the Alternative Work Practice in 40 CFR 60.18(g) - (i), the alternative frequencies specified in this standard permit are not allowed. Shutdown prior to Maintenance of Fugitive Start-up after Maintenance of Components components All components shall be kept in good repair. During repair or replacement, emission releases from the emptying of associated piping, equipment, and vessels must meet the emission limits and control requirements listed under pipeline or compressor blowdowns. When returning associated equipment and piping to service after repair or replacement of fugitive components, appropriate leak detection shall occur and correction, maintenance or repair shall be immediately performed if fugitive components are not in good working order. Page 57 of 67 Table 10 Best Available Control Technology Requirements Source or Facility Air Contaminant Minimum Acceptable Design, Control or Technique, Control Efficiencies, and Other Details during Production Operations Combined Control Requirements < 25 tpy VOC No add on control is required if the continuous and periodic vents from all units, vessels and equipment (including normal operation process blow downs) is less than 25 tons of VOC per year. WS\92& All continuous and periodic vents on process vessels and HTXLSPHQWZLWKSRWHQWLDOHPLVVLRQVFRQWDLQLQJ92&DW any time must be captured and directed to a control device listed in the Control Device BACT Table with a minimum design control efficiency of at least 95%, if the sum of the uncontrolled PTE of the vents at the site will equal or exceed 25 tons of VOC per year. A site total potential to emit of 1 tpy of VOC from vent gas streams may be exempted from this control requirement. Glycol Dehydration Unit Uncontrolled PTE < 10 tpy VOC VOC, BTEX, H2S No control is required. Condensers included in the equipment constructed must be maintained and operated as specified by the manufacturer or design engineering. Uncontrolled 37(WS\ and < 50 tpy VOC VOC, BTEX, H2S All non-combustion VOC emissions shall be routed to a vapor recovery unit (VRU), the unit reboiler, or to an appropriate control device listed in the Control Device BACT Table. This includes the emissions from the condenser vent. Liquid waste or product material captured by a condenser must be enclosed and transferred to a unit compliant with the requirements of this table and the condenser must meet the requirements listed in the Control Device BACT Table with a minimum design control efficiency of 80%. For condensers, greater efficiencies may be claimed where enhanced monitoring and testing are applied following Table 7. If the unit reboiler is used to control the VOC emissions from the dehydrator (e.g. to control the condenser vent and the flash tank if one is present) the unit must be designed to efficiently combust those vented VOCs at least 50% of the time the unit is operated. Page 58 of 67 Table 10 Best Available Control Technology Requirements Source or Facility Air Contaminant Minimum Acceptable Design, Control or Technique, Control Efficiencies, and Other Details during Production Operations Uncontrolled 37(WS\ VOC VOC, BTEX, H2S All non-combustion VOC emissions shall be captured and directed to an appropriate control device listed in the Control Device BACT Table with a minimum design control efficiency of at least 95%. Atmospheric Oil/Water separators VOC with partial pressure < 0.5 psia at maximum liquid temperature or 95 F whichever is greater. VOC, BTEX, H2S May vent to atmosphere through vent no larger than 3 inch diameter. If H2S can exceed 24 ppmv in the vapor space the separator vent shall be captured and directed to a control device listed in the Control Device BACT Table with a minimum design control efficiency of at least 95%. VOC with partial pressure psia at maximum liquid surface temperature or 95 F whichever is greater, VOC, BTEX, H2S The oil layer must have a floating cover over the entire liquid surface with a conservation vent to atmosphere or the vents must be captured and directed to a control device listed in the Control Device BACT Table with a minimum design control efficiency of at least 95%. If H2S can exceed 24 ppmv in the vapor space the separator vent shall be captured and directed to a control device listed in the Control Device BACT Table with a minimum design control efficiency of at least 95%. Oil water separators where the material entering the separator may flash. VOC, BTEX, H2S If the separator operates with more than 25,000 gallons (595 barrels) of liquid contained or is used as an oil storage tank, it shall be treated as a storage tank and meet those requirements. These separators must be treated as process separators with a gas stream and follow those requirements. Page 59 of 67 Table 10 Best Available Control Technology Requirements (continued) Source or Facility Air Contaminant Minimum Acceptable Design, Control or Technique, Control Efficiencies, and Other Details during Production Operations Fuel H2S Combustion Units including auxiliary fuel for combustion control devices Fuel for all combustion units at the site shall be sweet natural gas or liquid petroleum gas, fuel gas containing no more than ten grains of total sulfur per 100 dry standard cubic feet (dscf), or field gas. Boilers, Reboilers, HeaterTreaters, and Process Heaters NOx, CO, PM10/2.5, VOC, HCHO, SO2 If any unit has a designed maximum firing rate of < 40 MMBTU/hr and greater than 10 MMBtu/hr, it must be designed and operated for good combustion and meet 0.10 lb/MMBtu for NOX. For boilers and reboilers greater than or equal to 40 MMBtu/hr, emission shall not exceed 0.036 lb/MMBtu for NOx. For heaters and heater treaters greater than or equal to 40 MMBtu/hr but less than 100 MMBtu/hr, emissions shall not exceed 0.06 lb/MMBtu for NOx. Heaters and heater treaters greater than or equal to 100 MMBtu/hr shall not exceed 0.036 lb/MMBtu for NOx. GasFired Turbines All Tanks All Tanks For boilers, reboilers, process heaters, and heater treaters with heat inputs equal to or greater than 10 MMBtu/hr, the emission limit for CO is 0.074 lb CO/MMBtu NOx, CO, PM10/2.5, VOC, HCHO, SO2 Units shall be designed and operate with low NOx combustors and meet 25 ppmvd @ 15% O2 for NOX and 50 ppmvd @ 15% O2 for CO. Uncontrolled PTE of < 1.0 tpy VOC or < 0.1 tpy H2S Open-topped tanks or ponds containing VOCs or H2S are allowed Uncontrolled 37(RIWS\ 92&RU tpy H2S Open-topped tanks or ponds containing VOCs or H2S are not allowed. Tank hatches and valves, which emit to the atmosphere, shall remain closed except for sampling or planned maintenance activities. All pressure relief devices (PRD) shall be designed and operated to ensure that proper pressure in the vessel is maintained and shall stay closed except in upset or malfunction conditions. If the PRD does not automatically reset, it must be reset within 24 hours at a manned site and within one week if located at an unmanned site. Page 60 of 67 Table 10 Best Available Control Technology Requirements (continued) Source or Facility Air Contaminant Minimum Acceptable Design, Control or Technique, Control Efficiencies, and Other Details during Production Operations Process Separators, Crude oil, Condensate, Treatment chemicals, Produced water, Fuel, Slop/Sump Oil and any other storage tanks or vessels that contain a VOC or a film of VOC on the surface of water. VOC with partial pressure < 0.5 psia at maximum liquid surface temperature or 95 F whichever is greater, or with uncontrolled PTE of < 5 tpy VOC from working and breathing losses, including flash emissions VOC, BTEX, H2S All storage tanks with a storage capacity greater than 500 gallons must be submerged fill. Existing tanks and vessels (including temporary liquid storage tanks) which are not increasing emissions at an OGS shall also meet this requirement no later than 180 days after a registration renewal as of January 1, 2016 VOC with partial pressure psia at maximum liquid surface temperature or 95 F (whichever is greater), and with uncontrolled PTE of < 5 tpy from working and breathing losses, including flash emissions All storage tanks with a storage capacity greater than 500 gallons must be submerged fill. Un-insulated tank exterior surfaces exposed to the sun shall be of a color that minimizes the effects of solar heating (including, but not limited to, white or aluminum). To meet this requirement the solar absorptance should be 0.43 or less, as referenced in Table 7.1-6 in AP-42. Paint shall be maintained in good condition. If a new or modified tank cannot be painted white or other reflective color, then another control device may be used to control emissions. Exceptions to the color requirement include the following: (A) Up to 10% of the external surface area of the roof or walls of the tank or vessel may be painted with other colors to allow for identifying information or aesthetic purposes; and Page 61 of 67 Table 10 Best Available Control Technology Requirements (continued) Source or Facility Air Contaminant Minimum Acceptable Design, Control or Technique, Control Efficiencies, and Other Details during Production Operations (continued) (continued) VOC with partial pressure psia at maximum liquid surface temperature or 95 F (whichever is greater), and with uncontrolled PTE of < 5 tpy from working and breathing losses, including flash emissions (continued) (B) If a local, state or federal law or ordinance or private contract which predates this standard permit's effective date establishes in writing tank and vessel colors other than white. If applicable, a copy of this documentation must be provided to the commission upon registration. (C) Tanks and vessels purposefully darkened to create the process reaction and help condense liquids from being entrained in the vapor. Existing tanks and vessels (including temporary liquid storage tanks) which are not increasing emissions at an OGS using shall also meet this requirement no later than 180 days after a registration renewal as of January 1, 2016. VOC, BTEX, H2S Page 62 of 67 Table 10 Best Available Control Technology Requirements (continued) Source or Facility Air Contaminant Minimum Acceptable Design, Control or Technique, Control Efficiencies, and Other Details during Production Operations (continued) VOC with uncontrolled 37(RIWS\ Vents shall be captured and directed to an appropriate control device as listed in standard permit (e) BMP and BACT. Un-insulated tank exterior surfaces exposed to the sun shall be of a color that minimizes the effects of solar heating (including, but not limited to, white or aluminum). To meet this requirement the solar absorptance should be 0.43 or less, as referenced in Table 7.1-6 in AP-42. Paint shall be maintained in good condition. Exceptions to the color requirement include the following: (A) Up to 10% of the external surface area of the roof or walls of the tank or vessel may be painted with other colors to allow for identifying information or aesthetic purposes; and (B) If a local, state or federal law or ordinance or private contract which predates this standard permit's effective date establishes in writing tank and vessel colors other than white. If applicable, a copy of this documentation must be provided to the commission upon registration. (C) Tanks and vessels purposefully darkened to create the process reaction and help condense liquids from being entrained in the vapor. Existing tanks and vessels (including temporary liquid storage tanks) which are not increasing emissions at an OGS using shall also meet this requirement no later than 180 days after a registration renewal as of January 1, 2016. Truck Loading VOC with partial pressure < 0.5 psia at maximum liquid surface temperature or 95 F whichever is greater, or with uncontrolled PTE of < 5 tpy VOC VOC, BTEX, H2S Loading is recommended to be performed with submerged filling, or vapor balancing back to the tank and any subsequent recovery or control device. Page 63 of 67 Table 10 Best Available Control Technology Requirements (continued) Source or Facility Air Contaminant Minimum Acceptable Design, Control or Technique, Control Efficiencies, and Other Details during Production Operations VOC with partial pressure psia at maximum liquid surface temperature or 95 F whichever is greater Splash loading and uncontrolled vacuum truck loading is not allowed. Loading shall be performed with a control effectiveness of at least 42% as compared to splash loading. Loading may occur by submerged filling or equivalent prevention or recovery technique as listed in Table 10. VOC, BTEX, H2S VOC with uncontrolled 37(RIWS\ VOC VOC, BTEX, H2S Loading vapors shall be captured and directed to an appropriate control device listed in the Control Device BACT Table with a minimum design control efficiency of at least 98%, routed to a vapor recovery unit (VRU) with a control effectiveness of at least 95%, or vapor balanced back to the delivering storage tank equipped with a VRU, or connected to a control device listed in the Control Device BACT Table with a minimum design control efficiency of at least 95%. Controlled Loading Where loading control is required, the collection or capture system must be connected to the tank truck so all displaced vapors are directed to the control device and the control device is operational before loading is commenced. When properly connected the capture efficiency will be assumed to be 70% efficient at capturing the displaced truck vapors. The capture efficiency may be assumed to be 98.7 percent efficient when the tanker truck has certification that the tank has passed vapor-tightness testing within the last 12 months using the methods described in 40 CFR 60, Subpart XX. The capture efficiency may be assumed to be 99.2 percent efficient when the tanker truck has certification that the tank has passed vapor-tightness testing within the last 12 months using the methods described in 40 CFR 63, Subpart R. Loading shall be discontinued when liquid or gas leaks from the loading or collection system are observed. Page 64 of 67 Table 10 Best Available Control Technology Requirements (continued) Source or Facility Air Contaminant Minimum Acceptable Design, Control or Technique, Control Efficiencies, and Other Details during Production Operations Cooling Tower VOC, BTEX, Heat Exchange PM10/2.5 System Heat exchange systems must be non-contact design (i.e. designed and operated to avoid direct contact with gaseous or liquid process streams containing VOC, H2S, halogens or halogen compounds, cyanide compounds, inorganic acids, or acid gases). Systems with heat exchangers that cool a fluid with VOC shall meet the following: The cooling water must be at a higher pressure than the process fluid in the heat exchangers or the cooling tower water must be monitored monthly for VOC emissions using TCEQ Sampling Procedures Manual, Appendix P dated January 2003 or a later edition. Equipment shall be maintained so as to minimize VOC emissions into the cooling water. Cooling water VOC concentrations greater than 0.08 ppmw indicate faulty equipment. If the repair of a heat exchanger would require a unit shutdown that would create more emissions than the repair would eliminate, the repair may be delayed until the next planned shutdown or 180 days if no shutdowns are scheduled. Cooling towers shall be designed and operated with properly functioning drift eliminators. New cooling towers shall be designed with drift HOLPLQDWRUVGHVLJQHGWRPHHWGULIW Page 65 of 67 List of Acronyms C F g/m3 acfm ADMT AMINECalc AP-42 APD API APWL AREACIRC AERMOD AWP Degrees Celsius Degrees Fahrenheit Micrograms per cubic meter Actual cubic feet per minute Air Dispersion Modeling Team Amine Unit Air Emissions Model Ver 1.0 Air Pollutant Emission Factors, 5th ed Air Permits Division American Petroleum Institute Air Pollutant Watch List Co-located circular area source from the EPA Modeling System Alternative Work Practices BACT bbl bbl/day BMP BTEX Btu/scf Best Available Control Technology Barrel Barrels per day Best Management Practices (includes equipment manufacturer's guidelines and specifications) Benzene, Toluene, Ethylbenzene, Xylene British thermal units per standard cubic feet CEMS cf/day cfm CFR CO2 COS CPR CS2 CT Continuous Emissions Monitoring System Cubic feet per day Cubic feet per minute Code of Federal Regulations Carbon dioxide Carbonyl sulfide Considerable personnel and resources Carbon disulfide Cooling towers DEA DGA DIPA DOT DRE dscf DV Diethanolamine Diglycolamine Di-isopropylamine Department of Transportation Destruction rate efficiency Dry standard cubic feet Designated value E Maximum acceptable emission rate (lb/hr) EF Emission factor EFR Emax EPA EPN ESL FR ft ft/sec gal/wk gal/yr GLCmax GOP H2S HAP HB HCl hp hr HRVOC HYSIM HYSIS ICE IFR IR ISCST3 LACT lb lb/hr lb/MMBtu lbs/day LDAR LL LPG LT/D m/sec MACT MDEA MEA External floating roof tank Maximum acceptable emission rate (lb/hr) Environmental Protection Agency Emission point number Effects screening level Federal Register Feet Feet per second Gallons per week Gallons per year Max predicted ground-level concentration General Operating Permit Hydrogen sulfide Hazardous air pollutant House Bill Hydrogen chloride Horsepower Hour Highly reactive volatile organic compounds Hydrologic Simulation Model computer program Process simulator computer program Internal combustion engine Internal floating roof tank Infrared Industrial Source Complex Shortterm Model V02035 Lease automatic custody transfer unit Pound Pounds per hour Pounds per million British thermal units Pounds per day Leak detection and repair Loading losses Liquid petroleum gas Long ton per day Meters per second Maximum Available Control Technology Methyl-diethanolamine Monoethanol amine Page 66 of 67 MERA MMBtu MMBtu/hr MMCFD MSS Modeling and Effects Review Applicability Million British thermal units Million British thermal units per hour Million cubic feet per day Maintenance, start-up, and shutdown NAAQS NESHAP NGL NNSR NO2 NOx NSPS NSR National Ambient Air Quality Standards National Emission Standards for Hazardous Air Pollutants Natural gas liquids Nonattainment New Source Review Nitrogen dioxide Oxides of nitrogen New Source Performance Standards New Source Review O2 OGS Oxygen (molecular form) Oil and gas site PBR PM10 POC ppm Ppmvd PROSIM PSD psi psia psig Permit by Rule Particulate matter less than or equal to 10 microns Products of combustion Parts per million Parts per million by volume, dry DOS based process simulator computer program Prevention of Significant Deterioration Pounds per square inch Pounds per square inch, absolute Pounds per square inch, gage RICE RVP Reciprocating internal combustion engine Reid vapor pressure scfh Standard cubic feet per hour scfm Standard cubic feet per minute scmd Standard cubic feet per day SCREEN3 Air dispersion modeling computer program for windows, Version 5.0. BEE-line Software c1998-2002 SE Standard Exemption SIC Standard Industrial Classification System SO2 Sulfur dioxide SOP Site Operating Permit Standard permit Standard Permit SRU Sulfur recovery unit T&S TAC TCAA TCEQ TEA THSC tpy V-B VOC VRU WINSIM Transfer and storage Texas Administrative Code Texas Clean Air Act Texas Commission on Environmental Quality Triethanolamine Texas Health and Safety Code Tons per year Vasquez-Beggs correlation equation Volatile organic compounds Vapor recovery unit or system Windows process simulator computer program Page 67 of 67 Newberry Gas Plant /Enterprise Midland Basin Midstream LLC Inspection Date 12/19/2024 Appendix D Title 5 Permit December 20, 2023 FEDERAL OPERATING PERMIT A FEDERAL OPERATING PERMIT IS HEREBY ISSUED TO Enterprise Navitas Midstream Midland Basin LLC AUTHORIZING THE OPERATION OF Newberry Gas Plant Natural Gas Liquid Extraction LOCATED AT Midland County, Texas Latitude 31 51 10 Longitude 101 46 40 Regulated Entity Number: RN109272526 This permit is issued in accordance with and subject to the Texas Clean Air Act (TCAA), Chapter 382 of the Texas Health and Safety Code and Title 30 Texas Administrative Code Chapter 122 (30 TAC Chapter 122), Federal Operating Permits. Under 30 TAC Chapter 122, this permit constitutes the permit holder's authority to operate the site and emission units listed in this permit. Operations of the site and emission units listed in this permit are subject to all additional rules or amended rules and orders of the Commission pursuant to the TCAA. This permit does not relieve the permit holder from the responsibility of obtaining New Source Review authorization for new, modified, or existing facilities in accordance with 30 TAC Chapter 116, Control of Air Pollution by Permits for New Construction or Modification. The site and emission units authorized by this permit shall be operated in accordance with 30 TAC Chapter 122, the general terms and conditions, special terms and conditions, and attachments contained herein. This permit shall expire five years from the date of issuance. The renewal requirements specified in 30 TAC 122.241 must be satisfied in order to renew the authorization to operate the site and emission units. Permit No: O3959 Issuance Date: December 20, 2023 For the Commission Renewal- Effective Page i Table of Contents Section Page General Terms and Conditions.................................................................................................................... 1 Special Terms and Conditions:.................................................................................................................... 1 Emission Limitations and Standards, Monitoring and Testing, and Recordkeeping and Reporting.................................................................................................................... 1 Additional Monitoring Requirements............................................................................................... 5 New Source Review Authorization Requirements.......................................................................... 6 Compliance Requirements.............................................................................................................. 6 Permit Location............................................................................................................................... 7 Permit Shield (30 TAC 122.148).................................................................................................. 7 Attachments................................................................................................................................................. 8 Applicable Requirements Summary................................................................................................ 9 Additional Monitoring Requirements............................................................................................. 23 Permit Shield................................................................................................................................ 26 New Source Review Authorization References............................................................................ 28 Appendix A................................................................................................................................................ 32 Acronym List................................................................................................................................. 33 Renewal- Effective Page ii General Terms and Conditions The permit holder shall comply with all terms and conditions contained in 30 TAC 122.143 (General Terms and Conditions), 30 TAC 122.144 (Recordkeeping Terms and Conditions), 30 TAC 122.145 (Reporting Terms and Conditions), and 30 TAC 122.146 (Compliance Certification Terms and Conditions). In accordance with 30 TAC 122.144(1), records of required monitoring data and support information required by this permit, or any applicable requirement codified in this permit, are required to be maintained for a period of five years from the date of the monitoring report, sample, or application unless a longer data retention period is specified in an applicable requirement. The five year record retention period supersedes any less stringent retention requirement that may be specified in a condition of a permit identified in the New Source Review Authorization attachment. If the permit holder chooses to demonstrate that this permit is no longer required, a written request to void this permit shall be submitted to the Texas Commission on Environmental Quality (TCEQ) by the Responsible Official in accordance with 30 TAC 122.161(e). The permit holder shall comply with the permit's requirements, including compliance certification and deviation reporting, until notified by the TCEQ that this permit is voided. The permit holder shall comply with 30 TAC Chapter 116 by obtaining a New Source Review authorization prior to new construction or modification of emission units located in the area covered by this permit. All reports required by this permit must include in the submittal a cover letter which identifies the following information: company name, TCEQ regulated entity number, air account number (if assigned), site name, area name (if applicable), and Air Permits Division permit number(s). Special Terms and Conditions: Emission Limitations and Standards, Monitoring and Testing, and Recordkeeping and Reporting 1. Permit holder shall comply with the following requirements: A. Emission units (including groups and processes) in the Applicable Requirements Summary attachment shall meet the limitations, standards, equipment specifications, monitoring, recordkeeping, reporting, testing, and other requirements listed in the Applicable Requirements Summary attachment to assure compliance with the permit. B. The textual description in the column titled "Textual Description" in the Applicable Requirements Summary attachment is not enforceable and is not deemed as a substitute for the actual regulatory language. The Textual Description is provided for information purposes only. C. A citation listed on the Applicable Requirements Summary attachment, which has a notation [G] listed before it, shall include the referenced section and subsection for all commission rules, or paragraphs for all federal and state regulations and all subordinate paragraphs, subparagraphs and clauses, subclauses, and items contained within the referenced citation as applicable requirements. D. When a grouped citation, notated with a [G] in the Applicable Requirements Summary, contains multiple compliance options, the permit holder must keep records of when each compliance option was used. E. Emission units subject to 40 CFR Part 63, Subparts HH and ZZZZ as identified in the attached Applicable Requirements Summary table are subject to 30 TAC Chapter 113, Renewal- Effective Page i Subchapter C, 113.390 and 113.1090, respectively, which incorporate the 40 CFR Part 63 Subparts by reference. 2. The permit holder shall comply with the following sections of 30 TAC Chapter 101 (General Air Quality Rules): A. Title 30 TAC 101.1 (relating to Definitions), insofar as the terms defined in this section are used to define the terms used in other applicable requirements B. Title 30 TAC 101.3 (relating to Circumvention) C. Title 30 TAC 101.8 (relating to Sampling), if such action has been requested by the TCEQ D. Title 30 TAC 101.9 (relating to Sampling Ports), if such action has been requested by the TCEQ E. Title 30 TAC 101.10 (relating to Emissions Inventory Requirements) F. Title 30 TAC 101.201 (relating to Emission Event Reporting and Recordkeeping Requirements) G. Title 30 TAC 101.211 (relating to Scheduled Maintenance, Start-up, and Shutdown Reporting and Recordkeeping Requirements) H. Title 30 TAC 101.221 (relating to Operational Requirements) I. Title 30 TAC 101.222 (relating to Demonstrations) J. Title 30 TAC 101.223 (relating to Actions to Reduce Excessive Emissions) 3. Permit holder shall comply with the following requirements of 30 TAC Chapter 111: A. Visible emissions from stationary vents with a flow rate of less than 100,000 actual cubic feet per minute and constructed after January 31, 1972 that are not listed in the Applicable Requirements Summary attachment for 30 TAC Chapter 111, Subchapter A, Division 1, shall not exceed 20% opacity averaged over a six-minute period. The permit holder shall comply with the following requirements for stationary vents at the site subject to this standard: (i) Title 30 TAC 111.111(a)(1)(B) (relating to Requirements for Specified Sources) (ii) Title 30 TAC 111.111(a)(1)(E) (iii) Title 30 TAC 111.111(a)(1)(F)(i), (ii), (iii), or (iv) (iv) For emission units with vent emissions subject to 30 TAC 111.111(a)(1)(B), complying with 30 TAC 111.111(a)(1)(F)(ii), (iii), or (iv), and capable of producing visible emissions from, but not limited to, particulate matter, acid gases and NOx, the permit holder shall also comply with the following periodic monitoring requirements for the purpose of annual compliance certification under 30 TAC 122.146. These periodic monitoring requirements do not apply to vents that are not capable of producing visible emissions such as vents that emit only colorless VOCs; vents from non-fuming liquids; vents that provide passive ventilation, such as plumbing vents; or vent emissions from any other source that Renewal- Effective Page ii does not obstruct the transmission of light. Vents, as specified in the "Applicable Requirements Summary" attachment, that are subject to the emission limitation of 30 TAC 111.111(a)(1)(B) are not subject to the following periodic monitoring requirements: (1) An observation of stationary vents from emission units in operation shall be conducted at least once during each calendar quarter unless the emission unit is not operating for the entire quarter. (2) For stationary vents from a combustion source, if an alternative to the normally fired fuel is fired for a period greater than or equal to 24 consecutive hours, the permit holder shall conduct an observation of the stationary vent for each such period to determine if visible emissions are present. If such period is greater than 3 months, observations shall be conducted once during each quarter. Supplementing the normally fired fuel with natural gas or fuel gas to increase the net heating value to the minimum required value does not constitute creation of an alternative fuel. (3) Records of all observations shall be maintained. (4) Visible emissions observations of emission units operated during daylight hours shall be conducted no earlier than one hour after sunrise and no later than one hour before sunset. Visible emissions observations of emission units operated only at night must be made with additional lighting and the temporary installation of contrasting backgrounds. Visible emissions observations shall be made during times when the activities described in 30 TAC 111.111(a)(1)(E) are not taking place. Visible emissions shall be determined with each stationary vent in clear view of the observer. The observer shall be at least 15 feet, but not more than 0.25 mile, away from each stationary vent during the observation. For outdoor locations, the observer shall select a position where the sun is not directly in the observer's eyes. When condensed water vapor is present within the plume, as it emerges from the emissions outlet, observations must be made beyond the point in the plume at which condensed water vapor is no longer visible. When water vapor within the plume condenses and becomes visible at a distance from the emissions outlet, the observation shall be evaluated at the outlet prior to condensation of water vapor. A certified opacity reader is not required for visible emissions observations. (5) Compliance Certification: (a) If visible emissions are not present during the observation, the RO may certify that the source is in compliance with the applicable opacity requirement in 30 TAC 111.111(a)(1) and (a)(1)(B). (b) However, if visible emissions are present during the observation, the permit holder shall either list this occurrence as a deviation on the next deviation report as required under 30 TAC 122.145(2) or conduct the appropriate opacity test specified in 30 TAC 111.111(a)(1)(F) as soon as practicable, but no later than 24 hours after observing visible emissions to determine if the source is in compliance with the opacity requirements. If an opacity test is performed and the source is Renewal- Effective Page iii determined to be in compliance, the RO may certify that the source is in compliance with the applicable opacity requirement. However, if an opacity test is performed and the source is determined to be out of compliance, the permit holder shall list this occurrence as a deviation on the next deviation report as required under 30 TAC 122.145(2). The opacity test must be performed by a certified opacity reader. (c) Some vents may be subject to multiple visible emission or monitoring requirements. All credible data must be considered when certifying compliance with this requirement even if the observation or monitoring was performed to demonstrate compliance with a different requirement. B. Emission limits on nonagricultural processes, except for the steam generators specified in 30 TAC 111.153, shall comply with the following requirements: (i) Emissions of PM from any source may not exceed the allowable rates as required in 30 TAC 111.151(a) (relating to Allowable Emissions Limits) (ii) Sources with an effective stack height (he) less than the standard effective stack height (He), must reduce the allowable emission level by multiplying it by [he/He]2 as required in 30 TAC 111.151(b) (iii) Effective stack height shall be calculated by the equation specified in 30 TAC 111.151(c) C. Outdoor burning, as stated in 30 TAC 111.201, shall not be authorized unless the following requirements are satisfied: (i) Title 30 TAC 111.205 (relating to Exception for Fire Training) (ii) Title 30 TAC 111.207 (relating to Exception for Recreation, Ceremony, Cooking, and Warmth) (iii) Title 30 TAC 111.219 (relating to General Requirements for Allowable Outdoor Burning) (iv) Title 30 TAC 111.221 (relating to Responsibility for Consequences of Outdoor Burning) 4. The permit holder shall comply with the following requirements for units subject to any subpart of 40 CFR Part 60, unless otherwise stated in the applicable subpart: A. Title 40 CFR 60.7 (relating to Notification and Recordkeeping) B. Title 40 CFR 60.8 (relating to Performance Tests) C. Title 40 CFR 60.11 (relating to Compliance with Standards and Maintenance Requirements) D. Title 40 CFR 60.12 (relating to Circumvention) E. Title 40 CFR 60.13 (relating to Monitoring Requirements) Renewal- Effective Page iv F. Title 40 CFR 60.14 (relating to Modification) G. Title 40 CFR 60.15 (relating to Reconstruction) H. Title 40 CFR 60.19 (relating to General Notification and Reporting Requirements) 5. The permit holder shall comply with the requirements of 30 TAC Chapter 113, Subchapter C, 113.100 for units subject to any subpart of 40 CFR Part 63, unless otherwise stated in the applicable subpart. 6. For oil and natural gas production facilities as specified in 40 CFR Part 63, Subpart HH, the permit holder shall comply with the following requirements (Title 30 TAC Chapter 113, Subchapter C, 113.390 incorporated by reference): A. Title 40 CFR 63.760(c) (relating to Applicability and Designation of Affected Source) 7. For each gasoline dispensing facility, with a throughput of less than 10,000 gallons per month as specified in 40 CFR Part 63, Subpart CCCCCC, the permit holder shall comply with the following requirements (Title 30 TAC, Subchapter C, 113.1380 incorporated by reference): A. Title 40 CFR 63.11111(e), for records of monthly throughput B. Title 40 CFR 63.11111(i), for compliance due to increase of throughput C. Title 40 CFR 63.11111(j), for dispensing from fixed tank into portable tank for on-site delivery D. Title 40 CFR 63.11113(c), for compliance due to increase of throughput E. Title 40 CFR 63.11115(a), for operation of the source F. Title 40 CFR 63.11116(a) and (a)(1) - (4), for work practices G. Title 40 CFR 63.11116(b), for records availability H. Title 40 CFR 63.11116(d), for portable gasoline containers Additional Monitoring Requirements 8. The permit holder shall comply with the periodic monitoring requirements as specified in the attached "Periodic Monitoring Summary" upon issuance of the permit. Except for, as applicable, monitoring malfunctions, associated repairs, and required quality assurance or control activities (including, as applicable, calibration checks and required zero and span adjustments), the permit holder shall conduct all monitoring in continuous operation (or shall collect data at all required intervals) at all times that the pollutant-specific emissions unit is operating. The permit holder may elect to collect monitoring data on a more frequent basis and average the data, consistent with the averaging time or minimum frequency specified in the "Periodic Monitoring Summary," for purposes of determining whether a deviation has occurred. However, the additional data points must be collected on a regular basis. In no event shall data be collected and used in particular instances to avoid reporting deviations. Deviations shall be reported according to 30 TAC 122.145 (Reporting Terms and Conditions). Renewal- Effective Page v New Source Review Authorization Requirements 9. Permit holder shall comply with the requirements of New Source Review authorizations issued or claimed by the permit holder for the permitted area, including permits, permits by rule, standard permits, flexible permits, special permits, permits for existing facilities including Voluntary Emissions Reduction Permits and Electric Generating Facility Permits issued under 30 TAC Chapter 116, Subchapter I, or special exemptions referenced in the New Source Review Authorization References attachment. These requirements: A. Are incorporated by reference into this permit as applicable requirements B. Shall be located with this operating permit C. Are not eligible for a permit shield 10. The permit holder shall comply with the general requirements of 30 TAC Chapter 106, Subchapter A or the general requirements, if any, in effect at the time of the claim of any PBR. 11. The permit holder shall maintain records to demonstrate compliance with any emission limitation or standard that is specified in a permit by rule (PBR) or Standard Permit listed in the New Source Review Authorizations attachment. The records shall yield reliable data from the relevant time period that are representative of the emission unit's compliance with the PBR or Standard Permit. These records may include, but are not limited to, production capacity and throughput, hours of operation, safety data sheets (SDS), chemical composition of raw materials, speciation of air contaminant data, engineering calculations, maintenance records, fugitive data, performance tests, capture/control device efficiencies, direct pollutant monitoring (CEMS, COMS, or PEMS), or control device parametric monitoring. These records shall be made readily accessible and available as required by 30 TAC 122.144. Any monitoring or recordkeeping data indicating noncompliance with the PBR or Standard Permit shall be considered and reported as a deviation according to 30 TAC 122.145 (Reporting Terms and Conditions). 12. The permit holder shall comply with the following requirements for Air Quality Standard Permits: A. Registration requirements listed in 30 TAC 116.611, unless otherwise provided for in an Air Quality Standard Permit B. General Conditions listed in 30 TAC 116.615, unless otherwise provided for in an Air Quality Standard Permit C. Requirements of the Air Quality Standard Permit for Oil and Gas Handling and Production Facilities Compliance Requirements 13. The permit holder shall certify compliance in accordance with 30 TAC 122.146. The permit holder shall comply with 30 TAC 122.146 using at a minimum, but not limited to, the continuous or intermittent compliance method data from monitoring, recordkeeping, reporting, or testing required by the permit and any other credible evidence or information. The certification period may not exceed 12 months and the certification must be submitted within 30 days after the end of the period being certified. 14. Use of Discrete Emission Credits to comply with the applicable requirements: A. Unless otherwise prohibited, the permit holder may use discrete emission credits to comply with the following applicable requirements listed elsewhere in this permit: Renewal- Effective Page vi (i) Title 30 TAC Chapter 115 (ii) Title 30 TAC Chapter 117 (iii) If applicable, offsets for Title 30 TAC Chapter 116 (iv) Temporarily exceed state NSR permit allowables B. The permit holder shall comply with the following requirements in order to use the credit to comply with the applicable requirements: (i) The permit holder must notify the TCEQ according to 30 TAC 101.376(d) (ii) The discrete emission credits to be used must meet all the geographic, timeliness, applicable pollutant type, and availability requirements listed in 30 TAC Chapter 101, Subchapter H, Division 4 (iii) The executive director has approved the use of the discrete emission credits according to 30 TAC 101.376(d)(1)(A) (iv) The permit holder keeps records of the use of credits towards compliance with the applicable requirements in accordance with 30 TAC 101.372(h) and 30 TAC Chapter 122 (v) Title 30 TAC 101.375 (relating to Emission Reductions Achieved Outside the United States) Permit Location 15. The permit holder shall maintain a copy of this permit and records related to requirements listed in this permit on site. Permit Shield (30 TAC 122.148) 16. A permit shield is granted for the emission units, groups, or processes specified in the attached "Permit Shield." Compliance with the conditions of the permit shall be deemed compliance with the specified potentially applicable requirements or specified potentially applicable state-only requirements listed in the attachment "Permit Shield." Permit shield provisions shall not be modified by the executive director until notification is provided to the permit holder. No later than 90 days after notification of a change in a determination made by the executive director, the permit holder shall apply for the appropriate permit revision to reflect the new determination. Provisional terms are not eligible for this permit shield. Any term or condition, under a permit shield, shall not be protected by the permit shield if it is replaced by a provisional term or condition or the basis of the term and condition changes. Renewal- Effective Page vii Attachments Applicable Requirements Summary Additional Monitoring Requirements Permit Shield New Source Review Authorization References Renewal- Effective Page viii Applicable Requirements Summary Unit Summary.......................................................................................................................................... 10 Applicable Requirements Summary ...................................................................................................... 12 Note: A "none" entry may be noted for some emission sources in this permit's "Applicable Requirements Summary" under the heading of "Monitoring and Testing Requirements" and/or "Recordkeeping Requirements" and/or "Reporting Requirements." Such a notation indicates that there are no requirements for the indicated emission source as identified under the respective column heading(s) for the stated portion of the regulation when the emission source is operating under the conditions of the specified SOP Index Number. However, other relevant requirements pursuant to 30 TAC Chapter 122 including Recordkeeping Terms and Conditions (30 TAC 122.144), Reporting Terms and Conditions (30 TAC 122.145), and Compliance Certification Terms and Conditions (30 TAC 122.146) continue to apply. Renewal- Effective Page ix Unit Summary Unit/Group/ Process ID No. AMINE AMINE-2 COMB-1 Unit Type GAS SWEETENING/SULFUR RECOVERY UNITS GAS SWEETENING/SULFUR RECOVERY UNITS FLARES COMB-1 DEHY1 FLARE-1 FLARES GLYCOL DEHYDRATION FLARES FLARE-1 FLARE-2 FLARES FLARES FLARE-2 FUG-2 GRP-ENG1 FLARES FUGITIVE EMISSION UNITS SRIC ENGINES GRP-ENG1 SRIC ENGINES Group/Inclusive Units N/A SOP Index No. 60OOOOa-5365 Regulation 40 CFR Part 60, Subpart OOOOa Requirement Driver No changing attributes. N/A 60OOOOa-5365 40 CFR Part 60, Subpart No changing attributes. OOOOa N/A R1111 N/A 60A N/A 63HH-764 N/A R1111 N/A 60A N/A R1111 N/A 60A N/A 60OOOOa-5400 C-1680, C-1690, C1710, C-1720, C1730, C-1740, C1750, C-1760, C1770, C-1780, C181, C-182, C-183 C-1680, C-1690, C1710, C-1720, C1730, C-1740, C1750, C-1760, C1770, C-1780, C- 60JJJJ-4230 63ZZZZ-6590 30 TAC Chapter 111, Visible No changing attributes. Emissions 40 CFR Part 60, Subpart A No changing attributes. 40 CFR Part 63, Subpart HH No changing attributes. 30 TAC Chapter 111, Visible No changing attributes. Emissions 40 CFR Part 60, Subpart A No changing attributes. 30 TAC Chapter 111, Visible No changing attributes. Emissions 40 CFR Part 60, Subpart A No changing attributes. 40 CFR Part 60, Subpart OOOOa No changing attributes. 40 CFR Part 60, Subpart JJJJ No changing attributes. 40 CFR Part 63, Subpart ZZZZ No changing attributes. Renewal- Effective Page x GRP-ENG2 GRP-ENG2 GRP-TANKS1 GRP-TANKS2 SRIC ENGINES SRIC ENGINES STORAGE TANKS/VESSELS STORAGE TANKS/VESSELS 181, C-182, C-183 C-171N, C-172N, C- 60JJJJ-4230 173N, C-174N C-171N, C-172N, C- 63ZZZZ-6590 173N, C-174N TK-1, TK-2 60Kb-110b TK-3, TK-4 60Kb-110b 40 CFR Part 60, Subpart JJJJ 40 CFR Part 63, Subpart ZZZZ 40 CFR Part 60, Subpart Kb No changing attributes. No changing attributes. No changing attributes. 40 CFR Part 60, Subpart Kb No changing attributes. Renewal- Effective Page xi Applicable Requirements Summary Unit Group Process ID No. Unit Group Process Type SOP Index No. Pollutant State Rule or Federal Regulation Name AMINE EU 60OOOOa- SO2 5365 40 CFR Part 60, Subpart OOOOa AMINE-2 EU 60OOOOa- SO2 5365 40 CFR Part 60, Subpart OOOOa COMB-1 CD R1111 Opacity 30 TAC Chapter 111, Visible Emissions Emission Limitation, Standard or Equipment Specification Citation 60.5365a(g)(3) 60.5370a(b) 60.5365a(g)(3) 60.5370a(b) 111.111(a)(4)(A) Textual Description (See Special Term and Condition 1.B.) Monitoring And Testing Requirements Owners or operators of facilities that have a design capacity less than 2 long tons per day (LT/D) of hydrogen sulfide (H2S) in the acid gas (expressed as sulfur) are required to comply with recordkeeping and reporting requirements specified in 60.5423a(c), but are not required to comply with 60.5405a through 60.5407a and 60.5410a(g) and 60.5415a(g). None Owners or operators of facilities that have a design capacity less than 2 long tons per day (LT/D) of hydrogen sulfide (H2S) in the acid gas (expressed as sulfur) are required to comply with recordkeeping and reporting requirements specified in 60.5423a(c), but are not required to comply with 60.5405a through 60.5407a and 60.5410a(g) and 60.5415a(g). None Visible emissions from a process gas flare shall not be permitted for more than five minutes in any two-hour period. Non-excessive upset events are subject to the provisions under 101.222(b). 111.111(a)(4)(A)(i) 111.111(a)(4)(A)(ii) Recordkeeping Requirements (30 TAC 122.144) 60.5423a(c) 60.5423a(c) 111.111(a)(4)(A)(ii) Reporting Requirements (30 TAC 122.145) 60.5420a(a) 60.5420a(a)(1) 60.5420a(b) [G] 60.5420a(b)(1) 60.5420a(b)(11) [G] 60.5420a(b)(13) [G] 60.5420a(b)(14) 60.5420a(a) 60.5420a(a)(1) 60.5420a(b) [G] 60.5420a(b)(1) 60.5420a(b)(11) [G] 60.5420a(b)(13) [G] 60.5420a(b)(14) None Renewal- Effective Page xii COMB-1 CD DEHY1 EU FLARE-1 CD FLARE-1 CD FLARE-2 CD FLARE-2 CD 60A Opacity 63HH-764 112(B) HAPS R1111 Opacity 60A Opacity R1111 Opacity 60A Opacity 40 CFR Part 60, Subpart A 40 CFR Part 63, Subpart HH 30 TAC Chapter 111, Visible Emissions 40 CFR Part 60, Subpart A 30 TAC Chapter 111, Visible Emissions 40 CFR Part 60, Subpart A 60.18(b) 60.18(c)(1) 60.18(c)(2) 60.18(c)(3)(ii) 60.18(c)(4)(i) 60.18(c)(6) 60.18(e) 63.764(e)(1)(ii) 63.764(a) 63.764(e)(1) 63.764(j) 63.775(c)(8) 111.111(a)(4)(A) 60.18(b) 60.18(c)(1) 60.18(c)(2) 60.18(c)(3)(ii) 60.18(c)(4)(i) 60.18(c)(6) 60.18(e) 111.111(a)(4)(A) 60.18(b) 60.18(c)(1) 60.18(c)(2) 60.18(c)(3)(ii) Flares shall comply with paragraphs (c)-(f) of 60.18. 60.18(d) 60.18(f)(1) 60.18(f)(2) 60.18(f)(3) 60.18(f)(4) The owner or operator of an area source is exempt from the requirements of 63.764(d) when the actual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere < 0.90 megagram/yr, as determined by the procedures specified in 63.772(b)(2) of this subpart. [G] 63.772(b)(2) Visible emissions from a process gas flare shall not be permitted for more than five minutes in any two-hour period. Non-excessive upset events are subject to the provisions under 101.222(b). 111.111(a)(4)(A)(i) 111.111(a)(4)(A)(ii) Flares shall comply with paragraphs (c)-(f) of 60.18. 60.18(d) 60.18(f)(1) 60.18(f)(2) 60.18(f)(3) 60.18(f)(4) Visible emissions from a process gas flare shall not be permitted for more than five minutes in any two-hour period. Non-excessive upset events are subject to the provisions under 101.222(b). Flares shall comply with paragraphs (c)-(f) of 60.18. 111.111(a)(4)(A)(i) 111.111(a)(4)(A)(ii) 60.18(d) 60.18(f)(1) 60.18(f)(2) 60.18(f)(3) None 63.774(d)(1) 63.774(d)(1)(ii) 111.111(a)(4)(A)(ii) None 111.111(a)(4)(A)(ii) None None None None None None None Renewal- Effective Page xiii FUG-2 EU 60OOOOa- VOC 5400 40 CFR Part 60, Subpart OOOOa 60.18(c)(4)(i) 60.18(c)(6) 60.18(e) 60.18(f)(4) 60.5400a(a) 60.482-1a(a) 60.482-1a(b) 60.482-2a(a)(1) 60.482-2a(a)(2) 60.482-2a(b)(1) 60.482-2a(b)(1)(i) 60.4822a(b)(1)(ii) 60.482-2a(b)(2) 60.4822a(b)(2)(ii) 60.482-2a(c)(1) [G] 60.4822a(c)(2) 60.482-2a(d) [G] 60.4822a(d)(1) 60.482-2a(d)(2) 60.482-2a(d)(3) [G] 60.4822a(d)(6) [G] 60.482-2a(e) 60.482-2a(f) [G] 60.482-2a(g) 60.482-2a(h) 60.482-9a(a) 60.482-9a(b) [G] 60.482-9a(d) 60.482-9a(f) 60.485a(b) 60.485a(c) 60.485a(c)(1) 60.485a(f) 60.486a(a)(1) 60.486a(a)(2) 60.486a(k) 60.5370a(a) 60.5370a(b) 60.5400a(a) 60.5400a(d) 60.5400a(e) 60.5400a(f) 60.5401a(d) 60.5410a 60.5410a(f) 60.5415a(f) Except as provided in 60.5401 pumps in light liquid service must comply with the requirements of 60.482-2a. The instrument reading that defines a leak in a pump in light liquid service is 5,000 parts per million (ppm) or greater for pumps handling polymerizing monomers or 2,000 ppm or greater for all other pumps, as specified in paragraphs 60.4822a(b)(1)(i) and 60.4822a(b)(1)(ii). 60.482-1a(f)(1) 60.482-1a(f)(2) [G] 60.482-1a(f)(3) 60.482-2a(b)(2)(i) [G] 60.4822a(d)(4) [G] 60.4822a(d)(5) 60.482-9a(a) 60.485a(a) [G] 60.485a(b)(1) 60.485a(b)(2) 60.485a(c)(2) 60.485a(d) 60.485a(d)(2) 60.485a(d)(3) [G] 60.485a(e) [G] 60.5401a(f) 60.5401a(g) 60.485a(b)(2) [G] 60.486a(a)(3) [G] 60.486a(b) [G] 60.486a(c) 60.486a(e) 60.486a(e)(1) [G] 60.486a(e)(2) [G] 60.486a(e)(4) 60.486a(e)(7) [G] 60.486a(e)(8) [G] 60.486a(h) 60.487a(a) 60.487a(b) 60.487a(b)(1) 60.487a(b)(3) 60.487a(c) 60.487a(c)(1) 60.487a(c)(2) 60.487a(c)(2)(i) 60.487a(c)(2)(iii) 60.487a(c)(2)(iv) 60.487a(c)(2)(xi) 60.487a(c)(3) 60.487a(c)(4) 60.487a(e) 60.5420a(a) 60.5420a(a)(1) 60.5422a(a) Renewal- Effective Page xiv FUG-2 EU FUG-2 EU FUG-2 EU 60OOOOa- VOC 5400 60OOOOa- VOC 5400 60OOOOa- VOC 5400 40 CFR Part 60, Subpart OOOOa 40 CFR Part 60, Subpart OOOOa 40 CFR Part 60, Subpart OOOOa 60.5385a(a)(1) 60.5370a(a) 60.5370a(b) 60.5385a 60.5385a(a) 60.5385a(b) 60.5385a(c) 60.5385a(d) 60.5410a 60.5415a(c) 60.5415a(c)(2) 60.5415a(c)(3) 60.5400a(a) 60.482-11a(b)(2) 60.482-11a(b)(3) 60.482-11a(d) [G] 60.482-11a(e) [G] 60.48211a(f)(1) 60.482-11a(f)(2) 60.482-11a(g) 60.482-9a(a) 60.482-9a(b) 60.485a(b) 60.486a(a)(1) 60.486a(a)(2) 60.486a(k) 60.5370a(a) 60.5370a(b) 60.5400a(a) 60.5400a(d) 60.5400a(e) 60.5400a(f) 60.5401a(d) 60.5410a 60.5410a(f) 60.5415a(f) 60.5400a(a) 60.482-10a(a) [G] 60.482-10a(f) [G] 60.482-10a(g) 60.482-10a(h) 60.482-10a(i) [G] 60.482-10a(j) For each reciprocating compressor, the owner or operator must replace the rod packing on or before the compressor has operated for 26,000 hours. The number of hours of operation must be continuously monitored beginning upon initial startup of your reciprocating compressor affected facility, August 2, 2016, or the date of the most recent reciprocating compressor rod packing replacement, whichever is later. 60.5410a(c)(1) 60.5415a(c)(1) Except as provided in 60.5401 connectors in gas and vapor and light liquid service must comply with the requirements of 60.48211a. If an instrument reading greater than or equal to 500 ppm is measured in connectors in gas and vapor and light liquid service, a leak is detected. 60.482-11a(a) 60.482-11a(b) 60.482-11a(b)(1) 60.482-11a(b)(3) 60.48211a(b)(3)(i) 60.48211a(b)(3)(ii) [G] 60.48211a(b)(3)(iii) 60.48211a(b)(3)(iv) 60.482-11a(c) 60.482-9a(a) 60.485a(a) [G] 60.485a(b)(1) 60.485a(b)(2) 60.485a(d) 60.485a(d)(2) 60.485a(d)(3) [G] 60.485a(e) [G] 60.5401a(f) 60.5401a(g) Except as provided in 60.5401 closed vent systems leaks must comply with the requirements of 60.482-10a. Closed vent system leaks, as indicated by an instrument reading greater than 500 ppmv 60.485a(a) [G] 60.485a(b)(1) 60.485a(b)(2) 60.485a(d) 60.485a(d)(2) 60.485a(d)(3) [G] 60.5401a(f) 60.5410a(c)(4) 60.5420a(c) [G] 60.5420a(c)(3) 60.482-11a(b)(3)(v) 60.485a(b)(2) [G] 60.486a(a)(3) [G] 60.486a(b) [G] 60.486a(c) 60.486a(e) 60.486a(e)(1) [G] 60.486a(e)(8) 60.486a(e)(9) 60.486a(f) 60.486a(f)(1) [G] 60.482-10a(l) 60.485a(b)(2) [G] 60.486a(d) 60.486a(e) 60.486a(e)(1) [G] 60.486a(e)(8) 60.5410a(c)(3) 60.5420a(a) 60.5420a(a)(1) 60.5420a(b) [G] 60.5420a(b)(1) 60.5420a(b)(11) [G] 60.5420a(b)(13) [G] 60.5420a(b)(14) [G] 60.5420a(b)(4) 60.487a(a) 60.487a(b) 60.487a(b)(1) 60.487a(b)(5) 60.487a(c) 60.487a(c)(1) 60.487a(c)(2) 60.487a(c)(2)(vii) 60.487a(c)(2)(viii) 60.487a(c)(2)(xi) 60.487a(c)(3) 60.487a(c)(4) 60.487a(e) 60.5420a(a) 60.5420a(a)(1) 60.5422a(a) 60.487a(a) 60.487a(b) 60.487a(b)(1) 60.487a(c) 60.487a(c)(1) 60.487a(c)(2) 60.487a(c)(2)(xi) Renewal- Effective Page xv FUG-2 EU FUG-2 EU 60OOOOa- VOC 5400 60OOOOa- VOC 5400 40 CFR Part 60, Subpart OOOOa 40 CFR Part 60, Subpart OOOOa [G] 60.482-10a(k) 60.482-10a(m) 60.482-1a(a) 60.482-1a(b) 60.485a(b) 60.486a(a)(1) 60.486a(a)(2) 60.486a(k) 60.5370a(a) 60.5370a(b) 60.5400a(a) 60.5400a(d) 60.5400a(e) 60.5400a(f) 60.5410a 60.5410a(f) 60.5415a(f) 60.5400a(a) 60.18(b) 60.482-10a(a) 60.482-10a(d) 60.482-10a(m) 60.482-1a(a) 60.482-1a(b) 60.485a(b) 60.485a(c) 60.485a(c)(1) 60.485a(f) 60.486a(a)(1) 60.486a(a)(2) 60.486a(k) 60.5370a(a) 60.5370a(b) 60.5400a(a) 60.5400a(d) 60.5400a(e) 60.5400a(f) 60.5410a 60.5410a(f) 60.5415a(f) 60.5400a(a) 60.482-10a(a) 60.482-10a(c) 60.482-10a(m) 60.482-1a(a) 60.482-1a(b) 60.485a(b) 60.485a(c) 60.485a(c)(1) above background or by visual inspections, shall be repaired as soon as practicable except as provided in paragraph (h) of this section. 60.5401a(g) Except as provided in 60.5401 flares must comply with the requirements of 60.48210a. Flares used to comply with this subpart shall comply with the requirements of 60.18. 60.482-10a(e) 60.485a(a) [G] 60.485a(b)(1) 60.485a(b)(2) 60.485a(c)(2) 60.485a(d) 60.485a(d)(2) 60.485a(d)(3) [G] 60.485a(g) [G] 60.5401a(f) 60.5401a(g) Except as provided in 60.5401 enclosed combustion devices must comply with the requirements of 60.48210a. Enclosed combustion devices shall be designed and operated to reduce the VOC emissions vented to them with an efficiency of 60.482-10a(e) 60.485a(a) [G] 60.485a(b)(1) 60.485a(b)(2) 60.485a(c)(2) 60.485a(d) 60.485a(d)(2) 60.485a(d)(3) [G] 60.5401a(f) 60.485a(b)(2) [G] 60.486a(b) [G] 60.486a(c) 60.486a(e) 60.486a(e)(1) [G] 60.486a(e)(8) 60.485a(b)(2) 60.486a(e) 60.486a(e)(1) [G] 60.486a(e)(8) 60.487a(c)(3) 60.487a(c)(4) 60.487a(e) 60.5420a(a) 60.5420a(a)(1) 60.5422a(a) 60.487a(a) 60.487a(b) 60.487a(b)(1) 60.487a(c) 60.487a(c)(1) 60.487a(c)(2) 60.487a(c)(2)(xi) 60.487a(c)(3) 60.487a(c)(4) 60.487a(e) 60.5420a(a) 60.5420a(a)(1) 60.5422a(a) 60.487a(a) 60.487a(b) 60.487a(b)(1) 60.487a(c) 60.487a(c)(1) 60.487a(c)(2) 60.487a(c)(2)(xi) 60.487a(c)(3) 60.487a(c)(4) Renewal- Effective Page xvi FUG-2 EU FUG-2 EU 60OOOOa- VOC 5400 60OOOOa- VOC 5400 40 CFR Part 60, Subpart OOOOa 40 CFR Part 60, Subpart OOOOa 60.485a(f) 60.486a(a)(1) 60.486a(a)(2) 60.486a(k) 60.5370a(a) 60.5370a(b) 60.5400a(a) 60.5400a(d) 60.5400a(e) 60.5400a(f) 60.5410a 60.5410a(f) 60.5415a(f) 60.5400a(a) 60.482-1a(a) 60.482-1a(b) [G] 60.4822a(c)(2) [G] 60.482-7a(e) 60.482-8a(a) 60.482-8a(a)(2) 60.482-8a(b) [G] 60.482-8a(c) 60.482-8a(d) 60.482-9a(a) 60.482-9a(b) 60.485a(b) 60.485a(f) 60.486a(a)(1) 60.486a(a)(2) 60.486a(k) 60.5370a(a) 60.5370a(b) 60.5400a(a) 60.5400a(d) 60.5400a(e) 60.5400a(f) 60.5410a 60.5410a(f) 60.5415a(f) 60.5400a(a) 60.482-1a(a) 60.482-1a(b) 60.482-6a(a)(1) 60.482-6a(a)(2) 60.482-6a(b) 60.482-6a(c) 60.482-6a(d) 60.482-6a(e) 95 percent or greater, or to an exit concentration of 20 parts per million by volume, on a dry basis, corrected to 3 percent oxygen, whichever is less stringent or to provide a minimum residence time of 0.75 seconds at a minimum temperature of 816 degrees. 60.5401a(g) Except as provided in 60.5401 pressure relief devices in light liquid or heavy liquid service must comply with the requirements of 60.482-8a. At a pressure relief device in light liquid or heavy liquid service, if an instrument reading of 10,000 ppm or greater is measured, a leak is detected. 60.482-8a(a)(1) 60.482-9a(a) 60.485a(a) [G] 60.485a(b)(1) 60.485a(b)(2) 60.485a(d) 60.485a(d)(2) 60.485a(d)(3) [G] 60.5401a(f) 60.5401a(g) Except as provided in 60.5401 open-ended valves or lines must comply with the requirements of 60.482-6a. Each openended valve or line shall be equipped with a cap, blind flange, plug, or a second valve, except as provided in 60.482-1a(c) and 60.485a(a) [G] 60.485a(b)(1) 60.485a(b)(2) 60.485a(d) 60.485a(d)(2) 60.485a(d)(3) [G] 60.5401a(f) 60.5401a(g) 60.485a(b)(2) [G] 60.486a(a)(3) [G] 60.486a(b) [G] 60.486a(c) 60.486a(e) 60.486a(e)(1) [G] 60.486a(e)(8) 60.485a(b)(2) 60.486a(e) 60.486a(e)(1) [G] 60.486a(e)(8) 60.487a(e) 60.5420a(a) 60.5420a(a)(1) 60.5422a(a) 60.487a(a) 60.487a(b) 60.487a(b)(1) 60.487a(c) 60.487a(c)(1) 60.487a(c)(2) 60.487a(c)(2)(xi) 60.487a(c)(3) 60.487a(c)(4) 60.487a(e) 60.5420a(a) 60.5420a(a)(1) 60.5422a(a) 60.487a(a) 60.487a(b) 60.487a(b)(1) 60.487a(c) 60.487a(c)(1) 60.487a(c)(2) 60.487a(c)(2)(xi) 60.487a(c)(3) 60.487a(c)(4) Renewal- Effective Page xvii GRP-ENG1 EU GRP-ENG1 EU GRP-ENG1 EU GRP-ENG1 EU 60JJJJ- CO 4230 60JJJJ- NOX 4230 60JJJJ4230 VOC 63ZZZZ6590 112(B) HAPS 40 CFR Part 60, Subpart JJJJ 40 CFR Part 60, Subpart JJJJ 40 CFR Part 60, Subpart JJJJ 40 CFR Part 63, Subpart ZZZZ 60.485a(b) 60.485a(f) 60.486a(a)(1) 60.486a(a)(2) 60.486a(k) 60.5370a(a) 60.5370a(b) 60.5400a(a) 60.5400a(d) 60.5400a(e) 60.5400a(f) 60.5410a 60.5410a(f) 60.5415a(f) paragraphs 60.482-6a(d) and 60.482-6a(e) of this section. 60.4233(e)-Table 1 60.4234 60.4243(b) 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4243(g) 60.4246 Owners and operators of stationary non-emergency natural gas engines with a maximum engine power greater than or equal to 500 HP and were manufactured on or after 07/01/2010 must comply with a CO emission limit of 2.0 g/HP-hr, as listed in Table 1 to this subpart. 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4244(a) 60.4244(b) 60.4244(c) 60.4244(e) 60.4233(e)-Table 1 60.4234 60.4243(b) 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4243(g) 60.4246 Owners and operators of stationary non-emergency natural gas engines with a maximum engine power greater than or equal to 500 HP and were manufactured on or after 07/01/2010 must comply with a NOx emission limit of 1.0 g/HP-hr, as listed in Table 1 to this subpart. 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4244(a) 60.4244(b) 60.4244(c) 60.4244(d) 60.4233(e)-Table 1 60.4234 60.4243(b) 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4243(g) 60.4246 63.6590(c) Owners and operators of stationary non-emergency natural gas engines with a maximum engine power greater than or equal to 500 HP and were manufactured on or after 07/01/2010 must comply with a VOC emission limit of 0.7 g/HPhr, as listed in Table 1 to this subpart. Stationary RICE subject to Regulations under 40 CFR Part 60. An affected source 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4244(a) 60.4244(b) 60.4244(c) 60.4244(f) 60.4244(g) None 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4245(a) 60.4245(a)(1) 60.4245(a)(2) 60.4245(a)(4) 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4245(a) 60.4245(a)(1) 60.4245(a)(2) 60.4245(a)(4) 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4245(a) 60.4245(a)(1) 60.4245(a)(2) 60.4245(a)(4) None 60.487a(e) 60.5420a(a) 60.5420a(a)(1) 60.5422a(a) [G] 60.4245(c) 60.4245(d) [G] 60.4245(c) 60.4245(d) [G] 60.4245(c) 60.4245(d) None Renewal- Effective Page xviii GRP-ENG2 EU GRP-ENG2 EU GRP-ENG2 EU GRP-ENG2 EU 60JJJJ- CO 4230 60JJJJ- NOX 4230 60JJJJ4230 VOC 63ZZZZ6590 112(B) HAPS 40 CFR Part 60, Subpart JJJJ 40 CFR Part 60, Subpart JJJJ 40 CFR Part 60, Subpart JJJJ 40 CFR Part 63, Subpart ZZZZ that meets any of the criteria in paragraphs (c)(1) through (7) of this section must meet the requirements of this part by meeting the requirements of 40 CFR part 60 subpart IIII, for compression ignition engines or 40 CFR part 60 subpart JJJJ, for spark ignition engines as applicable. No further requirements apply for such engines under this part. 60.4233(e)-Table 1 60.4234 60.4243(b) 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4243(g) 60.4246 Owners and operators of stationary non-emergency natural gas engines with a maximum engine power greater than or equal to 500 HP and were manufactured on or after 07/01/2010 must comply with a CO emission limit of 2.0 g/HP-hr, as listed in Table 1 to this subpart. 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4244(a) 60.4244(b) 60.4244(c) 60.4244(e) 60.4233(e)-Table 1 60.4234 60.4243(b) 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4243(g) 60.4246 Owners and operators of stationary non-emergency natural gas engines with a maximum engine power greater than or equal to 500 HP and were manufactured on or after 07/01/2010 must comply with a NOx emission limit of 1.0 g/HP-hr, as listed in Table 1 to this subpart. 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4244(a) 60.4244(b) 60.4244(c) 60.4244(d) 60.4233(e)-Table 1 60.4234 60.4243(b) 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4243(g) 60.4246 63.6590(c) Owners and operators of stationary non-emergency natural gas engines with a maximum engine power greater than or equal to 500 HP and were manufactured on or after 07/01/2010 must comply with a VOC emission limit of 0.7 g/HPhr, as listed in Table 1 to this subpart. Stationary RICE subject to Regulations under 40 CFR Part 60. An affected source 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4244(a) 60.4244(b) 60.4244(c) 60.4244(f) 60.4244(g) None 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4245(a) 60.4245(a)(1) 60.4245(a)(2) 60.4245(a)(4) 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4245(a) 60.4245(a)(1) 60.4245(a)(2) 60.4245(a)(4) 60.4243(b)(2) 60.4243(b)(2)(ii) 60.4243(e) 60.4245(a) 60.4245(a)(1) 60.4245(a)(2) 60.4245(a)(4) None [G] 60.4245(c) 60.4245(d) [G] 60.4245(c) 60.4245(d) [G] 60.4245(c) 60.4245(d) None Renewal- Effective Page xix GRP- EU TANKS1 GRP- EU TANKS2 60Kb-110b VOC 60Kb-110b VOC 40 CFR Part 60, Subpart Kb 40 CFR Part 60, Subpart Kb that meets any of the criteria in paragraphs (c)(1) through (7) of this section must meet the requirements of this part by meeting the requirements of 40 CFR part 60 subpart IIII, for compression ignition engines or 40 CFR part 60 subpart JJJJ, for spark ignition engines as applicable. No further requirements apply for such engines under this part. [G] 60.112b(a)(3) 60.18 Storage vessels specified in 60.112b(a) and equipped with a closed vent system/control device are to meet the specifications of 60.112b(a)(3)(i)-(ii). 60.113b(d) 60.116b(a) 60.116b(b) 60.116b(e) 60.116b(e)(1) [G] 60.116b(e)(3) [G] 60.485(b) ** See Periodic Monitoring Summary 60.112b(a)(1) 60.112b(a)(1)(i) 60.112b(a)(1)(ii)(A) 60.112b(a)(1)(iii) 60.112b(a)(1)(iv) 60.112b(a)(1)(ix) 60.112b(a)(1)(v) 60.112b(a)(1)(vi) 60.112b(a)(1)(vii) 60.112b(a)(1)(viii) Storage vessels specified in 60.112b(a) and equipped with a fixed roof in combination with an internal floating roof shall meet the specifications listed in 60.112b(a)(1)(i)-(ix). 60.113b(a)(1) 60.113b(a)(2) 60.113b(a)(4) 60.113b(a)(5) 60.116b(a) 60.116b(b) 60.116b(c) 60.116b(e) 60.116b(e)(1) [G] 60.116b(e)(3) 60.115b 60.115b(d)(2) 60.116b(a) 60.116b(b) 60.115b 60.115b(a)(2) 60.116b(a) 60.116b(b) 60.116b(c) 60.115b 60.115b(d)(1) 60.115b(d)(3) 60.113b(a)(2) 60.113b(a)(5) 60.115b 60.115b(a)(1) 60.115b(a)(3) Renewal- Effective Page xx Additional Monitoring Requirements Periodic Monitoring Summary................................................................................................................ 24 Renewal- Effective Page xxi Periodic Monitoring Summary Unit/Group/Process Information ID No.: GRP-TANKS1 Control Device ID No.: CVS Control Device Type: Vapor collection system (closed vent system) Applicable Regulatory Requirement Name: 40 CFR Part 60, Subpart Kb SOP Index No.: 60Kb-110b Pollutant: VOC Main Standard: [G] 60.112b(a)(3) Monitoring Information Indicator: VOC Concentration Minimum Frequency: Once per year Averaging Period: N/A Deviation Limit: The closed vent system shall be operated with no detectable emissions as indicated by an instrument reading of less than 500 ppm above background. Periodic Monitoring Text: Measure and record fugitive emissions from the vapor collection system in accordance with part 60, appendix A, method 21. Renewal- Effective Page xxii Periodic Monitoring Summary Unit/Group/Process Information ID No.: GRP-TANKS1 Control Device ID No.: CVS Control Device Type: Vapor collection system (closed vent system) Applicable Regulatory Requirement Name: 40 CFR Part 60, Subpart Kb SOP Index No.: 60Kb-110b Pollutant: VOC Main Standard: [G] 60.112b(a)(3) Monitoring Information Indicator: Visual Inspection Minimum Frequency: Once per year Averaging Period: N/A Deviation Limit: It shall be considered a deviation if any defects found are not repaired. Periodic Monitoring Text: Visually inspect all components of the vapor collection system for defects, such as cracks, holes, gaps, loose connections, or broken or missing covers or other closure devices, that could result in air emissions. Renewal- Effective Page xxiii Permit Shield Permit Shield ........................................................................................................................................... 27 Renewal- Effective Page xxiv Permit Shield The Executive Director of the TCEQ has determined that the permit holder is not required to comply with the specific regulation(s) identified for each emission unit, group, or process in this table. Unit / Group / Process ID No. Group / Inclusive Units Regulation Basis of Determination AMINE AMINE-2 FUG-1 FUG-2 GRP-TANKS1 GRP-TANKS1 GRP-TANKS2 GRP-TANKS2 GRP-TANKS3 GRP-TANKS3 N/A N/A N/A N/A TK-1, TK-2 40 CFR Part 60, Subpart OOOO 40 CFR Part 60, Subpart OOOO 40 CFR Part 60, Subpart OOOO 40 CFR Part 60, Subpart OOOO 40 CFR Part 60, Subpart K TK-1, TK-2 TK-3, TK-4 40 CFR Part 60, Subpart OOOOa 40 CFR Part 60, Subpart K TK-3, TK-4 40 CFR Part 60, Subpart OOOOa TK-10, TK-11, TK-12, TK-13, TK-14, TK-15, TK-16, TK-17, TK-5, TK-6, TK7, TK-8, TK-9 TK-10, TK-11, TK-12, TK-13, TK-14, TK-15, TK-16, TK-17, TK-5, TK-6, TK7, TK-8, TK-9 40 CFR Part 60, Subpart K 40 CFR Part 60, Subpart OOOOa The components were constructed after 09/18/2015. The components were constructed after 09/18/2015. The components were constructed after 09/18/2015. The components were constructed after 09/18/2015 The storage tanks were constructed/reconstructed/modified after July 23, 1984. The storage tanks emit less than 6 TPY VOC per tank and were constructed after 09/18/2015. The storage tanks were constructed/reconstructed/modified after July 23, 1984. The storage tanks emit less than 6 TPY VOC per tank and were constructed after 09/18/2015. The storage tanks were constructed/reconstructed/modified after July 23, 1984. The storage tanks emit less than 6 TPY VOC per tank and were constructed after 09/18/2015. Renewal- Effective Page xxv New Source Review Authorization References New Source Review Authorization References..................................................................................... 29 New Source Review Authorization References by Emission Unit....................................................... 30 Renewal- Effective Page xxvi New Source Review Authorization References The New Source Review authorizations listed in the table below are applicable requirements under 30 TAC Chapter 122 and enforceable under this operating permit. Title 30 TAC Chapter 116 Permits, Special Permits, and Other Authorizations (Other Than Permits By Rule, PSD Permits, or NA Permits) for the Application Area. Authorization No.: 141647 IIssuance Date: 05/31/2023 Renewal- Effective Page xxvii New Source Review Authorization References by Emissions Unit The following is a list of New Source Review (NSR) authorizations for emission units listed elsewhere in this operating permit. The NSR authorizations are applicable requirements under 30 TAC Chapter 122 and enforceable under this operating permit. Unit/Group/Process ID No. AMINE AMINE-2 C-1680 C-1690 C-1710 C-171N C-1720 C-172N C-1730 C-173N C-1740 C-174N C-1750 C-1760 C-1770 C-1780 C-181 C-182 C-183 COMB-1 DEHY1 Emission Unit Name/Description AMINE UNIT VENT 1 AMINE UNIT VENT 2 COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE COMPRESSOR ENGINE TANK VENT FLARE DEHYDRATION UNIT New Source Review Authorization 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 Renewal- Effective Page xxviii FLARE-1 FLARE-2 FUG-1 FUG-2 TK-1 TK-10 TK-11 TK-12 TK-13 TK-14 TK-15 TK-16 TK-17 TK-2 TK-3 TK-4 TK-5 TK-6 TK-7 TK-8 TK-9 PLANT FLARE PLANT FLARE 2 NON-MONITORED FUGITIVES MONITORED FUGITIVES CONDENSATE STORAGE TANK OPEN DRAIN STORAGE TANK OPEN DRAIN STORAGE TANK OPEN DRAIN STORAGE TANK OPEN DRAIN STORAGE TANK OPEN DRAIN STORAGE TANK OPEN DRAIN STORAGE TANK OPEN DRAIN STORAGE TANK OPEN DRAIN STORAGE TANK CONDENSATE STORAGE TANK IFR CONDENSATE STORAGE TANK IFR CONDENSATE STORAGE TANK SLOPE OIL STORAGE TANK OPEN DRAIN STORAGE TANK OPEN DRAIN STORAGE TANK OPEN DRAIN STORAGE TANK OPEN DRAIN STORAGE TANK 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 141647 Renewal- Effective Page xxix Appendix A Acronym List............................................................................................................................................ 33 Renewal- Effective Page xxx Acronym List The following abbreviations or acronyms may be used in this permit: ACFM................................................................................................................. actual cubic feet per minute AMOC................................................................................................................... alternate means of control ARP................................................................................................................................. Acid Rain Program ASTM.......................................................................................... American Society of Testing and Materials B/PA.......................................................................................... Beaumont/Port Arthur (nonattainment area) CAM........................................................................................................ Compliance Assurance Monitoring CD........................................................................................................................................... control device CEMS............................................................................................ continuous emissions monitoring system CFR.................................................................................................................. Code of Federal Regulations COMS................................................................................................ continuous opacity monitoring system CVS................................................................................................................................. closed vent system D/FW................................................................................................ Dallas/Fort Worth (nonattainment area) EP........................................................................................................................................... emission point EPA................................................................................................... U.S. Environmental Protection Agency EU............................................................................................................................................. emission unit FCAA Amendments............................................................................... Federal Clean Air Act Amendments FOP.......................................................................................................................... federal operating permit gr/100 scf................................................................................................. grains per 100 standard cubic feet HAP........................................................................................................................... hazardous air pollutant H/G/B.............................................................................. Houston/Galveston/Brazoria (nonattainment area) H2S...................................................................................................................................... hydrogen sulfide ID No............................................................................................................................. identification number lb/hr................................................................................................................................... pound(s) per hour MACT.............................................................. Maximum Achievable Control Technology (40 CFR Part 63) MMBtu/hr.............................................................................................. Million British thermal units per hour NA........................................................................................................................................... nonattainment N/A........................................................................................................................................... not applicable NADB............................................................................................................. National Allowance Data Base NESHAP.................................National Emission Standards for Hazardous Air Pollutants (40 CFR Part 61) NOx........................................................................................................................................ nitrogen oxides NSPS........................................................................ New Source Performance Standard (40 CFR Part 60) NSR............................................................................................................................... New Source Review ORIS............................................................................................. Office of Regulatory Information Systems Pb............................................................................................................................................................ lead PBR........................................................................................................................................ Permit By Rule PEMS.............................................................................................. predictive emissions monitoring system PM...................................................................................................................................... particulate matter ppmv................................................................................................................... parts per million by volume PRO............................................................................................................................................ process unit PSD..................................................................................................... prevention of significant deterioration psia............................................................................................................ pounds per square inch absolute SIP........................................................................................................................ state implementation plan SO2........................................................................................................................................... sulfur dioxide TCEQ...................................................................................... Texas Commission on Environmental Quality TSP..................................................................................................................... total suspended particulate TVP................................................................................................................................. true vapor pressure U.S.C.............................................................................................................................. United States Code VOC.................................................................................................................... volatile organic compound Renewal- Effective Page xxxi