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Home My WebLink About20141285.tiff STATE OF COLORADO John W.Hickenlooper,Governor Christopher E.Urbina,MD,MPH �0?C9\o Executive Director and Chief Medical Officer he,, Dedicated to protecting and improving the health and environment of the people of Colorado ..4Yd-'4 4300 Cherry Creek Dr.S. Laboratory Services Division ��\ ,_YYYY Denver,Colorado 80246-1530 8100 Lowry Blvd. �8�� Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health http://www.cdphe.state.co.us and Environment Weld County—Clerk to the Board 1150 O Street PO Box 758 Greeley,CO 80632 April 21, 2014 Dear Sir or Madam: On April 27, 2014,the Air Pollution Control Division will publish a public notice for Aka Energy Group, LLC—Gilcrest Gas Plant, in the The Greeley Tribune. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30)days from the date the public notice is published. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health & Environment APCD-SS-B I 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, 7 r /,Vc& Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure Of Pclr ) Pizemim es) lit(.06) y ZOI -I y 'Z3 '2ottif 2014-1285 STATE OF COLORADO John W.Hickenlooper,Governor Christopher E.Urbina,MD,MPH Ao4:COL_ • Executive Director and Chief Medical Officer tre4i1417sis:\:*° Dedicated to protecting and improving the health and environment of the people of Colorado4300 Cherry Creek Dr.5. Laboratory Services Division • Denver,Colorado 80246-1530 8100 Lowry Blvd. • Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health http://www.cdphe.state.co.us and Environment Website Title: Aka Energy Group, LLC—Gilcrest Gas Plant—Weld County Released To: The Greeley Tribune On: April 21, 2014 Published: April 27, 2014 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Aka Energy Group, LLC Facility: Gilcrest Gas Plant Natural gas processing plant 13472 Weld County Road 40 Weld County The proposed project or activity is as follows: Natural gas processing plant modifying permit limits for six(6) existing reciprocating internal combustion engines,and adding three (3)reciprocating internal combustion engines,one(I) condensate storage tank, one (1)truck loadout, one (1) amine sweetening unit and reboiler, a natural gas heater for a thermal oxidizer and associated fugitive emissions with the new equipment. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Pan B, Section III.C.I.a (25 tpy in a non-attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 07WE0881 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at www.colorado.gov/cdphe/AirPublicNotices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Stephanie Chaousy Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South,APCD-SS-B I Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us DII STATE OF COLORADO of corn COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT `% AIR POLLUTION CONTROL DIVISION * i TELEPHONE: (303)692-3150 `*1876 4 CONSTRUCTION PERMIT PERMIT NO: 07WE0881 Issuance 1 DATE ISSUED: ISSUED TO: Aka Energy Group, LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Gilcrest Gas Plant, located at 13472 Weld County Road 40, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point One (1) Caterpillar, Model G3516LE, Serial Number WPW01963, natural gas-fired, turbo-charged, 4SLB C-1 001 reciprocating internal combustion engine, site rated at 1297 horsepower at 1400 RPM. This engine shall be equipped with an oxidation catalyst and air-fuel ratio control. This emission unit is used for natural gas compression. One (1)Waukesha Model F1197G, Serial Number 87655, natural gas-fired, four-cycle standard rich-burn reciprocating internal combustion engine, site rated at 166 horsepower. C-6 002 This engine is equipped with an air-fuel ratio controller and a Non-Selective Catalytic Reduction (NSCR) system for the control of NOx, CO and VOC. This emission unit powers a natural gas compressor. One (1)Waukesha Model F1197G, Serial Number 1060271, natural gas-fired, four-cycle standard rich-burn reciprocating internal combustion engine, site rated at 166 horsepower. C-7 003 This engine is equipped with an air-fuel ratio controller and a Non-Selective Catalytic Reduction (NSCR) system for the control of NOx, CO and VOC. This emission unit powers a natural gas compressor. AIRS ID: 123/0098 Page 1 of 38 NGEngine Version 2012-1 DCo do p e o Public PollutionHealthand Control DivisionEnvironment Facility AIRS Description Equipment ID Point One (1)White-Superior, Model 8G825, Serial Number 20220, natural gas-fired, four-cycle standard rich-burn reciprocating internal combustion engine, site rated at 708 C-3 005 horsepower. This engine is equipped with an air-fuel ratio controller and a Non-Selective Catalytic Reduction (NSCR) system for the control of NOx and CO and VOC. This emission unit powers a natural gas compressor. One (1)Waukesha, Model L5790GSI, Serial Number C13524/1, natural gas-fired, turbo-charged, 4SRB reciprocating internal combustion engine, site rated at 1215 C-4 007 horsepower at 1200 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. V-50 010 VOC emissions from plant blowdown vent One (1)Waukesha, Model L7044GSI, Serial Number C- 14656/1, natural gas-fired, turbo-charged, 4SRB reciprocating intemal combustion engine, site rated at 1680 C-2 011 horsepower at 1200 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. LEAKS (KKK) 014 Fugitive emissions from equipment leaks from existing emission components. One (1)Waukesha, Model L5790GSI, Serial Number C13525/1, natural gas-fired, turbo-charged, 4SRB reciprocating internal combustion engine, site rated at 1215 C-5 016 horsepower at 1200 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. One (1) Caterpillar, Model G3306TA, Serial Number TBD, natural gas-fired, turbo-charged,4SRB reciprocating intemal C-8 018 combustion engine, site rated at 195 horsepower at 1800 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. AIRS ID: 123/0098 Page 2 of 38 pCoIA do IF eM o Public Health and Environment Air Pollution Control Division Facility AIRS Description Equipment ID Point One (1) Caterpillar, Model G3306TA, Serial Number TBD, natural gas-fired, turbo-charged, 4SRB reciprocating internal C-9 019 combustion engine, site rated at 195 horsepower at 1800 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. LOADOUT 022 Truck loadout of condensate. Emissions from the loadout are controlled. One (1) Diglycolamine (DGA) natural gas sweetening system for acid gas removal with a design capacity of 40 MMSCF per day (make, model, serial number: TBD). This emissions unit is equipped with six (6) electric amine recirculation pumps of which three (3) are backup pumps, AMINE 023 with a total design capacity of 150 gallons per minute. This system includes a natural gas/amine contactor, a flash tank, an amine reclaimer and a natural gas fired amine regeneration reboiler (Point 024). Amine regenerator emissions are routed to a thermal oxidizer (Point 025). Flash tank emissions are 100% recycled. REBOILER 0Y4 Amine reboiler, natural gas-fired, with maximum expected rating of 16 MMBtu/hr. TOBURNER 025 Natural gas burner for thermal oxidizer with a maximum expected rating of 8.05 MMbtu/hr, including pilot light. LEAKS 026 Fugitive emissions from equipment leaks from expansion (OOOO) emission components. One (1) Caterpillar, Model G3508B, Serial Number TBD, natural gas-fired, turbo-charged, 4SLB reciprocating intemal C10 028 combustion engine, site rated at 690 horsepower at 1400 RPM. This engine shall be equipped with an oxidation catalyst and air-fuel ratio control. This emission unit is used for natural gas compression. One (1) Caterpillar, Model G3508B, Serial Number TBD, natural gas-fired, turbo-charged, 4SLB reciprocating intemal C11 029 combustion engine, site rated at 690 horsepower at 1400 RPM. This engine shall be equipped with an oxidation catalyst and air-fuel ratio control. This emission unit is used for natural gas compression. Regenerative gas heater, natural gas-fired, with a 11.5 REGEN 030 MMBtu/hr rating (manufacturer, model and SN: TBD). Emissions from this source are not controlled. AIRS ID: 123/0098 Page 3 of 38 D Co do p e o Public Health and Environment Air Pollution Control Division Points 001, 002, 003, 005, 007, 011, 016, 018, 019, 028, 029: These engines may be replaced with another engine in accordance with the temporary engine replacement provision or with another an engine of the same make and model specified for each point in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seaj, TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. Points 018, 019, 022, 023, 024, 025, 026, 028, 029 and 030: YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after commencement of operation, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Points 001, 002, 003, 005, 007, 010, 011, 014 and 016: Within one hundred and eighty days (180) after issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, II.G.2). 3. Points 018, 019, 022, 023, 024, 025, 026, 028, 029 and 030: Within one hundred and eighty days (180) after commencement of operation, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, II.G.2). 4. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 5. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 6. Points 018, 019, 022, 023, 024, 025, 026, 028, 029 and 030: The following information shall be provided to the Division within fifteen (15)days after issuance of permit. • manufacture date AIRS ID: 123/0098 Page 4 of 38 Col do p e o Public Health and Environment Air Pollution Control Division • construction date • order date • date of relocation into Colorado • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, III.E.) 7. The operator shall retain the permit final authorization letter issued by the Division after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 8. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Monthly Limits: Facility AIRS Pounds per Month Emission Equipment ID Point SO, H2S NO, VOC CO Type C-1 001 --- --- 3194 323 289 Point C6 002 --- --- 408 34 272 Point C7 003 --- --- 408 34 272 Point C-3 005 --- --- 1156 238 2328 Point C-4 007 --- --- 1393 799 1988 Point V-50 010 --- --- --- 901 Point C-2 011 --- 2752 697 2752 Point LEAKS (KKK) 014 --- --- --- 4773 --- Fugitive C-5 016 --- --- 1393 799 1988 Point C-8 018 --- --- 323 --- 646 Point C-9 019 --- --- 323 --- 646 Point LOADOUT 022 --- --- 374 136 731 Point AMINE 023 629 7 --- 527 323 Point REBOILER 024 --- --- 1138 --- 968 Point TOBURNER 025 --- --- 578 --- 493 Point LEAKS 026 --- --- --- 3160 --- Fugitive (OOOO) C10 028 --- --- 566 566 292 Point C11 029 --- --- 566 566 292 Point REGEN 030 --- --- 816 --- 697 Point AIRS ID: 123/0098 Page 5 of 38 I) Co do p e o Public PollutionHealthand ControlEnvironment Division (Note: Monthly limits are based on a 31-day month.) The owner or operator shall calculate monthly emissions based on the calendar month. Facility-wide emissions of each individual hazardous air pollutant shall be less than 1,359 lb/month. Facility-wide emissions of total hazardous air pollutants shall be less than 3,398 lb/month. Annual Limits: Facility AIRS Tons per Year Emission Equipment ID Point SO. H2S NO, VOC CO Type C-1 001 — --- 18.8 1.9 1.7 Point C-6 002 --- --- 2.4 0.2 1.6 Point C-7 003 --- --- 2.4 0.2 1.6 Point C-3 005 --- --- 6.8 1.4 13.7 Point C-4 007 --- -- 8.2 4.7 11.7 Point V-50 010 --- --- --- 5.3 -- Point C-2 011 --- — 16.2 4.1 16.2 Point LEAKS (KKK) 014 --- — --- 28.1 --- Fugitive C-5 016 --- --- 8.2 4.7 11.7 Point C-8 018 --- --- 1.9 -- 3.8 Point C-9 019 --- --- 1.9 — 3.8 Point LOADOUT 022 --- --- 2.2 0.8 4.3 Point AMINE 023 3.7 0.04 -- 3.1 1.9 Point REBOILER 024 --- --- 6.7 --- 5.7 Point TOBURNER 025 --- — 3.4 --- 2.9 Point LEAKS 026 --- --- — 18.6 --- Fugitive (OOOO) O10 028 -- --- 3.3 3.3 1.7 Point C11 029 — --- 3.3 3.3 1.7 Point REGEN 030 --- -- 4.8 --- 4.1 Point See "Notes to Permit Holder"for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. AIRS ID: 123/0098 Page 6 of 38 1,ll Colik do s'' p e o Public Health and Environment `• Air Pollution Control Division • Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 9. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) Facility AIRS Pollutants Equipment Point Control Device Controlled ID C-1 001 Oxidation catalyst and air/fuel ratio controller VOC, CO and HAPS C-6 002 Non-Selective Catalytic Reduction (NSCR) and NOx, VOC, CO air/fuel ratio controller and HAPS C-7 003 Non-Selective Catalytic Reduction (NSCR) and NOx, VOC, CO air/fuel ratio controller and HAPS C-3 005 Non-Selective Catalytic Reduction (NSCR) and NOx, VOC, CO air/fuel ratio controller and HAPS C-4 007 Non-Selective Catalytic Reduction (NSCR) and NOx, VOC, CO air/fuel ratio controller and HAPS C-2 011 Non-Selective Catalytic Reduction (NSCR) and NOx, VOC, CO air/fuel ratio controller and HAPS LEAKS 014 LDAR VOC, HAPS (KKK) C-5 016 Non-Selective Catalytic Reduction (NSCR) and NOx, VOC, CO air/fuel ratio controller and HAPS C-8 018 Non-Selective Catalytic Reduction (NSCR) and NOx, VOC, CO air/fuel ratio controller and HAPS C-9 019 Non-Selective Catalytic Reduction (NSCR) and NOx, VOC, CO air/fuel ratio controller and HAPS Loadout 022 Enclosed combustor device VOC, HAPS AMINE 023 Thermal Oxidizer H2S, VOC, HAPS LEAKS 026 LDAR VOC, HAPS (OOOO) C10 028 Oxidation Catalyst VOC, CO and HAPS C11 029 Oxidation Catalyst VOC, CO and HAPS 10. Points 014 and 026: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas analysis, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling AIRS ID: 123/0098 Page 7 of 38 DCo do ] e o Public PollutionHealthand Control DivisionEnvironment events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. PROCESS LIMITATIONS AND RECORDS 11. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Annual Monthly Limit Equipment Point Process Parameter Limit (31 days) ID 86.3 7.3 C-1 001 Consumption of natural gas as a fuel MMscf/yr MMscf/month Consumption of natural gas as a fuel 13.1 1.1 C-6 002 •MMscf/vr 13.1 Consumption of natural gas as a fuel sc MM 1.1 C-7 ' 003 f/yr MMscf/month C-3 005 Consumption of natural gas as a fuel 49.6 4.2 MMscf/yr MMscf/month 85.1 7.2 C-4 007 Consumption of natural gas as a fuel MMscf/yr MMscf/month V-50 010 Total volume of residue gas vented 3.5 0.3 due to maintenance activities MMscf/yr MMscf/month 112.6 9.6 C-2 011 Consumption of natural gas as a fuel sof/ MMscf/yr MMscf/month 8 CS MM 016 Consumption of natural gas as a fuel s 7.2 scf/yr MMscf/month 13.4 1.2 C-8 018 Consumption of natural gas as a fuel MMscf/yr MMscf/month 1 C-9 019 Consumption of natural gas as a fuel 1.2 MMscfcf/yr MMscf/month 70,000 5,945.2 LOADOUT 022 Condensate Loading BBUyrBUyr BBUmonth AMINE 023 Natural gas throughput 14,600 1,240 MMscf/yr MMscf/month REBOILER 024 Combustion of supplemental fuel 134.8 11.5 MMscf/yr MMscf/month TOBURNER 025 Combustion of supplemental fuel 67.8 5.8 MMscf/yr MMscf/month 47.7 4.1 C10 028 Consumption of natural gas as a fuel MMscfcf/yr MMscf/month 4 C11 029 Consumption of natural gas as a fuel 4.1 MMscf/yr MMscf/month REGEN 030 Consumption of natural gas as a fuel 96.9 8.2 MMscf/yr MMscf/month The owner or operator shall calculate monthly process rates based on the calendar month. AIRS ID: 123/0098 Page 8 of 38 Co ido • p_ e o Public Health and Environment Air Pollution Control Division During the first twelve (12) months of operation, compliance with both the monthly and annual throughput limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 12. Point 023: This unit shall be limited to the maximum lean amine recirculation pump rate of 150 gallons per minute. The lean amine recirculation rate shall be recorded weekly in a log maintained on site and made available to the Division for inspection upon request. (Reference: Regulation No. 3, Part B, II.A.4) STATE AND FEDERAL REGULATORY REQUIREMENTS 13. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 14. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) 15. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) Specific Requirements for Natural Gas-Fired Engines (Points 001, 002, 003, 005, 007, 011, 016, 018, 019, 028 and 029) 16. Points 001, 028 and 029: This equipment is subject to the control requirements for stationary and portable engines in the 8-hour ozone control area under Regulation No. 7, Section XVI.B.2. For lean burn reciprocating internal combustion engines, an oxidation catalyst shall be required. 17. Points 005, 007, 011, 016: This equipment is subject to the control requirements for stationary and portable engines in the 8-hour ozone control area under Regulation No. 7, Section XVI.B.1. For rich burn reciprocating internal combustion engines, a non-selective catalyst reduction system and an air fuel controller shall be required. 18. Points 001, 005, 007, 011 016, 028 and 029: This equipment is subject to the requirements for natural gas-fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E.3 (State only enforceable). Any lean or rich burn reciprocating internal combustion engine constructed or modified before February 1, 2009 with a manufacturer's name plate design rate greater than 500 horsepower shall install and operate both a non-selective catalyst reduction and an air fuel controller or an oxidation catalyst by July 1, 2010. The operator shall operate and maintain the air pollution control equipment to manufacturer specifications or equivalent to the extent practicable and shall keep manufacturer specifications or equivalent on file. Records of AIRS ID: 123/0098 Page 9 of 38 D Co do C/part e o Public Health and Environment 1■�_ Air Pollution Control Division maintenance shall be kept on site or at a local field office with site responsibility, for Division review. Please note that replacements of this engine in accordance with the AOS in Attachment A may be subject to this or other requirements in Regulation 7, Section XVII.E. 19. Points 001, 005, 007, 011 016, 018, 019, 028 and 029: This equipment may be subject to the control requirements for natural gas-fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas-fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Maximum Engine Construction or Emission Standard in g/hp-hr HP Relocation Date NOx CO VOC <100HP Any N/A N/A N/A 100HP and January 1, 2008 2.0 4.0 1.0 <500HP January 1, 2011 1.0 2.0 0.7 500HP July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 Note: Per Regulation No. 7, Section XVII.B.4, internal combustion engines that are subject to an emission standard or an emissions control requirement in a federal maximum achievable control technology ("MACT") standard under 40 CFR Part 63, a Best Available Control Technology ("BACT") limit, or a New Source Performance Standard under 40 CFR Part 60 are not subject to this Section XVII. Specific Requirements for the Plant Blowdown Vent(Point 0101 20. The permittee shall record each time the plant blowdown vent is used. The permittee shall record the start and finish time of each such event. 21. The permittee shall calculate the volume of gas released from each event. The permittee shall record such parameters necessary to calculate the volume of gas released such as pressure and pipeline dimensions. The calculations determining the volume from each release shall clearly show the methodology to estimate the volume of gas vented and shall be made available to the Division upon request. 22. The permittee shall calculate the VOC emissions from each event using the volume of gas estimated in accordance with Condition 21 and a representative gas analysis as required by Condition 47. Note that the most recent gas analysis shall be used to calculate emissions. VOC from each event shall be summed to obtain monthly emissions from venting. Monthly emissions shall be used in a rolling twelve month total AIRS ID: 123/0098 Page 10 of 38 Colo do e' p e o Public Health and Environment Air Pollution Control Division F to monitor compliance with the annual limitations. Each month a new twelve month total shall be calculated using the previous twelve months data. Standards of Performance for Equipment Leaks of VOC From Onshore Natural Gas Processing Plants (Points 014 and 026): 23. This source is subject to Regulation N.o. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. The operator shall comply with all applicable requirements of Section XII. 24. Point 014: This source is subject to Regulation No. 7, Section XII.G.1 (State only enforceable). For fugitive VOC emissions from leaking equipment, the leak detection and repair (LDAR) program as provided a 40 C.F.R. Part 60, Subpart KKK (see Regulation Number 6, Part A, Subpart KKK) shall apply, regardless of the date of construction of the affected facility. The operator shall comply with all applicable requirements of Section XII. 25. Point 014: This facility is subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart KKK, Standards of Performance for Onshore Natural Gas Processing Plants including, but not limited to, the following: • 40 CFR, Part 60, Subpart A— General Provisions • §60.632 Standards o (a) - Each owner or operator subject to the provisions of this subpart shall comply with the requirements of § 60.482-1 (a), (b), and (d) and 60.482-2 through 60.482-10, except as provided in § 60.633, as soon as practicable, but no later than 180 days after initial startup. o (b) - An owner or operator may elect to comply with the requirements of §60.483-1 and §60.483-2. o (d) Each owner or operator subject to the provisions of this subpart shall comply with the provisions of§60.485 except as provided in §60.633(f) of this subpart. o (e) Each owner or operator subject to the provisions of this subpart shall comply with the provisions of §§60.486 and 60.487 except as provided in §§60.633, 60.635, and 60.636 of this subpart. • §60.633 Exceptions o (a) Each owner or operator subject to the provisions of this subpart may comply with the following exceptions to the provisions of subpart W. o (b)(1) Each pressure relief device in gas/vapor service may be monitored quarterly and within 5 days after each pressure release to detect leaks by the methods specified in §60.485(b) except as provided in §60.632(c), paragraph (b)(4) of this section, and §60.482-4 (a) through (c) of subpart VV. • (2) If an instrument reading of 10,000 ppm or greater is measured, a leak is detected. AIRS ID: 123/0098 Page 11 of 38 D Co do p e o Public Health and Environment Air Pollution Control Division • (3)(i) When a leak is detected, it shall be repaired as soon as practicable, but no later than 15 calendar days after it is detected, except as provided in §60.482-9. • (Ii) A first attempt at repair shall be made no later than 5 calendar days after each leak is detected. o (c) Sampling connection systems are exempt from the requirements of §60.482-5. • §60.635 Recordkeeping o (a) Each owner or operator subject to the provisions of this subpart shall comply with the requirements of paragraphs (b) and (c) of this section in addition to the requirements of§60.486. o (b) The following recordkeeping requirements shall apply to pressure relief devices subject to the requirements of§60.633(b)(1) of this subpart. • (1) When each leak is detected as specified in §60.633(b)(2), a weatherproof and readily visible identification, marked with the equipment identification number, shall be attached to the leaking equipment. The identification on the pressure relief device may be removed after it has been repaired. • (2) When each leak is detected as specified in §60.633(b)(2), the following information shall be recorded in a log and shall be kept for 2 years in a readily accessible location: • (i) The instrument and operator identification numbers and the equipment identification number. • (ii) The date the leak was detected and the dates of each attempt to repair the leak. • (iii) Repair methods applied in each attempt to repair the leak. • (iv) "Above 10,000 ppm" if the maximum instrument reading measured by the methods specified in paragraph (a) of this section after each repair attempt is 10,000 ppm or greater. • (v) "Repair delayed" and the reason for the delay if a leak is not repaired within 15 calendar days after discovery of the leak. • (vi) The signature of the owner or operator (or designate) whose decision it was that repair could not be effected without a process shutdown. • (vii) The expected date of successful repair of the leak if a leak is not repaired within 15 days. • (viii) Dates of process unit shutdowns that occur while the equipment is unrepaired. • (ix) The date of successful repair of the leak. • (x) A list of identification numbers for equipment that are designated for no detectable emissions under the provisions of §60.482-4(a). The designation of equipment subject to the provisions of §60.482-4(a) shall be signed by the owner or operator. AIRS ID: 123/0098 Page 12 of 38 . . _ Coli do • p e o Public Health and Environment a Air Pollution Control Division • §60.636 Reporting Requirements o (a) Each owner or operator subject to the provisions of this subpart shall comply with the requirements of paragraphs (b) and (c) of this section in addition to the requirements of§60.487. o (b) An owner or operator shall include the following information in the initial semiannual report in addition to the information required in §60.487(b) (1)— (4): Number of pressure relief devices subject to the requirements of §60.633(b) except for those pressure relief devices designated for no detectable emissions under the provisions of §60.482-4(a) and those pressure relief devices complying with §60.482-4(c). o (c) An owner or operator shall include the following information in all semiannual reports in addition to the information required in §60.487(c)(2) (i) through (vi): • (1) Number of pressure relief devices for which leaks were detected as required in §60.633(b)(2) and • (2) Number of pressure relief devices for which leaks were not repaired as required in §60.633(b)(3). 26. Point 026: This source is subject to Regulation No. 7, Section XII.G.1 (State only enforceable). To comply with Regulation No. 7, Section XII.G.1, the source shall follow the leak detection and repair (LDAR) program as provided at 40 C.F.R. Part 60, Subpart OOOO in lieu of following 40 C.F.R. Part 60, Subpart KKK. 27. Point 026: The fugitive emissions addressed by AIRS ID 026 are subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart OOOO, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution including, but not limited to, the following: • §60.5365 Applicability - The group of all equipment, except compressors, within a process unit for which you commence construction, modification or reconstruction after August 23, 2011 is an affected facility per§60.5365(f). • §60.5400 Standards - The group of all equipment, except compressors, within a process unit must comply with the requirements of§60.5400 and §60.5401. • §60.6410 - Owner or operator must demonstrate initial compliance with the standards using the requirements in §60.5410(f). • § 60.5415 - Owner or operator must demonstrate continuous compliance with the standards using the requirements in §60.5415(f). • § 60.5421 - Owner or operator must comply with the recordkeeping requirements of §60.5421(b). • § 60.5422 - Owner or operator must comply with the reporting requirements of paragraphs (b) and (c) of this section in addition to the requirements of§ 60.487a(a), (b), (c)(2)(i) through (iv), and (c)(2)(vii) through (viii). 28. Point 026: The reciprocating compressors grouped with the fugitive emissions addressed by AIRS ID 018, 019, 028 and 029 are subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart OOOO, AIRS ID: 123/0098 Page 13 of 38 Co do p e o Public PollutionHealthand Control DivisionEnvironment Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution including, but not limited to, the following: • §60.5385(a) — Owner or operator must replace the reciprocating compressor rod packing according to either paragraph §60.5385(a)(1) or(2). (1) §60.5385(a)(1) - 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, or October 15, 2012, or the date of the most recent reciprocating compressor rod packing replacement, whichever is later. (2) §60.5385(a)(2) - Prior to 36 months from the date of the most recent rod packing replacement, or 36 months from the date of startup for a new reciprocating compressor for which the rod packing has not yet been replaced. • §60.5410 — Owner or operator must demonstrate initial compliance with the standards as detailed in §60.5410(c). • §60.5415— Owner or operator must demonstrate continuous compliance with the standards as detailed in §60.5415(c). • §60.5420 - Owner or operator must comply with the notification, reporting, and recordkeeping requirements as specified in -§60.5420(a), §60.5420(b)(1), §60.5420(b)(4), and §60.5420(c)(3). Specific Requirements for the Truck Loadout(Point 0221 29. This source is located in an ozone non-attainment or attainment-maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 30. The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches (including thief hatches)shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations to ensure compliance with Condition 30 (a) and (b) above. The inspections shall occur for each loading session but no more frequently than once every 14 days. Each inspection shall be documented in a log available to the Division on request. d. Loading pump shut-offs, set stop meters, or comparable equipment shall be employed to prevent the over filling of transport vehicles. AIRS ID: 123/0098 Page 14 of 38 Col " doll) e o Public Health and Environment Air Pollution Control Division 31. All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. for the Amine Sweetening Unit (Point 023) Specific Requirements g 32. The amine units addressed by AIRS ID 023 are subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart OOOO, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution including, but not limited to, the following: • §60.5365—Applicability and Designation of Affected Facilities o §60.5365(g)(3) - 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 §60.5423(c) but are not required to comply with §§60.5405 through 60.5407 and §§60.5410(g) and 60.5415(g). • §60.5423— Record keeping and reporting Requirements o §60.5423(c) -To certify that a facility is exempt from the control requirements of these standards, for each facility with a design capacity less that 2 LT/D of H2 S in the acid gas (expressed as sulfur) you must keep, for the life of the facility, an analysis demonstrating that the facility's design capacity is less than 2 LT/D of H2 S expressed as sulfur. 33. The combustion temperature of the thermal oxidizer used to control emissions from the amine unit shall be greater than 1400 °F, or the temperature established during the most recent stack test of the equipment that was approved by the Division. The approved operating temperature shall be maintained at all times that any amine unit emissions are routed to the thermal oxidizer in order to meet the emission limits in this permit. 34. 100% of emissions that result from the flash tank associated with this amine unit shall be recycled to the fuel gas system. 35. The operator shall continuously monitor with a flow meter the following amine unit emission streams: a. total acid gas volume routed to each RTO, b. total acid gas volume routed to the thermal oxidizer (point 025), c. total acid gas supplemental fuel volume routed to the thermal oxidizer(point 025), and By the end of each month, the total flow for the previous months' data shall be calculated, and a new twelve-month total shall be calculated and recorded based on the previous twelve months' data. Specific Requirements for the Amine Reboiler & Regenerator Heater (Points 024 and 030) AIRS ID: 123/0098 Page 15 of 38 Co do p e o Public PollutionHealthand Control DivisionEnvironment 36. This source is subject to the New Source Performance Standards requirements of Regulation No. 6, Part A Subpart Dc, Standards of Performance for Small Industrial- Commercial-Institutional Steam Generating Units including, but not limited to, the following: a. The owner or operator of the facility shall record and maintain records of the amount of fuel combusted during each month (40 CFR Part 60.48c(g)). b. Monthly records of fuel combusted required under the previous condition shall be maintained by the owner or operator of the facility for a period of two years following the date of such record (40 CFR Part 60.48c(i)). In addition, the following requirements of Regulation No. 6, Part A, Subpart A, General Provisions, apply. c. At all times, including periods of start-up, shutdown, and malfunction, the facility and control equipment shall, to the extent practicable, be maintained and operated in a manner consistent with good air pollution control practices for minimizing emissions. Determination of whether or not acceptable operating and maintenance procedures are being used will be based on information available to the Division, which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. (Reference: Regulation No. 6, Part A. General Provisions from 40 CFR 60.11 d. No article, machine, equipment or process shall be used to conceal an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in the gases discharged to the atmosphere. (§ 60.12) e. Written notification of construction and initial startup dates shall be submitted to the Division as required under§60.7. f. Records of startups, shutdowns, and malfunctions shall be maintained, as required under§ 60.7. 37. Particulate emissions shall be limited as per Regulation 6, Part B, II.C.2. where: PE= 0.5*(FI)-' Where: PE = allowable particulate emissions in pounds per million Btu heat input Fl = fuel input in million Btu per hour OPERATING & MAINTENANCE REQUIREMENTS 38. Points 001, 002, 003, 005, 007, 011, 014, 016, 018, 019, 022, 023, 026, 028 and 029: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements AIRS ID: 123/0098 Page 16 of 38 TiColik ado pp e o Public Health and Environment Air Pollution Control Division of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 39. Point 014: Within one hundred and eighty days (180) after issuance of this permit, the owner or operator shall complete the initial extended gas analysis of gas samples that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the gas analysis and emission calculations to the Division as part of the self-certification process to ensure compliance with emissions limits. 40. Point 014: Within one hundred and eighty days (180) after issuance of this permit, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. 41. Point 026: Within one hundred and eighty days (180) after commencement of operation, the owner or operator shall complete the initial extended gas analysis of gas samples that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the gas analysis and emission calculations to the Division as part of the self-certification process to ensure compliance with emissions limits. 42. Point 026: Within one hundred and eighty days (180) after commencement of operation, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. 43. Points 001, 002, 003, 005, 007, 011, 016, 018, 019, 028 and 029: A source initial compliance test shall be conducted on emissions points 001, 002, 003, 005, 007, 011, 016, 018, 019, 028 and 029 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emission limits in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. AIRS ID: 123/0098 Page 17 of 38 Co do par gT e o Public Health and Environment 1■p Air Pollution Control Division Carbon Monoxide using EPA approved methods. Volatile Organic Compounds using EPA approved methods. (For Points 018 and 019 ONLY) Formaldehyde 44. Point 023: The owner or operator shall complete the initial extended sour gas analysis testing required by this permit and submit the results to the Division as part of the self- certification process to ensure compliance with emissions limits. (Reference: Regulation No. 3, Part B, Section III.E.) 45. Point 023: A source initial compliance test shall be conducted on emissions point 023 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emission and process limits in this permit. The operator shall demonstrate the thermal oxidizer achieves a minimum destruction efficiency of 98.0%for VOC. The natural gas throughput, supplemental fuel throughput, lean amine recirculation rate, lean amine strength and sulfur content of gas shall be monitored and recorded during the test. The operator shall also measure and record combustion temperature during the test to establish minimum combustion temperature. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Sulfur Dioxide using EPA approved methods. Volatile Organic Compounds using EPA approved methods. Hazardous Air Pollutants using EPA approved methods. Carbon Monoxide using EPA approved methods. Periodic Testing Requirements 46. Points 001, 002, 003, 005, 007, 011, 016, 018, 019, 028 and 029: These engines are subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Altemative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. 47. Point 010: The permittee shall complete a gas analysis on a semiannual basis of gas samples that are representative of gas that may be vented from the plant blowdown vent (point 010). 48. Points 014 and 026: On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. AIRS ID: 123/0098 Page 18 of 38 syuY va�.% y,.ni ! t Col do 9a p.rtime or Public Health and Environment �3, #a ' Air Pollution Control Division � - . . 54`-zxe.l 49. Point 023: The operator shall sample the inlet gas to the amine unit on an annual basis to determine the concentration of hydrogen sulfide (H2S) in the gas stream. The sample results shall be monitored to demonstrate that this amine unit qualifies for the exemption from the Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution (§60.5365(g)(3)). The testing required by Condition 50 may be used for this demonstration. 50. Point 023: The owner shall complete an extended sour gas analysis prior to the inlet of the amine unit on an annual basis. Results of the sour gas analysis shall be used to calculate emissions of criteria pollutants and HAPS per Condition 8. ADDITIONAL REQUIREMENTS 51. All previous versions of this permit are cancelled upon issuance of this permit. 52. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO,) in ozone nonattainment areas emitting less than 100 tons of VOC or NO per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Points 001, 002, 003, 005, 007, 011, 016, 018, 019, 028 and 029: Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative-operating scenario and is installing a permanent replacement engine. AIRS ID: 123/0098 Page 19 of 38 D Col do p att e o Public Health and Environment 1■ Air Pollution Control Division 53. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS: 54. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section 11.8 upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 55. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 56. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 57. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 58. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 59. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the AIRS ID: 123/0098 Page 20 of 38 Col�,do Bp� `me o Public Health and Environment Il i Air Pollution Control Division Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 60. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Stephanie Chaousy, PE Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Aka Energy Group, LLC. Change in permit limits to Points 001, 002, 003, 005, 007, 010, 011, 014 and 016. Addition of(4) RICE, truck loadout, amine sweetening unit, amine reboiler and burner for the thermal oxidizer. Initial Approval — September 24, Modification to replace engine with point ID 001 Modification 1 2008 with a Caterpillar G3516LE. Initial Approval January 29, Issued to Aka Energy Group, LLC 2008 AIRS ID: 123/0098 Page 21 of 38 DCo do p e o Public PollutionHealthand Control DivisionEnvironment Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: htto://www.cdphe.state.co.us/requlations/ai rregs/100102agcccommonorovisionsrea.pdf. 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Are the Controlled AIRS Pollutant CAS# BIN Emission emissions Emission Point Rate reportable? Rate(Ib/yr) (lb/yr) Formaldehyde 50000 A 6513 Yes 1628 Acetaldehyde 75070 A 722 Yes 361 Acrolein 107028 A 444 Yes 222 001 Methanol 67561 C 216 No 108 n-Hexane 110543 C 96 No 48 Benzene 71432 A 112 Yes 56 Toluene 108883 C 704 No 352 Formaldehyde 50000 A 321 Yes 161 Acetaldehyde 75070 A 37 No 18 002 and Acrolein 107028 A 35 No 17 003 Methanol 67561 C 64 No 32 EACH Benzene 71432 A 21 No 11 Toluene 108883 C 7 No 4 • Formaldehyde 50000 A 1367 Yes 684 Methanol 67561 C 152 No 46 005 Acetaldehyde 75070 A 138 Yes 69 Acrolein 107028 A 131 Yes 65 AIRS ID: 123/0098 Page 22 of 38 .. p Col. do rid p, e o Public Health and Environment Air Pollution Control Division Benzene 71432 A 79 Yes 39 1,3-Butadiene 106990 A 33 No 16 Toluene 108883 C 28 No 14 Formaldehyde 50000 A 2347 Yes 1173 Methanol 67561 C 261 No 130 007 Acetaldehyde 75070 A 238 Yes 119 and Acrolein 107028 A 224 Yes 112 016 EACH Benzene 71432 A 135 Yes 67 1,3-Butadiene 106990 A 56 Yes 28 Toluene 108883 C 48 No 24 Formaldehyde 50000 A 3245 Yes 1622 Methanol 67561 C 649 No 324 Acetaldehyde 75070 A 314 Yes 157 011 Acrolein 107028 A 296 Yes 148 Benzene 71432 A 178 Yes 89 1,3-Butadiene 106990 A 75 Yes 37 Toluene 108883 C 63 No 31 Benzene 71432 A 1219 Yes 589 Toluene 108883 C 1555 Yes 753 014 Ethylbenzene 100414 C 0 No 0 Xylenes 1130207 C 375 No 180 n-Hexane 110543 C 8444 Yes 4094 Formaldehyde 50000 A 942 Yes 471 Methanol 67561 C 43 No 22 018 Acetaldehyde 75070 A 39 No 19 and Acrolein 107028 A 37 No 18 019 EACH Benzene 71432 A 22 No 11 1,3-Butadiene 106990 A 9 No 5 Toluene 108883 C 8 No 4 Benzene 71432 A 560 Yes 28 Toluene 108883 C 725 No 36 022 Xylenes 1130207 C 165 No 8 n-Hexane 110543 C 3953 No 198 023 Benzene 71432 A 133544 Yes 2671 AIRS ID: 123/0098 Page 23 of 38 DCo do D■p e o Public PollutionHealthand Control DivisionEnvironment Toluene 108883 C 99521 Yes 1990 Ethylbenzene 100414 C 299 No 6 i Xylenes 1130207 C 5330 Yes 107 n-Hexane 110543 C 201 No 4 Acetaldehyde 75070 A 103 Yes 103 Benzene 71432 A 105 Yes 105 Formaldehyde 50000 A 118 Yes 118 024 Toluene 108883 C 142 No 142 Ethylbenzene 100414 C 296 No 296 Xylenes 1130207 C 185 No 185 n-Hexane 110543 C 248 No 248 Acetaldehyde 75070 A 52 Yes 52 025 Benzene 71432 A 53 Yes 53 Formaldehyde 50000 A 60 Yes 60 Benzene 71432 A 848 Yes 411 Toluene 108883 C 1076 Yes 524 026 Ethylbenzene 100414 C 0 Yes 0 Xylenes 1130207 C 261 No 125 n-Hexane 110543 C 5826 Yes 2839 Formaldehyde 50000 A 5597 Yes 1399 Acetaldehyde 75070 A 415 Yes 207 028 Acrolein 107028 A 255 Yes 127 and Methanol 67561 C 124 No 62 029 EACH n-Hexane 110543 C 55 No 28 Benzene 71432 A 65 Yes 32 Toluene 108883 C 404 No 202 Benzene 71432 A 75 Yes 75 Toluene 108883 C 102 No 102 Ethylbenzene 100414 C 212 No 212 030 Xylenes 1130207 C 133 No 133 n-Hexane 110543 C 178 No 178 Formaldehyde 50000 A 86 Yes 86 Acetaldehyde 75070 A 74 Yes 74 AIRS ID: 123/0098 Page 24 of 38 Col do p n e o Public Health and Environment Air Pollution Control Division 5) The emission levels contained in this permit are based on the following emission factors: Point 001: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant Ib/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 0.4351 1.5 0.4351 1.5 CO 0.5512 1.9 0.0386 0.133 VOC 0.1740 0.6 0.0435 0.150 50000 Formaldehyde 0.0754 0.26 0.0189 0.065 75070 Acetaldehyde 0.0084 0.0288 0.0042 0.0144 107028 Acrolein 0.0051 0.0177 0.0026 0.0089 67561 Methanol 0.0025 0.0086 0.0013 0.0043 110543 n-Hexane 0.0011 0.0038 0.0006 0.0019 71432 Benzene 0.0013 0.0045 0.0006 0.0022 108883 Toluene 0.0081 0.0281 0.0041 0.0140 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 7600 Btu/hp-hr, a site-rated horsepower value of 1297, and a fuel heat value of 1000 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer+AP-42 Manufacturer+AP-42 50000 Formaldehyde Manufacturer Manufacturer Points 002 and 003 each: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant Ib/MMBtu g/bhp-hr Ib/MMBtu g/bhp-hr NOx 2.817 11.5 0.3674 1.5 CO 3.6744 15 0.2450 1 VOC 0.0735 0.3 0.0367 0.15 50000 Formaldehyde 0.0245 0.1 0.0122 0.05 67561 Methanol 0.0031 0.0125 0.0015 0.0062 75070 Acetaldehyde 0.0028 0.0114 0.0014 0.0057 107028 Acrolein 0.0026 0.0107 0.0013 0.0054 71432 Benzene 0.0016 0.0065 0.0008 0.0032 106990 1,3-Butadiene 0.0007 0.0027 0.0003 0.0014 108883 Toluene 0.0006 0.0023 0.0003 0.0011 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 9000 Btu/hp-hr, a site-rated horsepower value of 166, and a fuel heat value of 1000 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer/AP-42 Manufacturer/AP-42 VOC Manufacturer Manufacturer 50000 Formaldehyde GRI Field Data GRI Field Data i AIRS ID: 123/0098 Page 25 of 38 Co do p e o Public PollutionHealthand Control DivisionEnvironment Point 005: Emission Factors- Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.3069 12 0.2756 1 CO 3.0314 11 0.5512 2 VOC 0.1102 0.4 0.0551 0.2 50000 Formaldehyde 0.0276 0.1 0.0138 0.05 67561 Methanol 0.0031 0.0112 0.0015 0.0056 75070 Acetaldehyde 0.0028 0.0102 0.0014 0.0051 107028 Acrolein 0.0026 0.0094 0.0013 0.0047 71432 Benzene 0.0016 0.0058 0.0008 0.0029 106990 1,3-Butadiene 0.0007 0.0025 0.0003 0.0013 108883 Toluene 0.0006 0.0022 0.0003 0.0011 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8000 Btu/hp-hr, a site-rated horsepower value of 708, and a fuel heat value of 1000 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde Manufacturer Manufacturer Points 007 and 016: Emission Factors- Emission Factors— Uncontrolled Controlled CAS Pollutant IbIMMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.0314 11 0.1929 0.7 CO 2.2046 8 0.2756 1 VOC 0.2205 0.8 0.1102 0.4 50000 Formaldehyde 0.0276 0.1 0.0138 0.05 67561 Methanol 0.0031 0.0111 0.0015 0.0056 75070 Acetaldehyde 0.0028 0.0101 0.0014 0.0051 107028 Acrolein 0.0026 0.0095 0.0013 0.0048 71432 Benzene 0.0016 0.0057 0.0008 0.0029 106990 1,3-Butadiene 0.0007 0.0024 0.0003 0.0012 108883 Toluene 0.0006 0.0020 0.0003 0.0010 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8000 Btu/hp-hr, a site-rated horsepower value of 1215, and a fuel heat value of 1000 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer+AP-42 Manufacturer+AP-42 50000 Formaldehyde Manufacturer Manufacturer AIRS ID: 123/0098 Page 26 of 38 aik I- st Col do mt p e o'Public Health and Environment II Air Pollution Control Division ik Point 010: Emissions are calculated using the results of representative gas analyses and a calculation of the amount of gas released during each event that the blowdown vent is used. Point 011: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant Ib/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.7752 13.1 0.2882 1 CO 3.3718 11.7 0.2882 1 VOC 0.1441 0.5 0.0721 0.25 50000 Formaldehyde 0.0288 0.1 0.0144 0.05 67561 Methanol 0.0058 0.0201 0.0029 0.0101 75070 Acetaldehyde 0.0028 0.0097 0.0014 0.0049 107028 Acrolein 0.0026 0.0090 0.0013 0.0045 71432 Benzene 0.0016 0.0056 0.0008 0.0028 106990 1,3-Butadiene 0.0007 0.0024 0.0003 0.0012 108883 Toluene 0.0006 0.0021 0.0003 0.0011 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 7650 Btu/hp-hr, a site-rated horsepower value of 1680, and a fuel heat value of 1000 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde Manufacturer Manufacturer Point 014: Emission estimate for fugitive equipment leaks are based on the following component counts: Group 1: Wet gas, condensate, engine oil and other heavy liquids Stream VOC Benzene Toluene Ethyl- Xylene n- n -n e -o < o (wt%) (wt%) (wt%) benzene (wt%) hexane g ≥ m S °1 5 (wt%) (wt%) 'm t -6 CD m m R m O m Gas 25 0.1 0.1 0 0.05 0.5 1136 442 0 780 16 Heavy 100 1.7 2.2 0 0.5 12 561 86 5 244 7 Liquid Light 100 1.7 2.2 0 0.5 12 1729 596 13 1114 4 Liquid Water/Oil 100 1.7 2.2 0 0.5 12 215 48 1 83 1 Group 2: Dry Gas Stream VOC Benzene Toluene Ethyl- Xylene n- C) m < o (wt%) (wt%) (wt%) benzene (wt%) hexane s m m 5 (wt%) (wt%) z ' cl 9 m m N O y Gas 5 -- -- --- -- --- 2091 488 770 25 Heavy --- --- -- --- --- --- -- --- --- -- Liquid Light --- --- -- --- --- --- -- Liquid AIRS ID: 123/0098 Page 27 of 38 Co do p e o Publth D Airic PoHealllutionand Control DEnvironmentivision Water/Oil -- -- -- -- -- -- -- -- -- -- Group 3: Propane refrigerant, methanol, antifreeze Stream VOC Benzene Toluene Ethyl- Xylene n- n m N- (wt%) (wt%) (wt%) benzene (wt%) hexane g d m e m (wt%) (wt%) o Fig l a y O N Gas 100 -- -- — — -- 595 138 3 297 Heavy 100 -- - - - . -- 62 12 0 37 Liquid Light 100 -- -- -- - -- 42 0 0 21 Liquid , Water/Oil 100 -- -- -- -- -- -- -- -- -- *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors(kg/hr-component): Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas analysis. Points 018 and 019: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant Ib/MMBtu g/bhp-hr Ib/MMBtu g/bhp-hr NOx 4.4639 16.5 0.2705 1 CO 4.4639 16.5 0.5411 2 VOC 0.1028 0.38 0.0514 0.19 50000 Formaldehyde 0.0676 0.25 0.0338 0.125 67561 Methanol 0.0031 0.0115 0.0015 0.0058 75070 Acetaldehyde 0.0028 0.0103 0.0014 0.0052 107028 Acrolein 0.0026 0.0096 0.0013 0.0048 71432 Benzene 0.0016 0.0059 0.0008 0.0030 106990 1,3-Butadiene 0.0007 0.0026 0.0003 0.0013 108883 Toluene 0.0006 0.0022 0.0003 0.0011 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8149 Btu/hp-hr, a site-rated horsepower value of 195, and a fuel heat value of 1040 Btu/scf. Emission Factor Sources: AIRS ID: 123/0098 Page 28 of 38 Col do p rt e o Public Health and Environment Air Pollution Control Division CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer/AP-42 Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer/AP-42 50000 Formaldehyde Manufacturer Manufacturer Point 022: Emission Factors - Emission Factors - Uncontrolled Controlled CAS Pollutant lb/BBL Source lb/BBL Source loaded loaded VOC 0.47 AP-42 0.0235 AP-42 71432 Benzene 0.0080 Wt% 0.0004 Wt % 108883 Toluene 0.0104 Wt% 0.00052 Wt% 1330207 Xylenes 0.0024 Wt% 0.00012 Wt% 110543 n-Hexane 0.0565 Wt% 0.00283 Wt % The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L= 12.46*S*P*M/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 10.4 psia M (vapor molecular weight) = 74.98 Ib/Ib-mol T (temperature of liquid loaded) = 520.36 °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. Point 023: Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source lb/MMscf Natural lb/MMscf Natural Gas Throughput Gas Throughput NOx 0.10Ib/MMBtu --- TNRCC CO 0.53 lb/MMBtu --- TNRCC Compliance with VOC, H2S and SOx shall be demonstrated using a flow meter. Note: The controlled emissions factors for point 023 are based on the thermal oxidizer control efficiency of 98%. Points 024 and 025: Emission Factors— CAS Pollutant Uncontrolled Source VOC 5.5 lb/mmscf AP-42, Table 1.4-1 NOx 100 lb/mmscf AP-42, Table 1.4-1 CO 84 lb/mmscf AP-42, Table 1.4-1 75070 Acetaldehyde 0.000738 lb/mmbtu GRI Test Field Data 71432 Benzene 0.000748 lb/mmbtu GRI Test Field Data 5000 Formaldehyde 0.000844 lb/mmbtu GRI Test Field Data AIRS ID: 123/0098 Page 29 of 38 • D Co do p e o Pu and Environment Airblic PHealthollution Control Division Point 026: Emission estimate for fugitive equipment leaks are based on the following component counts: Group 1: Wet gas, condensate, engine oil and other heavy liquids Stream VOC Benzene Toluene Ethyl- Xylene n- n i O -o < O (wt%) (wt%) (wt%) benzene (wt%) hexane g g N 5 d g wt%) (wt%) d X a N O N Gas 25 0.1 0.1 0 0.05 0.5 844 348 0 587 16 Heavy 100 1.7 2.2 0 0.5 12 497 68 5 184 7 Liquid Light 100 1.7 2.2 0 0.5 12 1090 398 13 741 4 Liquid Water/Oil 100 1.7 2.2 0 0.5 12 174 30 1 61 1 Group 2: Dry Gas Stream VOC Benzene Toluene Ethyl- Xylene n- n -n < O (wt%) (wt%) (wt%) benzene (wt%) hexane g m m g (wt%) (wt%) O N y CD CD N g N Gas 5 -- -- -- -- -- 1294 364 501 25 Heavy -- -- -- -- -- -- -- -- — -- Liquid Light -- -- -- -- -- -- -- -- -- -- Liquid Water/Oil — -- -- -- -- -- -- — -- -- Group 3: Propane refrigerant, methanol, antifreeze Stream VOC Benzene Toluene Ethyl- Xylene n- (wt%) (wt%) (wt%) benzene (wt%) hexane g m CO = < (wt%) (wt%) N N N V m a N Gas 100 -- -- -- -- -- 356 70 3 124 Heavy 100 -- -- -- -- — 26 0 0 13 Liquid Light 100 -- -- -- -- — 30 0 0 15 Liquid Water/Oil 100 -- -- -- -- — -- — -- — Group 4: Amine plant • Stream VOC Benzene Toluene Ethyl- Xylene n- (wt%) (wt%) (wt%) benzene (wt%) hexane o m CO c 5 & O 5.2 ( t%) (wt%) N (gyp N V N a? a N J A N N Gas 25 0.5 0.5 0.005 0.10 1.5 20 20 0 15 0 Heavy 50 0.05 0.05 0.0001 0.001 0.001 800 800 6 720 50 Liquid Light 50 0.05 0.05 0.0001 0.001 0.001 -- -- -- -- -- Liquid Water/Oil 50 0.05 0.05 0.0001 0.001 0.001 — -- -- — -- AIRS ID: 123/0098 Page 30 of 38 . Col j do s p "" a o Public Health and Environment ,r Air Pollution Control Division ` ₹ ... . •. *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors(kg/hr-component): Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas analysis. Points 028 and 029: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant Ib/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 0.1344 0.5 0.1344 0.5 CO 0.6933 2.58 0.0693 0.258 VOC 0.2688 1 0.1344 0.5 50000 Formaldehyde 0.1129 0.42 0.0282 0.105 75070 Acetaldehyde 0.0084 0.0313 0.0042 0.0157 107028 Acrolein 0.0051 0.0190 0.0026 0.0095 67561 Methanol 0.0025 0.0093 0.00125 0.0047 110543 n-Hexane 0.0011 0.0041 0.0006 0.0021 71432 Benzene 0.0013 0.0048 0.0006 0.0024 108883 Toluene 0.0081 0.0301 0.0041 0.0151 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8203 Btu/hp-hr, a site-rated horsepower value of 690, and a fuel heat value of 1040 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde Manufacturer Manufacturer Point 030: Emission Factors CAS # Pollutant Uncontrolled Source Natural Gas Throughput NOx 100 lb/MMscf AP-42, Chapter 1.4 CO 84 lb/MMscf AP-42, Chapter 1.4 VOC 5.5 lb/MMscf AP-42, Chapter 1.4 AIRS ID: 123/0098 Page 31 of 38 Co do D■p e o Public PollutionHealthand Control DivisionEnvironment Emission Factors CAS# Pollutant Uncontrolled Source Natural Gas Throughput 71432 Benzene 0.000748 lb/mmbtu GRI Field Data 108883 Toluene 0.00102 lb/mmbtu GRI Field Data 100414 Ethylbenzene 0.00211 lb/mmbtu GRI Field Data 1330207 Xylenes 0.00132 lb/mmbtu GRI Field Data 110543 n-Hexane 0.00176 lb/mmbtu AP-42, Chapter 1.4 50000 Formaldehyde 0.000844 lb/mmbtu GRI Field Data 75070 Acetaldehyde 0.000738 lb/mmbtu GRI Field Data 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) All engines are subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting—effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.clov/ttn/atw/area/fr18ia08.odf 8) All engines are subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines≤ 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: htto://vwvw.eoa.aovittn/atw/area/fr18ia08.odf Additional information regarding area source standards can be found on the EPA website at: htto://www.eoa.qovittn/atw/area/arearules.html 9) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: NOx, VOC, CO,formaldehyde, benzene, toluene, total HAPS NANSR Synthetic minor Source of: NOx,VOC PSD Synthetic Minor Source of: CO MACT ZZZZ Area Source Requirements: Applicable MACT HH Area Source Requirements: Not applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources AIRS ID: 123/0098 Page 32 of 38 Coll do • .p " ` e o Public Health and Environment Air Pollution Control Division NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN —Subpart XXXXXX 11) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: http://www cdphe state co.us/ap/oiloaspermittino html AIRS ID: 123/0098 Page 33 of 38 DCo do p e o Public PollutionHealthand Control DivisionEnvironment ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit(including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five(5)years and made available to the Division upon request. The owner or operator shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/0098 Page 34 of 38 0- Col do • p " e, o'Public Health and Environment Air Pollution Control Division .. ` 2.1.2 The owner or operator may permanently replace the existing compressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: http://www.colorado.qov/cs/Satellite/C DP H E-AP/CBO N/1251596520270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. AIRS ID: 123/0098 Page 35 of 38 D Co do p�r 0■ t e o Public HealthPollution andControl Environment 1■p Air Division For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology(RACT): Reg 3, Part B §II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which _ the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: - VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ 5O2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/0098 Page 36 of 38 Coldo li p me o Public Health and Environment Air Pollution Control Division The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVILE—State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500<Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § 1.8 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting AIRS ID: 123/0098 Page 37 of 38 II) Co do D■p e o Public Health and Environment 1■�_ Air Pollution Control Division requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/0098 Page 38 of 38 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Aka Energy Group, LLC Permit Number: 07WE0881 Source Location: 13472 Weld County Road 40,Weld County (non-attainment) Point 001: 4SLB engine Point 002: 4SRB engine (added to this application 12/3/13) Point 003: 4SRB engine(added to this application 12/3/13) Point 005: 4SRB engine Point 007: 4SRB engine Point 010: Plant blowdowns Point 011: 4SRB engine Point 014: Fugitive emissions Point 016: 4SRB engine Point 018: 4SRB engine Equipment Description: Point 019: 4SRB engine Point 020: 4SLB engine. Cancelled with November 6, 2013 revised application. Point 021: (1) 210 BBL above ground atmospheric condensate storage tank. Cancelled with November 6, 2013 revised application. Point 022: Crude oil truck loadout Point 023: Amine sweetening unit Point 024: Amine reboiler Point 025: Natural gas burner for thermal oxidizer Point 026: Fugitive emissions Point 028: 4SLB engine Point 029: 4SLB engine Point 030: regeneration gas heater AIRS ID: 123-0098 Date: October 22, 2012; Revised application November 6, 2013. Received new APEN for Point 030 on 1/21/2014. Review Engineer: Stephanie Chaousy, P.E. Control Engineer: Carissa Money Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt *If tank is a true minor source at a true minor facility, it shall be granted "Final Approval" Page 1 Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? Yes X No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered"no"to any of the above, 10/2212012: A general APEN was submitted for the when did you mail an Information Ioadout. I emailed the operator for a new APEN. I Request letter to the source? received a new APEN via email on 10/22/12 October 5, 2010. Revised application received 8/17/12. I sent AKA some questions on 4125/13 and received On what date was this application responses and new APENS(new point sources and revisisions)on 11/6/13. New APENS were received complete? 12/3/13 to upgrade catalysts in order to lower NOx facility-wide emissions under 90 TPY. Received a new APEN for Point 030 on January 21, 2014. Section 4—Source Description AIRS Point Equipment Description One(1) Caterpillar, Model G3516LE, Serial Number WPW01963, natural gas-fired, turbo- 001 charged, 4SLB reciprocating internal combustion engine, site rated at 1297 horsepower at 1400 RPM. This engine shall be equipped with an oxidation catalyst and air-fuel ratio control. This emission unit is used for natural gas compression. One(1)Waukesha Model F1197G, Serial Number 87655, natural gas-fired, four-cycle standard rich-burn reciprocating internal combustion engine, site rated at 166 horsepower. 002 This engine is equipped with an air-fuel ratio controller and a Non-Selective Catalytic Reduction (NSCR) system for the control of NOx, CO and VOC. This emission unit powers a natural gas compressor. One(1)Waukesha Model F1197G, Serial Number 1060271, natural gas-fired, four-cycle standard rich-burn reciprocating internal combustion engine, site rated at 166 horsepower. 003 This engine is equipped with an air-fuel ratio controller and a Non-Selective Catalytic Reduction (NSCR) system for the control of NOx, CO and VOC. This emission unit powers a natural gas compressor. One(1)White-Superior, Model 8G825, Serial Number 20220, natural gas-fired,four-cycle standard rich-burn reciprocating internal combustion engine, site rated at 708 horsepower. 005 This engine is equipped with an air-fuel ratio controller and a Non-Selective Catalytic Reduction (NSCR) system for the control of NOx and CO and VOC. This emission unit powers a natural gas compressor. One(1)Waukesha, Model L5790GSI, Serial Number C13524/1, natural gas-fired, turbo- charged, 4SRB reciprocating internal combustion engine, site rated at 1215 horsepower 007 at 1200 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR)system and air-fuel ratio control. This emission unit is used for natural gas compression. 010 VOC emissions from plant blowdown vent One(1)Waukesha, Model L7044GSI, Serial Number C-14656/1, natural gas-fired, turbo- charged, 4SRB reciprocating internal combustion engine, site rated at 1680 horsepower 011 at 1200 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. 014 Fugitive emissions from equipment leaks from existing emission components. Page 2 One (1)Waukesha, Model L5790GSI, Serial Number C13525/1, natural gas-fired, turbo- charged, 4SRB reciprocating internal combustion engine, site rated at 1215 horsepower 016 at 1200 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. One (1) Caterpillar, Model G3306TA, Serial Number TBD, natural gas-fired, turbo- 018 charged, 4SRB reciprocating internal combustion engine, site rated at 195 horsepower at 1800 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. One(1) Caterpillar, Model G3306TA, Serial Number TBD, natural gas-fired, turbo- 019 charged, 4SRB reciprocating internal combustion engine, site rated at 195 horsepower at 1800 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. 020 Cancelled with November 6, 2013 revised apptrcation. 021 Cancelled with November 6. 2013 revised aopl:cation 022 Truck loadout of condensate. Emissions from the loadout are not controlled. One (1) Diglycolamine (DGA) natural gas sweetening system for acid gas removal with a design capacity of 40 MMSCF per day (make, model, serial number: TBD). This emissions unit is equipped with six(6) electric amine recirculation pumps of which three 023 (3) are backup pumps, with a total design capacity of 150 gallons per minute. This system includes a natural gas/amine contactor, a flash tank, an amine reclaimer and a natural gas fired amine regeneration reboiler. Amine regenerator emissions are routed to a thermal oxidizer(Point 025). Flash tank emissions are 100% recycled. The reboiler is rated at 16.0 MMBtu/hr(Point 024). 024 Amine reboiler, natural gas-fired, with maximum expected rating of 16 MMBtu/hr. 025 Natural gas burner for thermal oxidizer with a maximum expected rating of 8.05 MMbtu/hr, including pilot light. 026 Fugitive emissions from equipment leaks from expansion emission components. One (1) Caterpillar, Model G3508B, Serial Number TBD, natural gas-fired, turbo-charged, 028 4SLB reciprocating internal combustion engine, site rated at 690 horsepower at 1400 RPM. This engine shall be equipped with an oxidation catalyst and air-fuel ratio control. This emission unit is used for natural gas compression. One (1) Caterpillar, Model G35086, Serial Number TBD, natural gas-fired, turbo-charged, 029 4SLB reciprocating internal combustion engine, site rated at 690 horsepower at 1400 RPM. This engine shall be equipped with an oxidation catalyst and air-fuel ratio control. This emission unit is used for natural gas compression. 030 Regenerative gas heater, natural gas-fired, with a 11.5 MMBtu/hr rating (manufacturer, model and SN: TBD). Emissions from this source are not controlled. Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria x Yes No pollutant? If"yes", for what pollutant? PM10 CO X Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B, Section III.D.2) Page 3 Is this source located in the 8-hour ozone non- attainment region?(Note: If"yes" the provisions of X Yes No Regulation 7, Sectbns XII and XVII.C may apply) Point 022: Is this source located at an oil and gas exploration site? Yes X No Point 022: Is this source located at a facility that is considered a major source of hazardous air pollutant Yes X No (HAP) emissions? Point 022: Will this equipment be operated in any X Yes No NAAQS nonattainment area Point 022: Does this source load gasoline into transport vehicles? Yes X No Section 5—Emission Estimate Information AIRS Point Emission Factor Source 001 Manufacturer: NOx, VOC, CO,formaldehyde AP-42: All others Manufacturer: NOx, VOC, CO 002 GRI Field Data: formaldehyde AP-42: All others Manufacturer: NOx, VOC, CO 003 GRI Field Data: formaldehyde AP-42: All others Manufacturer: NOx, VOC, CO 005 GRI Field Data: formaldehyde AP-42: All others Manufacturer: NOx, VOC, CO 007 GRI Field Data: formaldehyde AP-42: All others Emissions are calculated using the results of representative gas analyses and a 010 calculation of the amount of gas released during each event that the blowdown vent is used. Manufacturer: NOx, VOC, CO 011 GRI Field Data: formaldehyde AP-42: All others 014 EPA-453/R-95-017, Table 2-4 Manufacturer: NOx, VOC, CO 016 GRI Field Data: formaldehyde AP-42: All others 018 Manufacturer: NOx, VOC, CO,formaldehyde AP-42: All others 019 Manufacturer: NOx, VOC, CO,formaldehyde AP-42: All others AP-42: Chapter 5.2, Equation 1 L= 12.46*S*P*M/T 022 L= loading losses in lb per 1000 gallons loaded S = Saturation Factor P =true vapor pressure of liquid loaded [psis] M =molecular weight of vapors[lb/lb-mole] T=temperature of bulk liquid loaded[deg. R] 023 Site-specific using process simulation model. (Refer to Section 14 for calculations) 024 AP-42, Table 1.4-1 025 AP-42, Table 1.4-1 026 EPA-453/R-95-017, Table 2-4 Page 4 028 Manufacturer: NOx, VOC, CO,formaldehyde AP-42: All others 029 Manufacturer: NOx, VOC, CO, formaldehyde AP-42: All others 030 AP-42, Section 1.4, Table 1.4-1 Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit IPTE) AIRS Point Process Consumption/Throughput/Production 001 86.4 MMSCF/yr 002 13.1 MMSCF/yr 003 13.1 MMSCF/yr 005 50 MMSCF/yr 007 85.2 MMSCF/yr 010 3,500 MSCF/yr 011 112.6 MMSCF/yr Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 3822 623 1771 215 014 Flanges 1068 98 596 48 Open-Ended Lines --- Pump Seals 3 5 13 1 Valves 1847 281 1135 83 Other 41 7 4 1 016 85.2 MMSCF/yr 018 13.4 MMSCF/yr 019 13.4 MMSCF/yr 022 70,000 BBL per year condensate loaded 023 14,600 mmscf per year, natural gas throughput, 150 gallons per minute lean amine circulation rate 024 134.8 mmscf per year 025 67.8 mmscf per year Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 2514 1323 1120 174 026 Flanges 808 868 398 30 Open-Ended Lines --- 50 Pump Seals 3 11 13 1 Valves 1227 917 756 61 Other 41 7 4 1 028 47.7 MMSCF/yr 029 47.7 MMSCF/yr 030 96.87 MMSCF/yr Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 001 86.3 MMSCF/yr Page 5 002 13.1 MMSCF/yr 003 13.1 MMSCF/yr 005 49.6 MMSCF/yr 007 85.1 MMSCF/yr 010 3,500 MSCF/yr 011 112.6 MMSCF/yr Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy (or Light Liquid) Liquid) Connectors 3822 623 1771 215 014 Flanges 1068 98 596 48 Open-Ended -- Lines Pump Seals 3 5 13 1 Valves 1847 281 1135 83 Other 41 7 4 1 016 85.1 MMSCF/yr 018 13.4 MMSCF/yr 019 13.4 MMSCF/yr 022 70,000 BBL per year condensate loaded 023 14,600 mmscf per year, natural gas throughput, 150 gallons per minute lean amine circulation rate 024 134.8 mmscf per year 025 67.8 mmscf per year Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy (or Light Liquid) Liquid) Connectors 2514 1323 1120 174 026 Flanges 808 868 398 30 Open-Ended --- 50 Lines Pump Seals 3 11 13 1 Valves 1227 917 756 61 Other 41 7 4 1 028 47.7 MMSCF/yr 029 47.7 MMSCF/yr 030 96.9 MMSCF/yr Basis for Permitted Emissions(Permit Limits) AIRS Point Process ConsumptionfThroughput/Production 001 86.3 MMSCF/yr 002 13.1 MMSCF/yr 003 13.1 MMSCF/yr 005 49.6 MMSCF/yr 007 85.1 MMSCF/yr 010 3,500 MSCF/yr Page 6 011 112.6 MMSCF/yr Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy (or Light Liquid) Liquid) Connectors 3822 623 1771 215 014 Flanges 1068 98 596 48 Open-Ended --- --- --- --- Lines Pump Seals 3 5 13 1 Valves 1847 281 1135 83 Other 41 7 4 1 016 85.1 MMSCF/yr 018 13.4 MMSCF/yr 019 13.4 MMSCF/yr 022 70,000 BBL per year condensate loaded 023 14,600 mmscf per year, natural gas throughput, 150 gallons per minute lean amine circulation rate 024 134.8 mmscf per year 025 67.8 mmscf per year Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy (or Light Liquid) Liquid) Connectors 2514 1323 1120 174 026 Flanges 808 868 398 30 Open-Ended --- 50 --- --- Lines Pump Seals 3 11 13 1 Valves 1227 917 756 61 Other 41 7 4 1 028 47.7 MMSCF/yr 029 47.7 MMSCF/yr 030 96.9 MMSCF/yr Does this facility use control devices? X Yes No AIRS Point Process Control Device Description %Reduction Granted 022 01 Enclosed combustor 95 023 01 Thermal oxidizer 98 Section 6—Emission Summary (tons per year) Point NO VOC CO H2S SOx PMI0 Single HAP Total HAP 3.3 001 18.8 7.5 23.8 --- --- --- (formaldehyde) 3.9 002 18.5 0.5 24.1 --- --- --- 0.16 0.2 (formaldehyde) PTE: 003 18.5 0.5 24.1 --- ___ _-_ 0.16 0.2 (formaldehyde) 005 82.0 2.7 75.2 --- --- -- (formaldehyde) 0.9 1.2 007 129.1 9.4 93.9 --- --- --- 1.5 (formaldehyde) Page 7 010 5.3 -- -- --- 1.6 011 212.5 8.1 189.8 -- (formaldehyde)4.2 2.0 014 60.6 (n-hexane) 5.8 1.2 016 129.1 9.4 93.9 "' 1.5 (formaldehyde)0.5 018 31.1 0.7 31.1 (formaldehyde)0.5 0.5 019 31.1 0.7 31.1 -- (formaldehyde) 0.5 022 2.2 16.5 4.3 -- --- 2.0 (n-hexane) 2.7 023 0.4 152.8 1.9 2.0 3.7 --- 66.8 119.4 (benzene) 024 6.7 0.4 5.7 - - - 025 3.4 0.2 2.9 --- - 0.03 0.08 (formaldehyde) 2.9 026 38.8 - 4.0 (n-hexane)2.8 028 3.3 6.7 17.2 --- (formaldehyde)2.8 3.2 029 3.3 6.7 17.2 -- — (formaldehyde)0.1 3.2 030 4.8 0.3 4.1 --- — "' 0.4 (ethylbenzene)3.3 001 18.8 7.5 23.8 --- (formaldehyde) 3.9 002 18.5 0.5 24.1 --- _-- __ 0.16 0.2 (formaldehyde) 003 18.5 0.5 24.1 --- 0'16 0.2 (formaldehyde) 0.7 005 82.0 2.7 75.2 -- — (formaldehyde)1.2 0.9 007 129.1 9.4 93.9 -- (formaldehyde) 1.5 1.6 011 212.5 8.1 189.8 -- — 2.0 (formaldehyde) Uncontrolled point --- 4x 5 014 60.6 -- 8 2(n-hexane) ' source emission 1.2 rate: 016 129.1 9.4 93.9 --- -- (formaldehyde)0.5 1.5 018 31.1 0.7 31.1 --- — (formaldehyde)0.5 0.5 019 31.1 0.7 31.1 -- — (formaldehyde) 0.5 022 2.2 16.5 4.3 --- --- — 2.0 (n-hexane) 2.7 023 0.4 152.8 1.9 2.0 3.7 — 66.8 119.4 (benzene) 024 6.7 0.4 5.7 — 025 3.4 0.2 2.9 --- 0.03 0.08 (formaldehyde) 2.9 4.0 (n-hexane)2.8 028 3.3 6.7 17.2 -- "' (formaldehyde) 3.2 2.8 029 3.3 6.7 17.2 -- (formaldehyde) 3.2 Page 8 0.1 -030 4.8 0.3 4.1 --- --- -- (ethylbenzene) 0.4 0.8 001 18.8 1.9 1.7 --- --- -- (formaldehyde) 1.1 002 2.4 0.2 1.6 --- --- --- 0.08 0.1 (formaldehyde) 003 2.4 0.2 1.6 --- --- --- 0.08 0.1 (formaldehyde) 0.3 005 6.8 1.4 13.7 --- --- -- 0.4 (formaldehyde)0.6 007 8.2 4.7 11.7 --- --- --' 0.7 (formaldehyde) 010 5.3 --- --- 0.8 011 16.2 4.1 16.2 --- --- -- 1.0 (formaldehyde)2.0 014 28.1 2.8 (n-hexane)06 Controlled point 016 8.2 4.7 11.7 0.7 (formaldehyde) source emission 018 1.9 0.4 3.8 --- --- --- 0.2 0 3 rate: (formaldehyde) 0.2 019 1.9 0.4 3.8 --- --- --- (formaldehyde) 0.3 022 2.2 0.8 4.3 --- --- --- 0.1 (n-hexane) 0.14 023 0.4 3.1 1.9 0.04 3.7 --- 1.3 (benzene) 2.4 024 6.7 0.4 5.7 --- --- --- --- --- 025 3.4 0.2 2.9 --- --- --- 0.03 0.08 (formaldehyde) 1.4 026 18.6 1.9 (n-hexane)0.7 028 3.3 3.3 1.7 --- --- --- (formaldehyde) 0.9 0.7 029 3.3 3.3 1.7 --- --- --- 0.9 (formaldehyde)0.1 030 4.8 0.3 4.1 --- --- -- 0.4 (ethylbenzene) Section 7—Non-Criteria/ Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS# BIN Emission Rate ennsio Rate(Iblyr) (lb/yr) reportable? Point 001 Formaldehyde 50000 A 6513 Yes 1628 Acetaldehyde 75070 A 722 Yes 361 Acrolein 107028 A 444 Yes 222 Methanol 67561 C 216 No 108 n-Hexane 110543 C 96 No 48 Benzene 71432 A 112 Yes 56 Toluene 108883 C 704 No 352 Point 002 and 003 EACH Formaldehyde 50000 A 321 Yes 161 Acetaldehyde 75070 A 37 No 18 Page 9 Acrolein 107028 A 35 No. 17 Methanol 67561 C 64 No 32 Benzene 71432 A 21 No 11 Toluene 108883 C 7 No 4 Point 005 Formaldehyde 50000 A 1367 Yes 684 Methanol 67561 C 152 No 46 Acetaldehyde 75070 A 138 Yes 69 Acrolein 107028 A 131 Yes 65 Benzene 71432 A 79 Yes 39 1,3-Butadiene 106990 A 33 No 16 Toluene 108883 C 28 No 14 Point 007 Formaldehyde 50000 A 2347 Yes 1173 Methanol 67561 C 261 No 130 Acetaldehyde 75070 A 238 Yes 119 Acrolein 107028 A 224 Yes 112 Benzene 71432 A 135 Yes 67 1,3-Butadiene 106990 A 56 Yes 28 Toluene 108883 C 48 No 24 Point 011 Formaldehyde 50000 A 3245 Yes 1622 Methanol 67561 C 649 No 324 Acetaldehyde 75070 A 314 Yes 157 Acrolein 107028 A 296 Yes 148 Benzene 71432 A 178 Yes 89 1,3-Butadiene 106990 A 75 Yes 37 Toluene 108883 C 63 No 31 Point 014 Benzene 71432 A 1219 Yes 589 Toluene 108883 C 1555 Yes 753 Ethylbenzene 100414 C 0 No 0 Xylenes 1130207 C 375 No 180 n-Hexane 110543 C 8444 Yes 4094 Point 016 Formaldehyde 50000 A 2347 Yes 1173 Methanol 67561 C 261 No 130 Page 10 Acetaldehyde 75070 A 238 Yes 119 Acrolein 107028 A 224 Yes 112 Benzene 71432 A 135 Yes 67 1,3-Butadiene 106990 A 56 Yes 28 Toluene 108883 C 48 No 24 Point 018 Formaldehyde 50000 A 942 Yes 471 Methanol 67561 C 43 No 22 Acetaldehyde 75070 A 39 No 19 Acrolein 107028 A 37 No 18 Benzene 71432 A 22 No 11 1,3-Butadiene 106990 A 9 No 5 Toluene 108883 C 8 No 4 Point 019 Formaldehyde 50000 A 942 Yes 471 Methanol 67561 C 43 No 22 Acetaldehyde 75070 A 39 No 19 Acrolein 107028 A 37 No 18 Benzene 71432 A 22 No 11 1,3-Butadiene 106990 A 9 No 5 Toluene 108883 C 8 No 4 Point 022 Benzene 71432 A 560 Yes 28 Toluene 108883 C 725 No 36 Xylenes 1130207 C 165 No 8 n-Hexane 110543 C 3953 No 198 Point 023 Benzene 71432 A 133544 Yes 2671 Toluene 108883 C 99521 Yes 1990 Ethylbenzene 100414 C 299 No 6 Xylenes 1130207 C 5330 Yes 107 n-Hexane 110543 C 201 No 4 Point 024 Acetaldehyde 75070 A 103 Yes 103 Benzene 71432 A 105 Yes 105 Formaldehyde 50000 A 118 Yes 118 Toluene 108883 C 142 No 142 Page 11 Ethylbenzene 100414 C 296 No 296 Xylenes 1130207 C 185 No 185 n-Hexane 110543 C 248 No 248 Point 025 Acetaldehyde 75070 A 52 Yes 52 Benzene 71432 A 53 Yes 53 Formaldehyde 50000 A 60 Yes 60 Point 026 Benzene 71432 A 848 Yes 411 Toluene 108883 C 1076 Yes 524 Ethylbenzene 100414 C 0 Yes 0 Xylenes 1130207 C 261 No 125 n-Hexane 110543 C 5826 Yes 2839 Points 028 and 029 each Formaldehyde 50000 A 5597 Yes 1399 Acetaldehyde 75070 A 415 Yes 207 Acrolein 107028 A 255 Yes 127 Methanol 67561 C 124 No 62 n-Hexane 110543 C 55 No 28 Benzene 71432 A 65 Yes 32 Toluene 108883 C 404 No 202 Point 030 Benzene 71432 A 75 Yes 75 Toluene 108883 C 102 No 102 Ethylbenzene 100414 C 212 No 212 Xylenes 1130207 C 133 No 133 n-Hexane 110543 C 178 No 178 Formaldehyde 50000 A 86 Yes 86 Acetaldehyde 75070 A 74 Yes 74 Note: Regulation 3, Part A, Section II.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory X Yes No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 014,026 01 VOC, State only requirement Extended gas HAPS analysis Page 12 014, 026 01 VOC, State only requirement Hard Component HAPS Count 018, 019, 01 VOC NOx, CO, Regulation No. 3, Part B., Section III.G.3 Stack test 028, 029 022 of VOC Regulation No. 3, Part B, Section III.E Extended gas analysis 023 01 VOC, Regulation No. 3, Part B., Section III.G.3 Stack Test HAPS 026 01 VOC, State only requirement Extended gas HAPS analysis 026 01 VOC, State only requirement Hard Component HAPS Count Section 9—Source Classification Is this a new previously 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N W N V 0 A 0) CO C N W A CT 0) CO CO O un-permitted source? YES X X X X X X X X X X NO X X X XXX X X X What is this point classification? True Minor X X X X X X X X X X X X X X X Synthetic Minor X X X X Major What is this facility True Synthetic X Major classification? Minor Minor Classification relates to what programs? X Title V PSD X NA NSR MACT Is this a modification to an existing permit? X Yes No If"yes"what kind of modification? Minor X Synthetic Major Minor Section 10—Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes",for which pollutants?Why? VOC For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? X Yes No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 —Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards(NAAQS)? If"yes", for which pollutants?Why? NOx emissions are less than 40 TPY. AIRS Point Section 12—Regulatory Review Regulation 1 - Particulate. Smoke. Carbon Monoxide and Sulfur Dioxide Page 13 Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20%opacity. This standard is based on 24 consecutive opacity readings 001-003, taken at 15-second intervals for six minutes. The approved reference test method for 005, 007, visible emissions measurement is EPA Method 9(40 CFR, Part 60, Appendix A(July, 010, 011, 1992)) in all subsections of Section II. A and B of this regulation. 014,016, Section II.A.5-Smokeless Flare or Flares for the Combustion of Waste Gases No owner 018-030 or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. % Reouletlon.2— .Ynt?•., ..;}. = ,Y''} ; 2'4'- 001-003, Section LA- No person, wherever located, shall cause or allow the emission of odorous air 007, 005, contaminants from any single source such as to result in detectable odors which are 010, 011, measured in excess of the following limits: For areas used predominantly for residential or 014, 016, commercial purposes it is a violation if odors are detected after the odorous air has been 018-030 diluted with seven 7 or more volumes of odor free air. .. ,. : m Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: each individual emission point in a non-attainment area with uncontrolled actual emissions All of one ton per year or more of any individual criteria pollutant(pollutants are not summed) for which the area is non-attainment. (Applicant is required to file an APEN since emissions from production exceed 1 ton per year VOC) Part B-Construction Permit Exemptions All Applicant is required to file a permit since uncontrolled VOC emissions are greater than the 2.0 TPY threshold(Reg. 3, Part B, Section ILD.2.a) Part B, III.D.2- RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in 022 nonattainment or attainment/maintenance areas. This source is located in the 8-hour ozone non-attainment area, therefore, subject to RACT. The operator is using 0.6 (submerged, dedicated normal service for its saturation factor. ."t'. L YA iribaTM utS` .v8 007, 010, 011, 022, None 025, 030 NSPS KKK: Equipment Leaks of VOC from onshore natural gas processing plants. Affected facilities at onshore natural gas facilities(any processing site engaged in the extraction of natural gas liquids from field gas,fractionation of mixed natural gas 014 liquids(NGLs)or both). Is this source at a"natural gas processing plant?" Yes Is this source subject to NSPS KKK? Yes WHY? Facility is defined as a natural gas processing plant, therefore, meets the criteria of NSPS KKK. Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal 001-003, Combustion Engines (See January 18, 2008 Federal Register posting—effective March 016,018- 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control 019, 028, Commission's Regulation No. 6. 029 See Section 14 for engine review. NSPS OOOO: Each sweetening (amine)unit and each sweetening unit followed by a sulfur recovery unit; manufacturer date after August 23, 2011. Applicant is subject to NSPS OOOO because... 023 This source will have a design capacity less than 2 long tons/day H2S in the acid gas based on the information submitted in the application. This source will be required by 60.5423(c) to keep for the life of the equipment an analysis demonstrating that the facility's design capacity is less than 2 LT/D of H2S expressed as sulfur. No other requirements apply. Page 14 NSPS Dc: For boilers, reboilers and/or heaters with a construction, modification, or reconstruction commenced date after June 9, 1989 and that has a maximum design 024 heat input capacity of 29 megawatts(MW) (100 million British thermal units per hour (MMBtu/h))or less, but greater than or equal to 2.9 MW(10 MMBtu/h). The reboiler has a rating of 16 MMBtu/hr, therefore, subject to Dc. NSPS OOOO: Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution. For fugitive emissions at natural gas processing plants subject to NSPS OOOO. This subpart establishes emission standards and compliance schedules for the control of volatile organic compounds(VOC)and sulfur dioxide (SO2) emissions from affected facilities that commence construction, modification or reconstruction after August 23, 2011. 026 Is this source at a "natural gas processing plant?" Yes Is this source subject to NSPS OOOO? Yes WHY? This source is located at a natural gas processing plant with modification after August 23, 2011. An APEN modification was submitted for modifying an existing fugitive point(Point 014). The existing fugitive point is subject to NSPS KKK while the modification is subject to NSPS OOOO. A new APEN will need to be submitted to cover the modification (received 11/6/13). Regulation 7—Volatile Organic Compounds 010, 022, 023, 024 None 025, 030 001-003, 005, 007, Regulation No. 7, Section XVII.E (State only enforceable). If source is subject 011, 016, to MACT ZZZZ and NSPS JJJJ, it is not subject to Regulation 7. 018, 019, 028, 029 Section XII.G: If facility is a natural gas processing plant located in non-attainment area, then subject to Section XII.G. 014, 026 Facility is a natural gas processing plant in non-attainment area, therefore, subject to Section XII.G. Regulation 8—Hazardous Air Pollutants 010, 023, 024, 025, None 030 MACT HH: If facility is MAJOR source for HAP (summation of HAPS of dehydrators and fugitives), then fugitive emissions are subject to MACT HH. 014, 026 Is this facility considered MAJOR for HAPS? No Is this source subject to MACT HH? No WHY? Facility is area source for MACT HH, therefore, only TEG dehydrators are subject to MACT HH. This facility has no TEG dehydrators, so facility not subject to MACT HH. 001-003, Subpart ZZZZ- National Emission Standards for Hazardous Air Pollutants for 005, 007, Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register 011, 016, posting-effective March 18, 2008). 018-028, 029 See Section 14 for engine review. MACT EEEE: Organic Liquids Distribution 022 This source is not subject to MACT EEEE because it is not located at a major source of HAP. Section 13—Aerometric Information Retrieval System Coding Information Emission Pollutant/ Fugitive Emission Factor Control Point Process Process Description Factor CAS# (Y/N) Source (%) 001 01 4SLB Engine 1.5 g/hp-hr NOx No Manufacturer 0 Page 15 1.9 g/hp-hr CO No Manufacturer 75 0.6 g/hp-hr VOC No Manufacturer 93 0.26 g/hp-hr Formaldehyde No Manufacturer 75 /50000 0.0288 g/hp- Acetaldehyde No AP-42 50 hr /75070 0.0177 g/hp- Acrolein No AP-42 50 hr /107028 0.0086 g/hp- Methanol No AP-42 50 hr /67561 0.0038 g/hp- n-Hexane No AP-42 50 hr /110543 0.0045 g/hp- Benzene No AP-42 50 . hr /71432 0.0281 g/hp- Toluene No AP-42 50 hr /108883 SCC 20200254: 4-cycle lean bum 11.5 g/hp-hr NOx No Manufacturer 87 0.3 g/hp-hr VOC No Manufacturer 50 15.0 g/hp-hr CO No Manufacturer 93.3 0.1 g/hp hr Formaldehyde No GRI Field Data 50 /50000 58.02 g/hp- Acetaldehyde No AP-42 50 hr /75070 38.02 g/hp- Acrolein No AP-42 50 002 01 4SRB Engine hr /107028 and 39.02 g/hp- Methanol 003 hr /67561 No AP-42 50 42.02 g/hp- n-Hexane No AP-42 50 hr /110543 32.02 g/hp- Benzene No AP-42 50 hr /71432 68.02 g/hp- Toluene No AP-42 50 hr /108883 58.02 g/hp- Acetaldehyde No AP-42 50 hr /75070 SCC 20200253: 4-cycle rich bum N 12 g/hp-hr NOx No Manufacturer 83.3 11 g/hp-hr CO No Manufacturer 72.7 0.4 g/hp-hr VOC No Manufacturer 50 0.1 g/hp hr Formaldehyde No GRI Field Data 50 /50000 58.02 g/hp- Acetaldehyde No AP-42 50 hr /75070 01 4SRB Engine 38.02 g/hp- Acrolein No AP-42 50 005 hr /107028 39.02 g/hp- Methanol No AP-42 50 hr /67561 42.02 g/hp- n-Hexane No AP-42 50 hr /110543 32.02 g/hp- Benzene No AP-42 50 hr /71432 68.02 g/hp- Toluene No AP-42 50 hr /108883 SCC 20200253: 4-cycle rich bum 007 01 4SRB Engine 11 g/hp-hr NOx No Manufacturer 93.6 Page 16 and 8 g/hp-hr CO No Manufacturer 87.5 016 0.8 g/hp-hr VOC No Manufacturer 50 0.1 g/hp-hr Formaldehyde No GRI Field Data 50 /50000 0.0111 g/hp- Acetaldehyde No AP-42 50 hr /75070 0.0101 g/hp- Acrolein No AP-42 50 hr /107028 0.0095 g/hp- Methanol No AP-42 50 hr /67561 0.0057 g/hp- n-Hexane No AP-42 50 hr /110543 0.0024 g/hp- Benzene No AP-42 50 hr /71432 0.0020 g/hp- Toluene No AP-42 50 hr /108883 SCC 20200253: 4-cycle rich bum 01 Plant Blowdowns 0.003 lb/scf VOC No Engineering 0 010 Calculation SCC 306004002—blowdown system w/o control 13.1 g/hp-hr NOx No Manufacturer 92.4 11.7 g/hp-hr CO No Manufacturer 91.5 0.5 g/hp-hr VOC No Manufacturer 50 0.1 g/hp-hr Formaldehyde/50000 No GRI Field Data 50 29.02 g/hp- Acetaldehyde No AP-42 50 hr /75070 , 01 4SRB Engine 9.02 g/hp-hr Acrolein No AP-42 50 011 /107028 10.02 g/hp- Methanol No AP-42 50 hr /67561 13.02 g/hp- n-Hexane No AP-42 50 hr /110543 3.02 g/hp-hr Benzene No AP-42 50 /71432 39.02 g/hp- Toluene No AP-42 50 hr /108883 SCC 20200253: 4-cycle rich bum 01 Fugitive VOC Leak Emissions VOC Yes EPA-453/R-95- LDAR 014 017, Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves,flanges, connections, seals, drains) 16.5 g/hp-hr NOx No Manufacturer 94 16.5 g/hp-hr CO No Manufacturer 88 0.38 g/hp-hr VOC No Manufacturer 50 0.25 g/hp-hr Formaldehyd No Manufacturer 50 9 p e/50000 018 87.02 g/hp- Acetaldehyde No AP-42 50 and 01 4SRB Engine hr /75070 019 67.02 g/hp- Acrolein hr /107028 No AP-42 50 68.02 g/hp- Methanol No AP-42 50 hr /67561 71.02 g/hp- n-Hexane No AP-42 50 hr /110543 • 61.02 g/hp- Benzene No AP-42 50 • hr /71432 Page 17 97.02 g/hp- Toluene No AP-42 50 hr /108883 SCC 20200253: 4-cycle rich bum 11.2 lb/1000 VOC No AP-42, 5.2 95 gal 0.138 NOx No TNRCC, RG- 0 lb/mmbtu 109, Table 4 0.2755 TNRCC, RG- lb/mmbtu CO No 109, Table 4 ° 01 Truck Crude oil Loadout 0.1905 Benzene No Wt%fraction 95 022 lb/2000 gal /71432 0.2466 Toluene No Wt%fraction 95 lb/1000 gal /108883 0.0561 Xylenes/ No Wt%fraction 95 I lb/1000 gal 1130207 1.3446 N-hexane No Wt%fraction 95 lb/1000 gal /110543 SCC 4060132: Crude Oil: Submerged Loading (Normal Service) 20.9lb/mmsd VOC No Process 98 Simulation 0.1 lb/MMBtu NOx No TNRCC 0 0.53 CO No TNRCC 0 lb/MMBtu 9.151b/mmsd Benzene No Process 98 /71432 Simulation 01 Amine unit Toluene Process 023 6.82lb/mmsd /108883 No Simulation 98 0.02lb/mmsd Ethylbenzene No Process 98 /100414 Simulation 0.37 lb/mmscf Xylenes/ No Process 98 1130207 Simulation 0.014 N-hexane No Process 98 lb/mmscf /110543 Simulation SCC 31000305—Gas Sweetening; Amine process 5.5 lb/mmscf VOC No AP-42, Table 1.4-1 1.4-1 100 lb/mmscf NOx No AP-42, Table 0 1.4-1 84 Ib/mmscf CO No AP-42,Table 1.4-1 01 Amine Reboiler 1.4 1 024 0.000738 Acetaldehyde No GRI Field Test lb/mmbtu /75070 Data ° 0.000748 Benzene GRI Field Test No 0 lb/mmbtu /71432 Data 0.000844 Formaldehyde No GRI Field Test ° lb/mmbtu /50000 Data SCC 10200602: 10-100 Million btu/hr 5.5 lb/mmscf VOC No AP-42,Table 0 1.41 100 lb/mmscf NOx No AP-42,Table 0 1.4-1 AP-42,Table 84 lb/mmscf CO No 1.4-1 0 01 Natural gas burner 0.000738 Acetaldehyde No GRI Field Test ° 025 lb/mmbtu /75070 Data 0.000748 Benzene GRI Field Test lb/mmbtu /71432 No Data ° 0.000844 Formaldehyde GRI Field Test lb/mmbtu /50000 No Data ° SCC 10200602: 10-100 Million btu/hr Page 18 EPA-453/R-95- LDAR 01 Fugitive VOC Leak Emissions VOC Yes 017, Table 2-4 026 SCC 31000220: All Equip. Leak Fugitives(Valves,flanges, connections, seals, drains) 0.5 g/hp-hr NOx No Manufacturer 0 2.58 g/hp-hr CO No Manufacturer 90 1 g/hp-hr VOC No Manufacturer 50 0.42 g/hp-hr Formaldehyde/50000 ormaldehyde50000 No Manufacturer 75 103.02 g/hp- Acetaldehyde No AP-42 50 hr /75070 01 4SLB Engine 104.02 g/hp- Acrolein No AP-42 50 028 hr /107028 118.02 g/hp- Methanol No AP-42 50 hr /67561 120.02 g/hp- n-Hexane No AP-42 50 hr /110543 105.02 g/hp- Benzene No AP-42 50 hr /71432 128.02 g/hp- Toluene No AP-42 50 hr /108883 SCC 20200254: 4-cycle lean bum 0.5 g/hp-hr NOx No Manufacturer 0 2.58 g/hp-hr CO No Manufacturer 90 1 g/hp-hr VOC No Manufacturer 50 Formaldehyde 0.42 g/hp-hr /50000 No Manufacturer 75 103.02 g/hp- Acetaldehyde No AP-42 50 hr /75070 01 4SLB Engine 104.02 g/hp- Acrolein No AP-42 50 029 hr /107028 118.02 g/hp- Methanol No AP-42 50 hr /67561 120.02 g/hp- n-Hexane No AP-42 50 hr /110543 105.02 g/hp- Benzene No AP-42 50 hr /71432 128.02 g/hp- Toluene No AP-42 50 hr /108883 SCC 20200254: 4-cycle lean bum 5.5 lb/mmscf VOC No AP-42,Table 0 1.4-1 100 AP-42, Table Ib/mmscf NOx Na 1.4-1 0 84 Ib/mmscf CO No AP-42, Table 0 1.4-1 0.000748 Benzene No GRI Field Data 0 lb/mmbtu /71432 0.00102 Toluene No GRI Field Data 0 lb/mmbtu /108883 030 01 Regenerative gas heater 0.00211 Ethylbenzene No GRI Field Data 0 lb/mmbtu /100414 0.00132 Xylenes/ No GRI Field Data 0 lb/mmbtu 1130207 0.00176 N-hexane AP-42, Table lb/mmbtu /110543 No 1.4-1 0 0.000844 Formaldehyde No GRI Field Data 0 lb/mmbtu /50000 0.000738 Acetaldehyde No GRI Field Data 0 lb/mmbtu /75070 Page 19 10200602: 10-100 Million Btu/hr SCC Based on a fuel content of 1040 btu/scf Section 14—Miscellaneous Application Notes AIRS Point 001 RICE Engine Operator requested to revise the VOC limit and to control formaldehyde(75%)and all other HAPS(50%). Construction date on APEN was 5/2008. Since commencement of construction was after June 12, 2006, this engine is subject to MACT ZZZZ. Manufacturer date was given as 1/24/2008. Since it was constructed after 1/1/2008, it is subject to NSPS JJJJ. AIRS Point 002 RICE Engine A new APEN for this point was received 12/3/13 (was not originally included with application)with an upgraded catalyst to lower facility-wide NOx emissions less than 90 TPY. A check was also included at this time. Since commencement of construction was prior to June 12, 2006, this engine is not subject to MACT 7777. Manufacturer date was given as before 7/1/2007. Since it was constructed before 7/1/2007, it is not subject to NSPS JJJJ. AIRS Point 003 RICE Engine A new APEN for this point was received 12/3/13 (was not originally included with application)with an upgraded catalyst to lower facility-wide NOx emissions less than 90 TPY. A check was also included at this time. Since commencement of construction was prior to June 12, 2006, this engine is not subject to MACT ZZZZ. Manufacturer date was given as before 7/1/2007. Since it was constructed before 7/1/2007, it is not subject to NSPS JJJJ. AIRS Point 007 RICE Engine Operator requested to revise the VOC limit and to control VOC and all HAPS(50%). Construction date on APEN was before 6/12/2006. Since commencement of construction was prior to June 12, 2006, this engine is not subject to MACT ZZZZ. Manufacturer date was given as before 7/1/2007. Since it was constructed before 7/1/2007, it is not subject to NSPS JJJJ. AIRS Point 005 RICE Engine Application originally replaced this point for point 017 (because it was not a like-kind AOS replacement). However, after discussion with the consultant, Point 005 was eventually replaced with a like-kind (one wasn't available right away, but they did find a replacement eventually)and Point 017 was never needed. I had the consultant cancel Point 017. I had to convert the PA and permit all Point 017 references back to Point 005. A new APEN was received 12/3/13 for this point in order to lower facility-wide NOX emissions below 100 TPY. Construction date on APEN was before 6/12/2006. Since commencement of construction was prior to June 12, 2006, this engine is not subject to MACT ZZZZ. Manufacturer date was given as before 7/1/2007. Since it was constructed before 7/1/2007, it is not subject to NSPS JJJJ. I received a cancellation notice from AKA on December 23, 2013 for Point 017 via email (I forwarded it on to Paul and put a copy in the application attached to the APEN). A new APEN for this point was received 12/3/13 with an upgraded catalyst to lower facility-wide NOx emissions less than 90 TPY. AIRS Point 010 Plant blowdowns Vent gas density based on a conservative estimate of specific gravity(0.8 based on a historical review of residue gas samples) and 0.0749 lb/scf of air. VOC emissions based on T/yr of total gas vented and a conservative estimate of VOC content(5% by weight, based on a historical review of residue gas samples). Vent gas density=0.8 *0.0479= 0.0599 lb/scf VOC= (3,500,000 SCF/yr)•0.6/2000= 105 TPY*0.05= 5.25 TPY VOC E.F. = (5.25 TPY*2000/3500000 scf/yr)= 0.003 lb/SCF AIRS Point 011 RICE Engine Operator requested to revise the VOC limit and to control VOC and all HAPS(50%). Construction date on APEN was before 6/12/2006. Since commencement of construction was prior to June 12, 2006, this engine is not subject to MACT ZZZZ. Manufacturer date was given as before 7/1/2007. Since it was constructed before 7/1/2007, it is not subject to NSPS JJJJ. Page 20 AIRS Point 014 Fugitive Emissions A permit will be issued because the uncontrolled VOC emissions are greater than 1 TPY(APEN threshold)and TOTAL FACILITY is greater than 2 TPY(permit threshold). Facility is subject to NSPS KKK LDAR program,which satisfies RACT requirements. There was not an O&M plan included with the application. Since it is being controlled with an LDAR program, I feel it's appropriate to have a fugitive O&M as well. I emailed the operator on 10/23/12 requesting an O&M plan. I am requiring initial testing again(extended gas analysis and hard component count) because 8 new point sources have been added to the facility and the APEN showed"estimated count," not a hard count. Operator originally combined new fugitive emissions as a modification of existing fugitives. This was not appropriate because the original fugitive point source is subject to NSPS KKK while the new fugitives at the facility will be subject to NSPS 0000. I requested the operator to separate the new from the existing and provide a new APEN. The operator provided a new APEN for the new fugitives but also requested to modify the emissions for the existing fugitives(Point 014). The operator calculated the emissions based on the different streams coming into the plant and the fugitives associated with these streams. Group 1: Wet gas,condensate, engine oil and other heavy liquids Stream VOC Benzene Toluene Ethyl- Xylene n- O ii o t < 0 (wt%) (wt%) (wt%) benzene (wt%) hexane =oEr N 3 °i (wt%) (wt%) N w -OCD CDZ y N O N O "t/1 Gas 25 0.1 0.1 0 0.05 0.5 1136 442 0 780 16 Heavy 100 1.7 2.2 0 0.5 12 561 86 5 244 7 Liquid Light 100 1.7 2.2 0 0.5 12 1729 596 13 1114 4 Liquid Water/Oil 100 1.7 2.2 0 0.5 12 215 48 1 83 1 Group 2: Dr/Gas Stream VOC Benzene Toluene Ethyl- Xylene n- n m < 0 (wt%) (wt%) (wt%) benzene (wt%) hexane 0 5 (wt%) (wt%) N o e a co O N Gas 5 -- --- -- -- --- 2091 488 770 25 Heavy -- -- --- -- --- --- --- --- --- -- Liquid Light -- -- --- --- --- --- --- --- --- -- Liquid Water/Oil -- -- --- --- --- --- --- --- -- -- Group 3: Propane refrigerant, methanol, antifreeze Stream VOC Benzene Toluene Ethyl- Xylene n- co -n w v < (wt%) (wt%) (wt%) benzene (wt%) hexane > ≥ 3 to m tn O N O N Gas 100 --- --- --- --- -- 595 138 3 297 Heavy 100 -- --- --- --- --- 62 12 0 37 Liquid Light 100 -- -- --- --- --- 42 0 0 21 Liquid • Water/Oil 100 -- -- --- --- --- --- --- --- --- Section 05 on the APEN was not filled out because there are different constituents for each stream. Operator did not list the emissions as uncontrolled,just included the LDAR controlled emissions under both uncontrolled and controlled. I emailed the consultant on 11/14/13 with my calculations to let him know that uncontrolled should be listed on the APENS. If he agrees, I will just redline the APEN. He confirmed this on 11/15/13. Page 21 AIRS Point 016 RICE Engine Operator requested to revise the VOC limit and to control VOC and all HAPS (50%). Construction date on APEN was before 6/12/2006. Since commencement of construction was prior to June 12, 2006, this engine is not subject to MACT ZZZZ. Manufacturer date was given as before 7/1/2007. Since it was constructed before 7/1/2007, it is not subject to NSPS JJJJ. AIRS Point 018 RICE Engine Operator requested a new engine. Construction date on APEN was before 6/12/2006. Since commencement of construction was prior to June 12, 2006, this engine is not subject to MACT ZZZZ. Manufacturer date was given as before 7/1/2007. Since it was constructed before 7/1/2007, it is not subject to NSPS JJJJ. AIRS Point 019 RICE Engine Operator requested a new engine. Construction date on APEN was before 6/12/2006. Since commencement of construction was prior to June 12, 2006, this engine is not subject to MACT ZZZZ. Manufacturer date was given as before 7/1/2007. Since it was constructed before 7/1/2007, it is not subject to NSPS JJJJ. AIRS Point 022 Truck condensate Loadout Units Basis S 0.6 Submerged loading: dedicated normal service P 10.4 Psia Sum of partial pressures of individual constituents per Raoult's Law M 74.98 Lb/lb-mole Calculated based on mole %of individual constituents in condensate vapors. T 520.36 Deg R Based on EPA TANKs run L 11.2 Lb/10^3 gal 0.47 Lb/bbl This value is used to calculate annual emissions AP-42: Chapter 5.2 Equation 1 L= 12.46*S*P*M/T L= loading losses in lb per 1000 gallons loaded S =Saturation Factor P =true vapor pressure of liquid loaded [psia] M =molecular weight of vapors[lb/lb-mole] T=temperature of bulk liquid loaded [deg. R] L 11.201b/10^3 gal 4.71 E-011b/bbl Annual requested Throughput 2940000ga1/yr Annual requested VOC emissions 329381b/yr 16.47tpy Benzene= (560 lb/yr)/(70000) = 0.008 lb/bbl * 1000/42 = 0.1905 lb/1000 gal Toluene= (725 Ib/yr)/(70000) = 0.0104 lb/bbl * 1000/42 = 0.2466 lb/1000 gal Xylenes= (165 lb/yr)/(70000)= 0.0024 lb/bbl * 1000/42= 0.0561 lb/1000 gal n-hexane= (3953 Ib/yr)/(70000) = 0.0565 lb/bbl * 1000/42 = 1.3446 lb/1000 gal Page 22 AIRS Point 023 Amine Unit A permit will be issued because the uncontrolled VOC emissions are greater than 2 (permit threshold). The table below summarizes the inputs to the process simulation used to calculate the PTE for this equipment. TABLE 1 Parameter Inlet Gas Rich Amine Lean Amine Flash Tank Feed Stream Pressure(psia) 893 psig 30 913 63 Temperature(°F) 100 221 115 174 NOx and CO emissions were generated from TNRCC emission factors. NOx = 0.1 lb/mmbtu and CO= 0.53 lb/mmbtu Uncontrolled emission factor calculations using process simulation model: VOC= 152.8*2000/14600 mmscf/yr=20.9 Ib/mmscf(matches APEN) Benzene = 133544/14600 = 9.15 lb/mmscf(matches APEN) Toluene= 99521/14600= 6.82 lb/mmscf(matches APEN) Ethylbenzene= 299/14600 = 0.02 lb/mmscf(matches APEN) Xylenes= 5330/14600 = 0.37 lb/mmscf(matches APEN) n-hexane= 201/14600 = 0.014 lb/mmscf(matches APEN) I emailed the operator on 10/23/12 how many pumps(gas or electric) does the amine unit have? Looking at the model, it looks like 1 electric pump. Also, what is the name of the simulation model used for the analysis? We typically see Promax or HYSYS, and this doesn't look familiar. Does this amine unit have a reboiler?Yes If Yes, what is the reboiler rated? 16 mmbtu/hr The source has a desi n rate greater than 5 mmbtu/hr. See Point 024. AIRS Point 024 Amine Reoilber A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY(permit threshold). Emission factors from AP-42 and GRI Field Test Data. AIRS Point 025 Natural gas burner A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY (permit threshold). Emission factors from AP-42 and GRI Field Test Data. Page 23 AIRS Point 026 Fugitive Emissions . A permit will be issued because the uncontrolled VOC emissions are greater than 1 TPY(APEN threshold) and TOTAL FACILITY is greater than 2 TPY(permit threshold). Source is non-attainment, and therefore, subject to RACT. Facility is subject to NSPS OOOO LDAR program,which satisfies RACT requirements. There was not an O&M plan included with the application. Since it is being controlled with an LDAR program, I feel it's appropriate to have a fugitive O&M as well. I em ailed the operator on 10/23/12 requesting an O&M plan. Operator originally combined new fugitive emissions as a modification of existing fugitives. This was not appropriate because the original fugitive point source is subject to NSPS KKK while the new fugitives at the facility will be subject to NSPS OOOO. I requested the operator to separate the new from the existing and provide a new APEN. The operator provided a new APEN for the new fugitives but also requested to modify the emissions for the existing fugitives(Point 014). The operator calculated the emissions based on the different streams coming into the plant and the fugitives associated with these streams. Group 1: Wet gas, condensate, engine oil and other heavy liquids Stream VOC Benzene Toluene Ethyl- Xylene n- (wt%) (wt%) (wt%) benzen (wt%) hexane o y m e CO 5 e(wt%) (wt%) N N (fit m P. N o N Gas 25 0.1 0.1 0 0.05 0.5 844 348 0 587 16 Heavy 100 1.7 2.2 0 0.5 12 497 68 5 184 7 Liquid Light 100 1.7 2.2 0 0.5 12 1090 398 13 741 4 Liquid Water/Oil 100 1.7 2.2 0 0.5 12 174 30 1 61 1 Group 2: Dry Gas Stream VOC Benzene Toluene Ethyl- Xylene n- (wt%) (wt%) (wt%) benzene (wt%) hexane�p o m O yst ( %) (wt l0) CD fD N a N FA Gas 25 0.1 0.1 0 0.05 0.5 1294 364 770 25 Heavy 100 -- -- -- -- — -- -- -- -- Liquid Light 100 -- -- -- -- • — -- -- -- -- Liquid Water/Oil 100 -- -- -- -- -- -- — -- Group 3: Propane refrigerant, methanol, antifreeze Stream VOC Benzene Toluene Ethyl- Xylene n- (wt%) (wt%) (wt%) benzene (wt%) hexane o > m 3 3 < a N N Gas 25 0.1 0.1 0 0.05 0.5 356 70 3 124 Heavy 100 - -- -- - -- 26 0 0 13 Liquid Light 100 -- -- -- -- - 30 0 0 15 Liquid WaterfOil 100 -- -- -- — — -- -- -- — Page 24 AIRS Point 026 Fugitives continued Group 4: Amine plant Stream VOC Benzene Toluene Ethyl- Xylene n- n ,m in v < o O (wt%) (wt%) (wt%) benzene (wt%) hexane > ≥ m 3 <CD CD m (7 o O N 0 Gas 25 0.5 as 0.005 0.10 1.5 20 20 0 15 0 Heavy 50 0.05 0.05 0.0001 0.001 0.001 800 800 6 720 50 Liquid Light 50 0.05 0.05 0.0001 0.001 0.001 -- --- --- --- -- Liquid Water/Oil 50 0.05 0.05 0.0001 0.001 0.001 -- --- -- -- -- Section 05 on the APEN was not filled out because there are different constituents for each stream. Operator did not list the emissions as uncontrolled,just included the LDAR controlled emissions under both uncontrolled and controlled. I emailed the consultant on 11/14/13 with my calculations to let him know that uncontrolled should be listed on the APENS. If he agrees, I will just redline the APEN. He confirmed this on 11/15/13. AIRS Point 028 RICE Engine Operator requested the addition of this engine on 11/6/13. Construction date on APEN was after 6/12/13. Since commencement of construction was after June 12, 2006, this engine is subject to MACT ZZZZ. Manufacturer date was given as after 6/12/2006. Since it was constructed after 1/1/2008, it is subject to NSPS JJJJ. AIRS Point 029 RICE Engine Operator requested to revise the VOC limit and to control formaldehyde (75%) and all other HAPS (50%). Construction date on APEN was 5/2008. Since commencement of construction was after June 12, 2006, this engine is subject to MACT ZZZZ. Manufacturer date was given as 1/24/2008. Since it was constructed after 1/1/2008, it is subject to NSPS JJJJ. AIRS Point 030 Regenerative gas heater A permit will be issued because the uncontrolled NOx emissions are greater than 1 TPY(APEN threshold)and TOTAL FACILITY is greater than 5 TPY(permit threshold). This APEN was submitted as a last minute change from the operator. The division received the APEN and supporting calculations via email on 1/21/2014. I modified the PA, history file and permit accordingly. Facility Page 25 I emailed the operator a 30+hour letter on 10/19/12. A copy of the letter is in the package. I emailed the operator on 4/25/13 some questions after supervisor review of the draft permit. I received responses and new APENS on 11/6/13. Responses are in italics: 1. For the amine APEN: The H2S and SOX is greater than the 1 TPY/2 TPY threshold, so could you please fill out the addendum APEN for H2S and SOx? The requested APEN addendum is attached(see Attachment 1). 2. The fugitives: Since the modification is after August 23, 2011,the modification is actually subject to NSPS OOOO while the existing fugitives(Point 014)is subject to NSPS KKK. It is really confusing because this is a situation where you will have to have 2 fugitive point sources at the site, one subject to KKK and the other OOOO. I am assuming that Point 014 therefore does not need modification(and does not need to be revised in this application modification), and a new APEN will need to be submitted as a new point for the modification. Could you please submit a new APEN for the modification so that each point will have its correct requirements? I will only need to verify from you what the permitted emissions were and the component hard count was for Point 014 so I can correctly update it back to its original in the permit. I am assuming a hard component count was already done for Point 014, so that can be used and whatever is left would be put on the new APEN. We have attached the APEN and supporting information as requested for OOOO leaks, but also are requesting modification of the existing KKK leaks APEN. (It was necessary to refine these emission calculations in order to stay below 20 TPY HAP, in aggregate, on a facility-wide basis. An APEN and supporting documentation for the KKK leaks is also attached, with an updated FORM-102, Facility-wide Emission Inventory(see Attachment 2). 3. For the 210 bbl condensate tank: we did have some discussions about XII, however, we think this tank is subject to Regulation 7, Section XII.G.5.a. The uncontrolled emissions are greater than 2 TPY,therefore, subject to this section. Please review and let me know your thoughts. AKA has decided to cancel the APEN request for the atmospheric condensate tank and to instead use the existing pressurized condensate system at the facility to handle the condensate generated from the expansion. AKA has therefore revised the loadout APEN already submitted for the expansion by increasing the requested throughput to account for existing and proposed operations and to add a combustion device to control emissions from this source. (A revised process description is attached to account for this change). Please process this loadout APEN instead of the one submitted during July 2012(see Attachment 3). 4. If you could please provide some documentation stating that the project is a minor modification for CO2. The Gilcrest expansion will not trigger TV or NSR review for GHG emissions. The existing facility emits< 100,000 TPY CO2e and is therefore not considered a major source of GHG emissions with respect to the TV and NSR programs. The proposed expansion will also emit< 100,000 TPY CO2e and is also therefore not considered a major source of GHG emission with respect to the TV and NSR programs. Post- modification GHG emissions will exceed 100,000 TPY CO2e, however, and future modifications to the facility will need to be evaluated to determine if the modification is significant(i.e., emits>75,000 TPY CO2e). Supporting calculations are provided in Attachment 4. AKA is also proposing to install two(2) Caterpillar G3508LE compressor engines instead of the Caterpillar G35208 engine originally proposed in order to increase operational flexibility for the facility. We have therefore included an APEN for each of these engines as well as an updated O&M plans for the engines at the facility. I made the changes accordingly to the PA, permit,APENS and history file. I requested cancellation letters for Point 021 (condensate tank)and engine(Point 020)on 11/14/13. December 3,2013 from consultant/operator: As we have discussed, Aka is proposing to upgrade the catalysts on units C3, C6 and C7 at the Gilcrest facility to lower facility-wide NOX emissions below 90 TPY. Attached,please find a scan of original materials sent to you today via Fed Ex, including revised APEN for C3, C6, and C7, as well as a cancellation notice for Point 015(a hot oil heater that is not functional and is to be removed from service). A revised facility-wide emission inventory(APCD Form 102)and an APEN check($152.90 x 3=$458.70)are also provided. Page 26 • a. I o a s o o — z pp — W 'S T O a ryW m o a N N N C .. E .2 i CO p 8 a O 2 c. ¢s v u u or ° . a, c=7 a ❑ ,o o cL1 " °' E men fn c n o o N C w y o 8' u o W U o e e e— y o a o N u o o. U y P. -Ti.; a `o `o N a d `o and m`•ao o "> E .°o ova I h v Pei % u ^ > o «ti; c S a o ' Z p g u U o g a d 5 0 0 'u `n p W P.y. A o t W . 0 y s a m Vi m . 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