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Home My WebLink About20162605.tiffCDPHE COLORADO Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 11500 St PO Box 758 Greeley, CO 80632 July 29, 2016 Dear Sir or Madam: r'� }'}e'�� i $"iEC I Y'i EC) AUG 0 5 2016 On August 4, 2016, the Air Pollution Control Division will begin a 30 -day public notice period for Aka Energy Group, LLC - Gitcrest Gas Plant. 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 beginning of the public notice period. Please send any comment regarding this public notice to the address below. Regards, 444_ /i Colorado Dept. of Public Health ft Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure PObliC R-vieW 4300 Cherry Creek Drive S.. Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe '7 1 S I CO John W. Hickentooper, Governor Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer CC- PLC TP) , Wc. C PG) Pw C E.R/ CH t Sm) St ! `62'/ 30 CO 2016-2605 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Aka Energy Group, LLC - Gilcrest Gas Plant - Weld County Notice Period Begins: August 4, 2016 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: Existing natural gas processing plant modifying permit limits for hydrocarbon loadout, modifying limits for one (1) existing reciprocating internal combustion engine and adding two (2) new reciprocating internal combustion engines. In addition permit is requesting the addition of one (1) triethylene glycol (TEG) dehydrator with new synthetic minor limits. 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): • 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 https://www.colorado.gov/pacific/cdphe/air-permit-public-notices 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: Bradley Eades Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us 1 I c 7 cocoa on STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 PERMIT NO: 07WE0881 CONSTRUCTION PERMIT Issuance 2 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 Equipment ID AIRS Point Description C-1 001 One (1) Caterpillar, Model G3516LE, Serial Number WPW01963, natural gas -fired, turbo -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. C-6 002 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. 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. C-7 003 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. 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 36 NGEngine Version 2012-1 of Public Health and Environment Air Pollution Control Division Facility Equipment ID Point Description C-3 005 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. 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 is used for natural gas compression. This emission unit may be used interchangeably with point 033 and emission limits contained in this permit are combined for these points. C-4 007 One (1) Waukesha, Model L5790GSI, Serial Number C13524/1, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1215 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 C-2 011 One (1) Waukesha, Model L7044GS1, Serial Number C- 14656/1, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1680 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 subject to NSPS subpart KKK. C-5 016 One (1) Waukesha, Model L5790GS1, Serial Number C13525/1, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1215 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. LOADOUT 022 Truck loadout of condensate. Emissions from the loadout are uncontrolled and are routed to the plant vent. LEAKS (OOOO) 026 Fugitive emissions from equipment leaks subject to NSPS subpart OOOO. AIRS ID: 123/0098 Page 2 of 36 Public Health and Environment Air Pollution Control Division Facility Equipment ID Point Description DEHY 031 One (1) triethylene glycol (TEG) dehydrator unit with a design capacity of 50 MMscf/day (Exterran, Model: TBD, serial number: TBD). This emissions unit is equipped with two (2) electric Rotor Tech glycol pumps (one (1) primary and one (1) backup) with a maximum capacity of 10 gallons per minute. This system includes a Jetco BTEX condenser, reboiler, still vent, and a flash tank. The flash tank emissions will be recycled in a closed loop system that utilizes a vapor recovery unit (VRU), or routed to an enclosed combustion device (ECD) which achieves a minimum of 95% control efficiency. The still vent emissions are routed to a condenser and then to an enclosed combustor with a minimum destruction efficiency of 95%. C-8 032 One (1) Caterpillar, Model G3516TALE, Serial Number TBD, natural gas -fired, turbo -charged, 4SLB reciprocating internal combustion engine, site rated at 1340 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. C-3 033 One (1) Caterpillar, Model G3508B, Serial Number TBD, natural gas -fired, turbo -charged, 4SLB reciprocating internal combustion engine, site rated at 690 horsepower. This engine shall be equipped with an oxidation catalyst and air - fuel ratio control This emission unit is used for natural gas compression. This emission unit may be used interchangeably with point 005 and emission limits contained in this permit are combined for these points. Points 001, 002, 003, 005, 007, 011, 016, 032, 033: 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 seq) 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. 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. AIRS ID: 123/0098 Page 3 of 36 of Public Health and Environment Air Pollution Control Division 2. Within one hundr 'ei. '' d'= 8= latt commencement of operation or 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. A self certification form and guidance on how to self - certify compliance as required by this permit may be obtained online at www.colorado.qov/pacific/cdphe/air-permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 3. 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.) 4. 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.) 5. Point 031: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of permit. • 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.) 6. Points 032, 033: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of permit. • manufacture date • construction date • order date • date of relocation into Colorado • 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 AIRS ID: 123/0098 Page 4 of 36 of Public Health and Environment Air Pollution Control Division 8. Emissions of air pa is I , c ollo 5r limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Monthly Limits: Facility Equipment ID AIRS Point Pounds per Month Emission Type SO, H2S NO, VOC CO C-3 005 --- --- 1156 476 2328 Point 033 Point LOADOUT 022 --- --- --- 1003 --- Point DEHY 031 --- --- 272 2548 544 Point C-8 032 --- --- 4400 578 2362 Point (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 4077 lb/month. Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type SO, H2S NO, VOC CO 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 2.8 13.7 Point C-3 033 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 LOADOUT 022 --- --- --- 5.9 --- Point LEAKS (OOOO) 026 --- --- --- 18.6 --- Fugitive DEHY 031 --- --- 1.6 15.0 3.2 Point C-8 032 --- --- 25.9 3.4 13.9 Point See "Notes to Permit Holder' for information on emission fac ors and methods used to calculate limits. Limits listed above for AIRS Point 005 & 033 apply to the summation of emissions from both points AIRS ID: 123/0098 Page 5 of 36 of Public Health and Environment Air Pollution Control Division Facility -wide emis = = of --' " . .u_•'I dou pollutant shall be less than 8.0 tons per year (tpy). Facility -wide emissions of total hazardous air pollutants shall be less than 24.0 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. 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 owner or operator shall track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility potential emission limitations as indicated below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. (Reference: Regulation 3, Part C. II.E.) Total potential emissions from the facility, including all permitted emissions and potential to emit from all insignificant activities, shall be less than: • 100 tons per year of NOx; and • 25 tons per year of total hazardous air pollutants (HAP) 10. Point 031: Compliance with the emission limits in this permit shall be demonstrated by running the GRI GlyCalc model version 4.0 or higher on a monthly basis using the most recent wet gas analysis and recorded operational values (including gas throughput, lean glycol recirculation rate and other operational values specified in the O&M Plan). Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into GRI GlyCalc and be provided to the Division upon request. 11. Points 005 and 033: Compliance with the emission limits in this permit shall be demonstrated using the emission factors in the "notes to permit holder". Emissions shall be calculated for each engine based on their respective emission factors, manufacturer - provided fuel consumption and actual hours of operation. The total combined emissions from both engines shall be used to demonstrate compliance with the limits in this permit. 12. 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 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. AIRS ID: 123/0098 Page 6 of 36 olo D- atmen of Public Health and Environment Air Pollution Control Division 13. The emission point ., _ e,, r- m.. s* : sper ss 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 Equipment ID AIRS Point Control Device Pollutants Controlled C-1 001 Oxidation catalyst and air/fuel ratio controller VOC, CO and HAPS C-6 002 Non -Selective Catalytic Reduction (NSCR) and air/fuel ratio controller NOx, VOC, CO and HAPS C-7 003 Non -Selective Catalytic Reduction (NSCR) and air/fuel ratio controller NOx, VOC, CO and HAPS C-3 005 Non -Selective Catalytic Reduction (NSCR) and air/fuel ratio controller NOx, VOC, CO and HAPS C-4 007 Non -Selective Catalytic Reduction (NSCR) and air/fuel ratio controller NOx, VOC, CO and HAPS C-2 011 Non -Selective Catalytic Reduction (NSCR) and air/fuel ratio controller NOx, VOC, CO and HAPS LEAKS (KKK) 014 LDAR VOC, HAPS C-5 016 Non -Selective Catalytic Reduction (NSCR) and air/fuel ratio controller NOx, VOC, CO and HAPS LEAKS (OOOO) 026 LDAR VOC, HAPS DENY 031 Flash Tank: Recycled via closed loop with VRU or routed to an enclosed combustor during VRU downtime VOC, HAPS Still Vent: Routed to a condenser and enclosed combustor C-8 032 Oxidation Catalyst VOC, CO and HAPS C-3 033 Oxidation Catalyst VOC, CO and HAPS PROCESS LIMITATIONS AND RECORDS 14. 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) 15. Process/Consumption Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 days) C-1 001 Consumption of natural gas as a fuel 86.3 MMscf/yr AIRS ID: 123/0098 Page 7 of 36 of Public Health and Environment Air Pollution Control Division C-6 002 Consump ion of na ura gas as a uel 13.1 MMscf/yr --- C-7 003 Consumption of natural gas as a fuel 13.1 MMscf/yr C-3 005 Consumption of natural gas as a fuel 49.7 MMscf/yr 4.3 MMscf/month C-3 033 C-4 007 Consumption of natural gas as a fuel 85.1 MMscf/yr --- V-50 010 Total volume of residue gas vented due to maintenance activities 3.5 MMscf/yr C-2 011 Consumption of natural gas as a fuel 112.6 MMscf/scf/yr C-5 016 Consumption of natural gas as a fuel 85.1 MMscf/yr LOADOUT 022 Condensate Loading 50,000 BBL/yr 4246.6 BBL/month DENY 031 Natural gas throughput 18,250.0 MMscf/yr 1550.0 MMscf/month C-8 032 Consumption of natural gas as a fuel 90.4 MMscf/yr 7.7 MMscf/month The owner or operator shall calculate monthly process rates based on the calendar month. 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. 16. Points 005 and 033: Compliance with the process limits in this permit shall be demonstrated using the manufacturer -provided fuel consumption and actual hours of operation for each engine respectively. The total combined fuel consumption for both engines shall be used to demonstrate compliance with the limits in this permit. 17. Point 031: This source shall be limited to a maximum lean glycol recirculation pump rate as calculated per 40 CFR, Part 63, Subpart HH, §63.764 (d)(2)(i). If the owner or operator requests an alternate circulation rate per §63.764(d)(2)(ii), then the maximum recirculation rate shall not exceed 10 gallons per minute. The owner or operator shall maintain monthly records of the actual lean glycol recirculation rate and make them available to the Division for inspection upon request. STATE AND FEDERAL REGULATORY REQUIREMENTS 18. 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) AIRS ID: 123/0098 Page 8 of 36 of Public Health and Environment Air Pollution Control Division 19. Points 001, 002, , 0 X22, 026, 032, and 033: 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.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) 20. 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, 032 and 033) 21. Points 001, 032 and 033: 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. 22. 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. 23. Points 001, 005, 007, 011 016: 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 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. 24. Points 001, 005, 007, 011 016, 032, 033: 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: AIRS ID: 123/0098 Page 9 of 36 of Public Health and Environment Air Pollution Control Division Maximum Engi HP Co u ' • " o Relocation Date Eneion Standard in g/hp-hr NOx CO VOC <100HP Any N/A N/A N/A ≥100HP and <500HP January 1, 2008 January 1, 2011 2.0 1.0 4.0 2.0 1.0 0.7 ≥S00HP July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 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 010) 25. 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. 26. 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. 27. The permittee shall calculate the VOC emissions from each event using the volume of gas calculated and the most recent representative gas analysis as required by this permit. VOC emissions from each event shall be summed to obtain monthly emissions from venting. Monthly emissions shall be used in a rolling twelve month total 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): 28. This source is subject to Regulation No. 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. 29. 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 at 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. AIRS ID: 123/0098 Page 10 of 36 of Public Health and Environment Air Pollution Control Division 30. Point 014: Thi- "ity 4 dTw t +s - » Ne f `ource 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. • (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. • (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 VV. 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 W. • (2) If an instrument reading of 10,000 ppm or greater is measured, a leak is detected. (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. AIRS ID: 123/0098 Page 11 of 36 of Public Health and Environment Air Pollution Control Division ted! P -= 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. • §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). AIRS ID: 123/0098 Page 12 of 36 of Public Health and Environment Air Pollution Control Division 31. Point 026: Thison 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. 32. 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. • §60.5410 - 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). Specific Requirements for the Truck Loadout (Point 022} 33. 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) 34. 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 the conditions 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 13 of 36 of Public Health and Environment Air Pollution Control Division 35. All hydrocarbon lidi ap`m n ;''r=. =Mess ize, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. Specific Requirements for the Glycol Dehydration Unit (Point 0311 36. This equipment is subject to the control requirements for glycol natural gas dehydrators under Regulation No. 7, Section XII.H. Beginning May 1, 2005, uncontrolled actual emissions of volatile organic compounds from the still vent and vent from any gas - condensate -glycol (GCG) separator (flash separator or flash tank), if present, shall be reduced by at least 90 percent through the use of air pollution control equipment. This source shall comply with all applicable general provisions of Regulation 7, Section XII. 37. The equipment covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). These requirements include, but are not limited to: XVII.B.2.b If a combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. XVII.B.2.d Auto -igniters: All combustion devices used to control emissions of hydrocarbons must be equipped with and operate an auto -igniter as follows: XVI1.B.2.d.(i) All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device. XVII.B.2.d.(ii) All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 38. This equipment is subject to the control requirements for glycol natural gas dehydrators under Regulation No. 7, Section XVII.D. (State only enforceable). These requirements include, but are not limited to: XVII.D.3. Beginning May 1, 2015, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas -processing plant subject to control requirements pursuant to Section XVII.D.4., shall reduce uncontrolled actual emissions of hydrocarbons by at least 95 percent on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. If a combustion device is used, it shall have a design destruction efficiency of at least 98% for hydrocarbons. XVII.D.4. The control requirement in Section XVII.D.3. shall apply where: XVII.D.4.a. Uncontrolled actual emissions of VOCs from a glycol natural gas dehydrator constructed on or after May 1, 2015, are equal to or greater than two (2) tons per AIRS ID: 123/0098 Page 14 of 36 of Public Health and Environment Air Pollution Control Division year. Suc „'".l 'a°a rs 4tr be in compliance with Section XVII.D.3. by the date that the glycol natural gas dehydrator commences operation. 39. This source is subject to the TEG dehydrator area source requirements of 40 CFR, Part 63, Subpart HH - National Emission Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities including, but not limited to, the following: §63.760 — Applicability and designation of affected source o (f) The owner or operator of an affected major source shall achieve compliance with the provisions of this subpart by the dates specified in paragraphs (f)(1) and (f)(2) of this section. The owner or operator of an affected area source shall achieve compliance with the provisions of this subpart by the dates specified in paragraphs (f)(3) through (f)(6) of this section. (6) The owner or operator of an affected area source, located in an Urban -1 county, as defined in §63.761, the construction or reconstruction of which commences on or after February 6, 1998, shall achieve compliance with the provisions of this subpart immediately upon initial startup or January 3, 2007, whichever date is later. §63.764 - General Standards o (d)(2) Each owner or operator of an area source not located in a UA plus offset and UC boundary (as defined in §63.761) shall comply with the provisions specified in paragraphs (d)(2) (i) through (iii) of this section. • (i) Determine the optimum glycol circulation rate using the following equation: L-I.IS*3.0'�TEG* F*(1-O)-\ lbH2O 24hr/day, Where: LOFT = Optimal circulation rate, gal/hr. F = Gas flowrate (MMSCF/D) I = Inlet water content (lb/MMSCF) O = Outlet water content (lb/MMSCF) 3.0 = The industry accepted rule of thumb for a TEG-to water ratio (gal TEG/IbHZO) 1.15 = Adjustment factor included for a margin of safety. (ii) Operate the TEG dehydration unit such that the actual glycol circulation rate does not exceed the optimum glycol circulation rate determined in accordance with paragraph (d)(2)(i) of this section. If the TEG dehydration unit is unable to meet the sales gas specification for moisture content using the glycol circulation rate determined in accordance with paragraph (d)(2)(i), the owner or operator must calculate an alternate circulation rate using GRI—GLYCalcTM, Version 3.0 or higher. The owner or operator must document why the TEG dehydration unit must be operated using the alternate circulation rate AIRS ID: 123/0098 Page 15 of 36 of Public Health and Environment Air Pollution Control Division sue d E '_-_ ^ atio ith the initial notification in accordance with §63.775(c)(7). (iii) Maintain a record of the determination specified in paragraph (d)(2)(ii) in accordance with the requirements in §63.774(f) and submit the Initial Notification in accordance with the requirements in §63.775(c)(7). If operating conditions change and a modification to the optimum glycol circulation rate is required, the owner or operator shall prepare a new determination in accordance with paragraph (d)(2)(i) or (ii) of this section and submit the information specified under §63.775(c)(7)(ii) through (v). • §63.774 - Recordkeeping Requirements o (b) Except as specified in paragraphs (c), (d), and (f) of this section, each owner or operator of a facility subject to this subpart shall maintain the records specified in paragraphs (b)(1) through (11) of this section: (1) The owner or operator of an affected source subject to the provisions of this subpart shall maintain files of all information (including all reports and notifications) required by this subpart. The files shall be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report or period. • (i) All applicable records shall be maintained in such a manner that they can be readily accessed. • (ii) The most recent 12 months of records shall be retained on site or shall be accessible from a central location by computer or other means that provides access within 2 hours after a request. • (iii) The remaining 4 years of records may be retained offsite. (iv) Records may be maintained in hard copy or computer - readable form including, but not limited to, on paper, microfilm, computer, floppy disk, magnetic tape, or microfiche. o (f) The owner or operator of an area source not located within a UA plus offset and UC boundary must keep a record of the calculation used to determine the optimum glycol circulation rate in accordance with §63.764(d)(2)(i) or §63.764(d)(2)(ii), as applicable. • §63.775 — Reporting Requirements o (c) Except as provided in paragraph (c)(8), each owner or operator of an area source subject to this subpart shall submit the information listed in paragraph (c)(1) of this section. If the source is located within a UA plus offset and UC boundary, the owner or operator shall also submit the information listed in paragraphs (c)(2) through (6) of this section. If the source is not located within any UA plus offset and UC boundaries, the owner or operator shall also submit the information listed within paragraph (c)(7). • (1) The initial notifications required under §63.9(b)(2) not later than January 3, 2008. In addition to submitting your initial notification to the AIRS ID: 123/0098 Page 16 of 36 of Public Health and Environment Air Pollution Control Division 'ss r -fit .r d = s <63. • you must also submit a copy of the initial notification to EPA's Office of Air Quality Planning and Standards. Send your notification via e-mail to CCG— ONG@EPA.GOV or via U.S. mail or other mail delivery service to U.S. EPA, Sector Policies and Programs Division/Coatings and Chemicals Group (E143—01), Attn: Oil and Gas Project Leader, Research Triangle Park, NC 27711. (7) The information listed in paragraphs (c)(1)(i) through (v) of this section. This information shall be submitted with the initial notification. • (i) Documentation of the source's location relative to the nearest UA plus offset and UC boundaries. This information shall include the latitude and longitude of the affected source; whether the source is located in an urban cluster with 10,000 people or more; the distance in miles to the nearest urbanized area boundary if the source is not located in an urban cluster with 10,000 people or more; and the names of the nearest urban cluster with 10,000 people or more and nearest urbanized area. • (ii) Calculation of the optimum glycol circulation rate determined in accordance with §63.764(d)(2)(i). • (iii) If applicable, documentation of the alternate glycol circulation rate calculated using GRI-GLYCalcTM, Version 3.0 or higher and documentation stating why the TEG dehydration unit must operate using the alternate glycol circulation rate. • (iv) The name of the manufacturer and the model number of the glycol circulation pump(s) in operation. • (v) Statement by a responsible official, with that official's name, title, and signature, certifying that the facility will always operate the glycol dehydration unit using the optimum circulation rate determined in accordance with §63.764(d)(2)(i) or §63.764(d)(2)(ii), as applicable. (f) Notification of process change. Whenever a process change is made, or a change in any of the information submitted in the Notification of Compliance Status Report, the owner or operator shall submit a report within 180 days after the process change is made or as a part of the next Periodic Report as required under paragraph (e) of this section, whichever is sooner. The report shall include: • (1) A brief description of the process change; • (2) A description of any modification to standard procedures or quality assurance procedures (3) Revisions to any of the information reported in the original Notification of Compliance Status Report under paragraph (d) of this section; and AIRS ID: 123/0098 Page 17 of 36 of Public Health and Environment Air Pollution Control Division or . ir : No tion of Compliance Status Report under paragraph (d) of this section for changes involving the addition of processes or equipment. OPERATING & MAINTENANCE REQUIREMENTS 40. Points 001, 002, 003, 005, 007, 0th, 014, 016, 026, 031, 032 and 033: 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 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 41. 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. 42. Points 032 and 033: A source initial compliance test shall be conducted on emissions points 032 and 033 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. Carbon Monoxide using EPA approved methods. Formaldehyde 43. Point 031: The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.16) Periodic Testing Requirements 44. Points 001, 002, 003, 005, 007, 011, 016, 032 and 033: 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 Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. AIRS ID: 123/0098 Page 18 of 36 45. Point 010: The p on a semiannual basis of gas samples that are representative of gas that may be vented from the plant blowdown vent (point 010). Public Health and Environment Air Pollution Control Division 46. 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. 47. Point 031: The owner or operator shall complete an extended wet gas analysis prior to the inlet of the dehydration unit on an annual basis. Results of the wet gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit and be provided to the Division upon request. ADDITIONAL REQUIREMENTS 48. All previous versions of this permit are cancelled upon issuance of this permit. 49. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, 'LC) a. Annually by April 30`h 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. AIRS ID: 123/0098 Page 19 of 36 of Public Health and Environment Air Pollution Control Division The APEN nc e. ufa• . .r, 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. 50. 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: 51. 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 II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 52. 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. 53. 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. 54. 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. 55. 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. AIRS ID: 123/0098 Page 20 of 36 of Public Health and Environment Air Pollution Control Division 56. Section 25-7-114. .re I so 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 Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 57. 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: Bradley Eades Permit Engineer Permit Histo Issuance Date Description Issuance 2 This Issuance Issued to Aka Energy Group, LLC. Modification to remove points 018, 019, 023, 024, 025, 028, 029, 030. These points were never installed. Addition of (2) RICE, (1) TEG Dehydrator, and modification of point 022 to remove emission controls. Issuance 1 June 16, 2014 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 — Modification 1 September 24, 2008 Modification to replace engine with point ID 001 with a Caterpillar G3516LE. Initial Approval January 29, 2008 Issued to Aka Energy Group, LLC AIRS ID: 123/0098 Page 21 of 36 Notes to Permit Holder at the urie oft is perms 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: http://www. cdphe.state. co. us/req u lations/ai rregs/100102agcccommonprovisionsreq. 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. of Public Health and Environment Air Pollution Control Division AIRS Point Pollutant CAS # Uncontrolled Emission Rate (lb/yr) Are the emissions reportable? Controlled Emission Rate (lb/yr) 001 Formaldehyde 50000 6513 Yes 1628 Acetaldehyde 75070 722 Yes 361 Acrolein 107028 444 Yes 222 Methanol 67561 216 No 108 n -Hexane 110543 96 No 48 Benzene 71432 112 Yes 56 Toluene 108883 704 No 352 002 and 003 EACH Formaldehyde 50000 321 Yes 161 Acetaldehyde 75070 37 No 18 Acrolein 107028 35 No 17 Methanol 67561 64 No 32 Benzene 71432 21 No 11 Toluene 108883 7 No 4 005 and 033 BOTH Formaldehyde 50000 5064 Yes 2532 Acetaldehyde 67561 366 Yes 183 Acrolein 75070 225 No 113 Methanol 107028 273 Yes 137 AIRS ID: 123/0098 Page 22 of 36 olo D-' aSmen of Public Health and Environment Air Pollution Control Division Benzene 7L 'c '' No 39 Toluene 108883 357 Yes 178 007 and 016 EACH Formaldehyde 50000 2347 Yes 1173 Methanol 67561 261 No 130 Acetaldehyde 75070 238 Yes 119 Acrolein 107028 224 Yes 112 Benzene 71432 135 Yes 67 1,3 -Butadiene 106990 56 Yes 28 Toluene 108883 48 No 24 011 Formaldehyde 50000 3245 Yes 1622 Methanol 67561 649 No 324 Acetaldehyde 75070 314 Yes 157 Acrolein 107028 296 Yes 148 Benzene 71432 178 Yes 89 1,3 -Butadiene 106990 75 Yes 37 Toluene 108883 63 No 31 014 Benzene 71432 1219 Yes 589 Toluene 108883 1555 Yes 753 Ethylbenzene 100414 0 No 0 Xylenes 1130207 375 No 180 n -Hexane 110543 8444 Yes 4094 022 Benzene 71432 21 No 21 n -Hexane 110543 181 No 181 026 Benzene 71432 848 Yes 411 Toluene 108883 1076 Yes 524 Ethylbenzene 100414 0 Yes 0 Xylenes 1130207 261 No 125 n -Hexane 110543 5826 Yes 2839 031 Benzene 71432 77,745 Yes 3887 Toluene 108883 133172 Yes 6659 Ethylbenzene 100414 3847 Yes 192 Xylenes 1130207 62079 Yes 3104 n -Hexane 110543 11890 Yes 594 032 Formaldehyde 50000 6211 Yes 3105 AIRS ID: 123/0098 Page 23 of 36 of Public Health and Environment Air Pollution Control Division 032 Acetaldehy. •"I Yes 376 Acrolein 107028 463 Yes 231 Methanol 67561 225 No 113 n -Hexane 110543 100 No 50 Benzene 71432 112 No 56 Toluene 108883 734 Yes 367 5) The emission levels contained in this permit are based on the following emission factors: Point 001: CAS Pollutant Emission Uncontrolled Ib/MMBtu Factors - g/bhp-hr Emission Controlled Ib/MMBtu Factors — 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: CAS Pollutant Emission Uncontrolled Ib/MMBtu Factors - g/bhp-hr Emission Controlled Ib/MMBtu Factors — 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. AIRS ID: 123/0098 Page 24 of 36 Emission Factor Sot 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 of Public Health and Environment Air Pollution Control Division Point 005: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr NOx 3.307 12.000 0.274 1.000 CO 3.031 11.00 0.552 2.000 VOC 0.110 0.400 0.055 0.200 50000 Formaldehyde 0.0276 0.1000 0.0138 0.0500 67561 Methanol 0.0055 0.0200 0.0028 0.0100 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-Spec'fic Fuel Consumption Factor of 8000 Btu/hp-hr, a site -rated horsepower value of 708.6 bhp, and a fuel heat value of 1000 Btu/scf. Emissions limits contained in this permit are based on the highest controlled emission factors for each pollutant between point 005 and point 033. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde Manufacturer Manufacturer Point 033: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr NOx 0.304 1.000 0.304 1.000 CO 0.947 3.110 0.473 1.555 VOC 0.253 0.830 0.126 0.190 50000 Formaldehyde 0.116 0.380 0.058 0.190 67561 Methanol 0.0025 0.0082 0.0013 0.0041 75070 Acetaldehyde 0.0084 0.0275 0.0042 0.0137 107028 Acrolein 0.0051 0.0169 0.0026 0.0084 71432 Benzene 0.0013 0.0043 0.0007 0.0022 106990 1,3 -Butadiene 0.0003 0.0009 0.0001 0,0004 108883 Toluene 0.0082 0.0268 0.0041 0.0134 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 7243 Btu/hp-hr, a site -rated horsepower value of 690 bhp, and a fuel heat value of 1000 Btu/scf. Emissions limits AIRS ID: 123/0098 Page 25 of 36 contained in this p between point 005 and point 033. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer/AP-42 Manufacturer 50000 Formaldehyde Manufacturer Manufacturer of Public Health and Environment Air Pollution Control Division ntr.= emission factors for each pollutant Points 007 and 016: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — 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-Specfic 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 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: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — 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-Specfic 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: AIRS ID: 123/0098 Page 26 of 36 of Public Health and Environment Air Pollution Control Division CAS Poll i ' `' of Sourc 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 as condensa e, engine oil and other heavy liquids Stream VOC (wt%) Benzene (wt%) Toluene (wt%) Ethyl- benzene (wt%) Xylene (wt%) n - hexane (wt%) Connectors Flanges Valves Pump Seals Other* Gas 25 0.1 0.1 0 0.05 0.5 1136 442 0 ; 780 16 Heavy Liquid 100 1.7 2.2 0 0.5 12 561 86 5 244 7 Light Liquid 100 1.7 2.2 0 0.5 12 1729 596 13 1114 4 Water/Oil 100 1.7 2.2 0 0.5 12 215 48 1 83 1 Group 2: Dry Gas Stream VOC (wt%) Benzene (wt%) Toluene (wt%) Ethyl- benzene (WIN Xylene (wt%) n- hexane (W1%) Connectors T cu ©m CO Valves O = Gas 5 --- --- --- --- --- 2091 488 770 25 Heavy--- Liquid --- --- --- --- --- -- -- --- --- Light Liquid -- --- --- --- --- --- --- --- -- --- Water/Oil --- --- --- --- --- --- --- Group 3: Propane refrigerant, methanol, antifreeze Stream VOC (wt%) Benzene (wt%) Toluene (wt%) Ethyl- benzene (wt%) Xylene (wt%) n - hexane (wt%) Connectors Flanges Pump Seals Valves Gas 100 --- --- --- --- -- 595 138 3 297 Heavy Liquid 100 --- --- --- --- --- 62 12 0 37 Light Liquid 100 --- --- -- — -- 42 0 0 21 Water/Oil 100 -- --- --- --- --- --- --- --- --- *0 her 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 AIRS ID: 123/0098 Page 27 of 36 of Public Health and Environment Air Pollution Control Division Connectors 20 +• 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. Point 022: Pollutant Emission Factors Uncontrolled lb/BBL loaded - Source Emission Factors Controlled lb/BBL loaded - Source VOC 0.236 CDPHE PS Memo14-02 --- The uncontrolled VOC emission factor was calculated using State approved emission factors for hydrocarbon liquid loadout in PS Memo 14-02. This loadout operation is not controlled. Point 031: The VOC and HAP emission levels contained in this permit are based on information provided in the application and the GRI GlyCalc 4.0 model. For Lopt, the gas flowrate (F) is 50 MMSCF/D, the inlet water content (I) was estimated as 90.3 lb/MMSCF in the application and the outlet water content (O) is 7.0 lb/MMSCF. For the Secondary Combustion emissions from the Enclosed Combustor: CAS Pollutant Emission Factors — Uncontrolled lb/MMscf gas processed Uncontrolled EF Source --- NOx 0.172 TCEQ Emissions Inventory Guidelines- Flare Emission Factors --- CO 0.343 Actual emissions for NOx and CO shall be calculated based on the emission factors in the table above and the total natural gas processed by the TEG dehydrator. NOx and CO emissions factors are based on a waste gas heat content of 2100 Btu/scf and 1235 scf waste gas/hr as modeled in the GRI GlyCalc model submitted with this application. Point 032: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr --- NOx 0.575 2.000 0.575 2.000 --- CO 0.618 2.150 0.309 1.075 VOC 0.150 0.520 0.075 0.260 AIRS ID: 123/0098 Page 28 of 36 of Public Health and Environment Air Pollution Control Division CAS : Pollutant Gmtilts' el,' Uncontrolled Ib/MMBtu -:=a ors - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr 50000 Formaldehyde 0.070 0.240 0.0350 0.120 75070 Acetaldehyde 0.0084 0.0291 0.0042 0.0145 107028 Acrolein 0.0051 0.0179 0.0023 0.0089 108883 Toluene 0.0082 0.0283 0.0041 0.0142 Emission factors are based on a Brake-Speclic Fuel Consumption Factor of 7668 Btu/hp-hr, a site -rated horsepower value of 1340 bhp, 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 Other HAP AP -42, GRI Field Test, or GRI Literature (most conservative) Manufacturer 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 (wt%) Benzene (wt%) Toluene (wt%) Ethyl- benzene (wt%) Xylene (wt%) n- hexane (wt%) Connectors Flanges Pump Seals Valves O 5= (-1,) Gas 25 0.1 0.1 0 0.05 0.5 844 348 0 587 16 Heavy Liquid 100 1.7 2.2 0 0.5 12 497 68 5 184 7 Light Liquid 100 1.7 2.2 0 0.5 12 1090 398 13 741 4 Water/Oil 100 1.7 2.2 0 0.5 12 174 30 1 61 1 Group 2: Dry Gas Stream VOC (wt%) Benzene (wt%) Toluene (wt%) Ethyl- benzene (wt%) Xylene (wt%) n- hexane (wt%) Connectors Flanges C cu m Other' Gas 5 --- --- --- --- --- 1294 364 501 25 Heavy Liquid --- -- -- --- -- --- --- Light Liquid --- --- --- --- --- --- --- --- --- --- Water/Oil --- --- --- --- --- --- Group 3: Propane refrigerant methanol, antifreeze Stream VOC (wt%) Benzene (wt%) Toluene (wt%) Ethyl- benzene (wt%) Xylene (wt%) n - hexane (wt%) Connectors Flanges Pump Seals Valves Gas 100 --- --- --- --- --- 356 70 3 124 AIRS ID: 123/0098 Page 29 of 36 of Public Health and Environment Air Pollution Control Division Heavy Liquid 100 --- --- 26 0 0 13 Light Liquid 100 --- --- - --- --- 30 0 0 15 Water/Oil 100 --- --- --- --- --- --- -- — --- Group 4: Amine plant Stream VOC (wt%) Benzene (wt%) Toluene (wt%) Ethyl- benzene (wt%) Xylene (wt%) n - hexane (wt%) Connectors Flanges Pump Seals Valves Open- ended lines Gas 25 0.5 0.5 0.005 0.10 1.5 20 20 0 15 0 Heavy Liquid 50 0.05 0.05 0.0001 0.001 0.001 800 800 6 720 50 Light Liquid 50 0.05 0.05 0.0001 0.001 0.001 Water/Oil 50 0.05 0.05 0.0001 0.001 0.001 --- --- — -- -- *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 ervi Water/Oil Service S 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. 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.qov/ttn/atw/area/fr18ia08.pdf 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 AIRS ID: 123/0098 Page 30 of 36 of Public Health and Environment Air Pollution Control Division include requirements foed 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: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www. epa. qov/ttn/atw/area/arearu les. htm I 9) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: NOx, VOC, CO, formaldehyde, benzene, toluene, xylenes, n -Hexane, 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: 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 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 )OOOO X 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. cd phe. state. co. us/ap/oilgasperm ittinq. htm I AIRS ID: 123/0098 Page 31 of 36 of Public Health and Environment Air Pollution Control Division 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 32 of 36 of Public Health and Environment Air Pollution Control Division 2.1.2 The owner or operatotaditty p;tt'ni =aa'(a r .{ e_ +ae excompressor 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. co lorado. qov/cs/Satel I ite/CD PHE-AP/CBON/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 33 of 36 of Public Health and Environment Air Pollution Control Division For comparison with a sho ". ` li r he `' ''<=asemmBtu), 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 SO2: 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 34 of 36 of 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 XVII. E — 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: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NO x CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 500<Hp July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 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 35 of 36 of Public Health and Environment Air Pollution Control Division requirements for the perm ,r- em - - m-<<..._ ., I be uded 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 36 of 36 Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Facility Equipment ID Aka Energy Group, LLC Gilcrest Gas Plant 13472 Weld County Road 40 C-3 Permit No. AIRS Review Date Permit Engineer 07WE0881 123/0098/005 03/07/2016 Bradley Fades Requested Action Issuance No. Request MOD - change fuel/equipment, Request MOD - change permit limit 2 Emission Point Description One (1) White Superior, Model 8G825, Serial Number 18478, natural gas -fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 708.56 horsepower. 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. Natural Gas Consumption Requested (mmscf/yr) 49.66 Requested (mmscf/m) 4.22 Fuel Heat Value (btu/scf) 1000 BSCF (Btu/hp-hr) 8000 Emission Factor Sources Uncontrolled Controlled NOx manufacturer (as indicated in CP1) Manufacturer VOC manufacturer (as indicated in CP1) Manufacturer CO manufacturer (as indicated in CP1) Manufacturer Formaldehyde manufacturer (as indicated in CP1) Manufacturer SOX AP -42', Table 3.2-3 (7/2000); Natural Gas No Control TSP AP -42', Table 3.2-3 (7/2000); Natural Gas No Control PM10 AP -42', Table 3.2-3 (7/2000); Natural Gas No Control PM2.5 AP -42', Table 3.2-3 (7/2000); Natural Gas No Control Other Pollutants AP -42, Table 3.2-3 (7/2000); Natural Gas AP -42 Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 87 8760 POINT 005 Point Summary of Criteria Emissions It Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 82.1 6.8 82.1 91.7% VOC 2.7 1.4 2.7 50.0% CO 75.3 13.7 75.3 81.8% SOx 0.0 0.0 0.0 0.0% TSP 0.5 0.5 0.5 0.0% PM10 0.5 0.5 0.5 0.0% PM2.5 0.5 0.5 0.5 0.0% Total HAPs* 0.0 0.0 1.0 50.0% `Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants lb/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 1368 684 1368 50.0% Methanol 274 137 274 50.0% Acetaldehyde * 139 50.0% Acrolein * * 131 50.0% Benzene * * 78 50.0% 1,3 -Butadiene * * 33 50.0% Toluene * * 28 50.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines/No NAAQS violations expected (see details of modeling analysis) Public Comment Public Comment not required MACT 777Z Existing 4SRB over 500 HP located at a(n) Area Source Reg 7 XVII.E Standards (g/hp-hr) NOx: NA CO: NA VOC: NA Reg 7 XVI.B (Ozone NAA requirements) applies? yes MACT ZZZZ (area source) Is this engine subject to MACT 7777 area TBD source requirements? NSPS JJJJ Is this engine subject to NSPS JJJJ? TBD Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes Aka is requesting to adjust this permit to allow for the engine replacement with a Caterpillar G3508B (point 033) should they need to. As a result, the permit limits for point 005 and 033 will be combined in permit 07WE0881 based on "worst -case" emissions and a total combined fuel throughput limit. ADDITIONAL INFORMATION ON THIS EMISSION POINT AND REQUESTED PERMIT ACTION IS CONTAINED IN A SEPARATE DOCUMENT (07WE0881.CP2.xlsm) Summary of Preliminary Analysis - NG RICE Company Name Aka Energy Group, LLC Facility Name Gilcrest Gas Plant Facility Location 13472 Weld County Road 40 Facility Equipment ID C-8 Permit No. AIRS Review Date Permit Engineer 07WE0881 123/0098/032 01/26/2016 Bradley Eades Requested Action New permit/newly reported emission Issuance No. 2 Emission Point Description One (1) Caterpillar , Model G3516TALE, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SLB reciprocating internal combustion engine, site rated at 1340 horsepower. This engine shall be equipped with an oxidation catalyst and air -fuel ratio control This emission unit is used for natural gas compression. Natural Gas Consumption Requested (mmscf/yr) 90.37 Requested (mmscf/m) 7.68 Fuel Heat Value (btu/scf) 996 BSCF (Btu/hp-hr) 7668 Emission Factor Sources Uncontrolled Controlled NOx Manufacturer Indicated catalyst control efficiency VOC Manufacturer/AP-42 Indicated catalyst control efficiency CO Manufacturer Indicated catalyst control efficiency Formaldehyde Manufacturer Indicated catalyst control efficiency SOx AP -42; Table 3.2-2 (7/2000); Natural Gas No Control TSP AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM10 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM2.5 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control Other Pollutants AP -42; Table 3.2-2 (7/2000); Natural Gas Indicated catalyst control efficiency Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Point Summary of Criteria Emissions (tpy) Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 25.9 25.9 25.9 0.0% VOC 6.7 3.4 6.7 50.0% CO 27.8 13.9 27.8 50.0% SOx 0.0 0.0 0.0 0.0% TSP 0.4 0.4 0.4 0.0% PM10 0.4 0.4 0.4 0.0% PM2.5 0.4 0.4 0.4 0.0% Total HAPs` 4.1 2.0 4.4 50.0% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (Ib/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 6211 3105 6211 50.0% Acetaldehyde 752 376 752 50.0% Toluene 734 367 734 50.0% Acrolein 463 231 463 50.0% Methanol * * 225 50.0% Benzene * 112 50.0% n -Hexane * * 100 50.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines/No NAAQS violations expected (see details of modeling analysis) Public Comment Public Comment Required/Public Comment not required MACT 777Z TBD over 500 HP located at a(n) Area Source Reg 7 XVII.E Standards (g/hp-hr) NOx: 1.0 CO: 2.0 VOC: 0.7 Reg 7 XVI.B (Ozone NAA requirements) applies? Yes MACT ZZZZ (area source) Is this engine subject to MACT 7777 area TBD source requirements? NSPS JJJJ Is this engine subject to NSPS JJJJ? TBD Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes New engine at existing facility. Additional information for this emissions unit and the requested permit action is included in a separate PA document (07WE0881.CP2.xlsm) Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Facility Equipment ID Aka Energy Group, LLC Gilcrest Gas Plant 13472 Weld County Road 40 C-3 Permit No. AIRS Review Date Permit Engineer 07WE0881 123/0098/033 03/07/2016 Bradley Eades Requested Action New permit/newly reported emission, Request MOD - change permit limit Issuance No. 2 Emission Point Description One (1) Caterpillar, Model G3508B, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SLB reciprocating internal combustion engine, site rated at 690 horsepower. This engine shall be equipped with an oxidation catalyst and air -fuel ratio control This emission unit is used for natural gas compression. Natural Gas Consumption Requested (mmscf/yr) 43.78 Requested (mmscf/m) 3.72 Fuel Heat Value (btu/scf) 1000 BSCF (Btu/hp-hr) 7243 Emission Factor Sources Uncontrolled Controlled NOx Manufacturer- 0 VOC Manufacturer spec/AP-42 0 CO Manufacturer 0 Formaldehyde Manufacturer 0 SOX AP -42; Table 3.2-2 (7/2000); Natural Gas No Control TSP AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM10 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM2.5 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control Other Pollutants Describe EF sources - HAPs etc. Describe EF sources - HAPs, etc. Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Point Summary of Criteria Emissions (tpy) Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 6.7 6.7 6.7 0.0% VOC 5.5 2.8 5.5 50.0% CO 20.7 10.4 20.7 50.0% SOx 0.0 0.0 0.0 0.0% TSP 0.2 0.2 0.2 0.0% PM10 0.2 0.2 0.2 0.0% PM2.5 0.2 0.2 0.2 0.0% Total HAPs* 2.9 1.4 3.1 50.0% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minim us thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 5064 2532 5064 50.0% Acetaldehyde 366 183 366 50.0% Toluene 357 178 357 50.0% Acrolein * * 225 50.0% Methanol * * 109 50.0% Benzene * * 57 50.0% n -Hexane * * 49 50.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment not required MACT 777Z TBD - Engine dates are unknown at this time. Only date indicated on APEN is manufactured before 7/1/2007, however there was no date indicated for date of construction or reconstruction. Reg 7 XVII.E Standards (g/hp-hr) NOx: NA CO: NA VOC: NA Reg 7 XVI.B (Ozone NAA requirements) applies? Yes MACT ZZZZ (area source) Is this engine subject to MACT 7777 area TBD source requirements? NSPS JJJJ Is this engine subject to NSPS JJJJ? No Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Based on manfuacture date indicated on APEN "before 07/1/2007", this engine will not be subject to requirements per NSPS JJJJ. For lean burn engines greater than 500HP and less than 1350HP are subject only when construction commenced after 06/12/06 and manufacture date is on or after January 1, 2008. Comments/Notes Aka is requesting to adjust this permit to allow for the engine replacement of a Superior 8G825 (point 005) with a Caterpillar G3508B should they need to. As a result, the permit limits for point 005 and 033 will be combined in permit 07WE0881 based on "worst -case" emissions and a total combined fuel throughput limit. Point 033 is newly reported emissions source. It should be noted that the Superior engine (point 005) has a higher maximum potential fuel consumption. Since both engines are being permitted with a combined fuel limit and emission limit, the Caterpillar engine when operating exclusively is not capable of consuming the entire fuel limit. Therefore the Imit used to develop the emissions for both engines should be the higher of the two. Additional information on this emission unit and permit action are contained in a separate PA document (07WE0881.CP2.xlsm) Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Package #: Received Date: Review Start Date: Section 01 - Facility Information Company Name: Aka Energy Group, LLC. County AIRS ID: 123 Plant AIRS ID: 0098 Facility Name: Gikrest Gas Plant Physical Address/Location: 13472 Weld County Road 40 Type of Facility: Natural Gas Processing Plant What industry segment? Oil & Natural Gas Production & Probing Is this facility located in a NAAQS non -attainment area? If yes, for what pollutant? CI Carbon Monoxide (CO) Bradley Eades 340108 10/28/2015 1/21/2016 Section 02 - Emissions Units In Permit Application Yam. .. . • ❑ Particulate Matter (PM) 3omne (Nth & VCC) AIRS Point # Emissions Source Type Emissions Control? Permit # Issuance # Self Cut Required? Action Engineering Remarks 001 . ' Natural Gas RICE • Yes • 07WEC881 2 No No Action . ' Requested 451.8 002 Natural Gas RICE - - - Yes:. 07WE0881 2 ... • No ;: . No Action.. . Requested 4SRB 003 Natural Gas RICE. •..• .. . . :. . Yes. 07WE0881 2 ... No.......': • No Action RReqnested .:.• 4SRB 005 al NaturGas: RICE': � :' : . Yes . 07W E0881 2 Yes: ' .: Permit. • Modification' : • Combine limits with 032. PA is in separate document 007 Natural: Gas•RlcE • Ye'.'. 07WE0881 2 No. :.. Na Action. ..'Requested • 4SRB 010 Other (Explain) No' 07WE0881 2 Na..:. .:::• ;.. ' NO Action Requested . Plant Vent (owdown vent) 011 Natural:Gas RICE : • • .Yes. • • 07WE0881 2 ••• • No'• No Action : Requested • 4SRB 014 ' ' .• FugRrye•ComiponentLeaks- '•' -'' Na 07WE0881 2 N6. .': : :NO Action .. . Requested Subject to KKK 016 Natural Gas.RICE:. Yes 07WE0881 2 ':Ntl..... No. Action .:...Requested' 4SRB 022 Hydrocarbon tuquid loading.:'- No 07WE0881 2 ' No' ' Permit .' •• Modification: • Mod to remove emission control 026 Fiigitive.Component Leaks:' ' ' ' Yes 07WE0881 2 Yes. '.:.No AtYiOn . . ', : Requested 0000 031 TEG Dehydrator Yes 07WE0881 2 .....Yet t :.:Permit • . Modification .. New Point 032 Natural•Gas RICE • . Yes' 07WE0881 2 Yes ' Permit ' t'' Modification New Point, 4SLB. PA is in separate document 033 ... .. .. .... .... .. � . .... ... ' • Naturai'GasRICE • • Yes C7WE0881 2 ......... • Y. ': .. P . ' Modification ' • New point interchangeably with 005, 4SL8 PA is ln separate document Colorado Air Permitting Project Section 03 - Description of Project A 708 hp natural gas fired engine (AIRS 032), a 690 hp natural gas fired engine (AIRS 033), and a Tr'Ethylene Glycol dehydratia i unit (AIRS 031) will be added to the existing Gilcrest Gas Plant to add 50 MMscf/day of dehydration capacity to the plant. In addition this project is requesting modification of 07WE0831 to allow for a permanent engine replacement for point 005 with point 033 (non like -kind) and remove controls used for loadout. In order to maintain facility -wide emissions below major source thresholds (for N0x), the process and emission limits are being combined for points 005 & 033. The operator has indicated that the engine assigned to AIRS 005 is nearing fie end of its expected operational life, and once it has been replaced by point 033, point 005 will be removed from service. New or updated operating and maintenance plans were submittedfor the following points: 001, 002, 003, 005, 007, 011, 016, 032, 031, & 033. Facilty is synthetic minor forTitle V, NANSR, and P50. Additionally Aka is requesting removal of the following points from 07WE0881 for equipment that was never installed at the faulty (Expansion project was cancelled before construction began): 018, 019, 023, 024, 025, 028, 029, 030 . Although fugitive point 026 (subject to NSPS 0000) was originally associated with components added with the cancelled expansbn, Aka has made the determination that new componenets to be added with the construction of the new TEG Dehy (point 031) will be subject to NSPS 0000 for fugitive component leaks and will be covered under AIRS 026. Component hard counts for AIRS 026 will be required with self -certification. Hard counts for 014 were submitted with partial sel cert received 12/12/2015. Initial testing requirements for the existing engines at this site (on Issuance 1) were removed based on review of records related to the facility. I was able to confirm the engines were tested and demonstrated compliance with the annual emissions limits on the following dates: AIRS 001: December 11, 2014 AIRS 002, 003, & 007 : January 21, 2015 AIRS 016: January 20, 2015 AIRS 005: April 2, 2015 AIRS 011: December 12, 2014 On June 13, 2016 Aka energy darified details of a request stemming from the O&M plan submitted with this application for the engines associated with this permit. As a result, a periodic testing requirement was included in order to allow the establishment of lower pre -catalyst operating temperatures than those prescribed in the 0&M plan. As a result, stack test language was developed through consultation with the Divsion stack test coordinator to allow for annual reference mehtodtesting on the engines in question. This language deviates from the Division test protocol in that the testing is not required at maximum load, and may be run at the was found' operating conditions (since the lower temperatures are observed when the engine is operating at c 100% load capacity). Condition 41 was also added to clarify the allowable minimum pre -catalyst temperature (prior to required maintenance) based on results of the testing. The language is meant to allow for operation down to the minimum temperature observed during a reference method test done in accordance with condition 46. It should also be noted that any reference mehtod testing done in accordandce with condition 46may substitute for portable analyzer testing for the monitoring period specified in the O&M plan for which the test was conducted. On 7/28/16 received request from Aka requestingthe periodic testing permit requirement be required on an "opt -ins basis only. This request was denied and Aka requested to remove the periodic testing requirement from the permitalong with the proposed pre -catalyst temperature deviation. Facility -wide permitted emissions are greater than 90 tpy for NOx. Additionally, faci(ty-wide emissions of HAPs are greater than 20 tpy. Therefore tracking of emissions from insignificant activities will be required to ensure total potential emissions from the facility are less than 100 tpy NOx and 25 tpy total HAP. Section 04 - Public Comment Requiements Is Public Comment Required?,,,,,i.,:•,;,:: _: •;; If yes, why?' R sttnB Yt11114tk!xN!sotPeeti�t .:..........:≥::::::'.::: fs::. ' • .i.:-:JP:,?,;';:'.: : TEG Dehy is new synthetic minor Section 05 - Ambient Air Impact Analysis Requirements Was a quantitative modeling analysis required?2 If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, explain what programs and which pollutants here: Prevention of significant Deterioration IPSO): CO Title V'Operating Permits (OP) : NOx, CO, VOC, HAPs • Non-AttainmentNew Source. Review (NANSR):: NOx, VOC Is this stationary source a major source? If yes, explain what programs and which pollutants here: Prevention of significant Deterioration (P5O): N/A Title V Operating Permits (OP) : N/A Non -Attainment New Source Review (NANSRI: N/A Aka Energy Group, LLC Gilcrest Gas Plant Permit # AIRS ID 07WE0681 123-0098-022 Issuance 2 Point Description Hydrocarbon liquid loadout operation to tank trucks. Emissoins displaced from truck are exhausted to the plant blowdown vent (point 010). Division Information Engineer Bradley Fades Control Engineer: Chnstopher Laplante Review Date: 01/26/2016 Application Date: 10/28/2015 Emissions Inventory Analysis bbl/yr NO CONTROL Emissions Summary Hydrocarbon Liquid Loaded: 50,000 Component Uncontrolled Emission Factor (lb/BBL) Uncontrolled Emissions (lb/yr) Uncontrolled Emissions (tpy) Are Emissions Reportable? Emission Factor Source VOC 0.236 11,800 5.90 CDPHE PS -M Benzene 4.16E-04 21 0.01 No CDPHE PS -M n -hexane 361E-03 181 0.09 No CDPHE PS -M Section 03 - Regulatory Considerations ma 14-02 mo 14-02 ma 14-02 Is this site considered an exploration and production location (e.g. well pad)? No If yes, review the following two exemptions for applicability: Does the operator unload less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II.D. 1.1 Does this operator unload less than 6,750 bbls per year of condensate via splash fill or 16,308 bbls per year of condensate via submerged fill procedure? No If yes, this emissions point is categorcally exempt from permit requirements per Regulation 3, Part B, Section II. D. 1 I Is this site located in an ozone non -attainment area? Yes If yes, this source is subject to Reasonably Available Control Technology (RACT) requirements under Regulation 3. Part B Section IIID 2 a. This requirement may be met using "submerged fill" and/or vapor balance with emissions routed to an emissions control device. Is this facility classified as a major source of HAPs? No If yes, evaluate if 40 CFR, Part 63, Subpart EEEE "Organic Liquids Distribution" MACT provisions apply Does this facility involve the loading of refined crude/condensate in the form of "gasoline"? If yes, proceed to evaluate the following: Is this facility classified as a "Terminal" as defined per Regulation 7, Section VI.C.2.a? If yes, the provisions of Regulation 7, Section VI.C.2 may apply Is this facility classified as a "Bulk Plant" as defined per Regulation 7, Section Vl.C.3.a? If yes, the provisions of Regulation 7, Section VI.C.3 may apply Section 04 - SCC Coding Pollutant VOC Benzene n -hexane Emissions Factor (lb/1.000 gallons) 5.63 lb/1,000 gallons 0.0099 lb/1,000 gallons 0.086 lb/1,000 gallons No No No No 40600132: Gmtle OII' Submerged Loading (Normal Service) Used S = 0.6 Analysis Note, *Modification ofthis point of requesting Yemovaf of emdosed com11133idn as the controldevice. Af§o emission factors are being updated M reflect State approved emisstomfa€tors State Emission Factors aze bemg;appravedforvse-per PS Memo24 G2 Secdon 4.fi'. Aka Energy Group, LLC Gilcrest Gas Plant Permnp AIRS ID Point Description 07WE0001 Issuance 2 123-0098-031 One (1) triethylene glycol (TEG) dehydrator unit with a design opacity of 50 MMscf/day IE#erran, Model TOO, serial number: Tell. This emissions unit is equipped with two (2) electric glycol pumps (Rotor Teal with a maximum capacity of 10 gallons per minute (2 primaryand 1 backup), This system includes a /etco BTEx T. condenser, reboiler, still vent, and a flash tank. The flash tank emissions will be recycled in a closed loop system that utilizes a vapor recovery unit IVel11, or routed to an ECB which achieves a minimum of95%control efficiency. The still vent emissions are routed to a condenser and then to an enclosed combustor with a minimum destruction efficiency of 95% fMissions Calculation Review The source used GEl ulycalc 4.0 to estimate emissions. Wet gas composition, pressure and temperature are from site-specfic wet gas analysis collected are 2015. Initial and annual sampling will be used to calculate actual emissions. Although this system is equipped with a ETEX condenser, still vent emissions were calculated by operatoricing a maximum of 95% control of the still vent emkisons. Secondary combustion emissions were conservatively calculated assuming the entirety of both emission streams are combusted The flow rate of each emission stream and HMV is estimated from Glycalc model. The model was based on the following parameters: Inlet Gas Pressure 1200 psig Flash Tank:k Pressure 60 psig Inlet Gas Temperature 120 degF Flash Tank Temperature 115 degF Glycol Recirculate Rate 10 Rpm /Ayr, Resin/0106S Der year) 'VRU Control 0% Flare 95% Pollutant Uncontrolled Naar) Uncontrolled 06w) Uncontrolled I1➢vl Controlled nWhr) Controlled OOvrl Controlled (Ind %Control VOC HAPs 172142 150796.392 75398196 086071 7539.82 376991 950% 07179 6206804 3.144402 0035895 3144402 0.15722 95.0% Benzene 0.1265 112566 0.56283 O006425 56.283 0028142 95.0% Toluene o taOs 1215888 0607944 0.00694 60.7944 O030397 95.0% Elhylbenzene 00023 20.148 0.010074 0000115 10074 0000504 95.0% Xylenes .0.0248 217248 0.108624 000124 108624 0005431 95.0% nHexane 0.4218 3694 968 1.647484 002109 184 7484 0092374 95.0% Emissions are calculated assuming overall 95%control deep40 a p5 on of ems Ions from t e flash tank are recycled to Me Intel. 611 Vent BTEX Condenser and Flare Pollutant Uncontrolled (Wm) Uncontrolled Uwm) uncontrolled (toy) Controlled 116411 controlled MAO Controlled VOC HAP5 51.3576 449892 576 224 946288 256788 2249463 1124731 95.0% 32.2462 282094 232 141 247116 161241 14124.71 7062356 95.0% Benzene 8.7465 7661934 3830967 0437325 3830.967 1.915484 95.0% Toluene 15,0634 131955 384 65977692 0.75317 6597 769 3.298885 95.0% Ethylbenzene 0.4389 3827244 1913622 0.021045 1913622 0095681 95.0% Xylenes 70618 61861368 30 930684 0.35309 3093068 1546534 95.0% mHexane 09355 619498 4.09749 0046775 409.749 0204874 95.0% 208 MMscl/hr 50 MMscld 1550 MMscf/mor 18250 MMscllyr 45525 MA/sof/quarter Pollutant Uncontrolled (lb/hr) Uncontrolled (lb/yr) uncontrolled (ipy) Controlled (ISlErl Controlled (lb/yr) Controlled (t➢y) %LOmrel EF db/MMsoll. VOL HAPs 685718 600889 30034 342859 30034 15.0 95% 3291 32.9661 ne,783 14439 1648305 14439 72 95% 15824 Benzene 8875 77,745 38.87 044375 3,887 19 95% 4260 Toluene 15.2022 133,171 66.59 076011 6,658 3.3 95% 7297 Ethylbe noene 04392 3.847 1.92 0.02196 192 0.1 95% 0.211 Xylenes 70856 62,079 3104 035433 3,104 16 95% 3402 n -Henn 1.3573 11,860 594 0067665 594 0.3 95% 0652 Secondary Emissions 761 sdh (from flash tank) 474 Set (from all I vent) achy waste gas now 0 0.01235 MBYCI waste 98Ynr (from GI calc report) Dehy write Rae heal cont 2100 BIWsof ( conservatively estimated IrOm Glycalc report) MMBTU/yr 2 5935E- 06 MMBtulhr Wet Gas Processed 2.08 MMscf wet gun processed/er combustion emission factor source: ]CEO Emissions Inventory Guidelines Flan Emission Factors 0138 2898 lb NOXIMMHIu waste gas lb NOWMh%c1 waste Gas lb NOLMMscl Wet Gas Prou 0 2755 570 55 lb CG/MMRN waste gas lb CO/MMscf waste Gas lb CO/MMnct Wet Gas Processed 0.17179314 0 34296444 Note: emsvon factors are converted from lb/MM6lu waste gas to IbMM5cr gas processed since asaooeted process limb wily be wet gas processed Emission Fedor Emissions 3008051 9aa Pollutant sed Source IIMyr NOx 0,17179344 TCEO/Glycalc 3,1352 1,5 157 CO 0.34296444 TCFO/Glycak 6.259.1 3.13 K \PA\07\07WE0881 CP2.xlsm 123/0107 Arca Energy Grouo. L_C Gaueat Gas Plant PermitP AIRS D Regal Reawaken Part A APEN Requitementa APEN is required since actual uncontrolled VOC emissions are greater than 21py. NOx and CO emissions are below APEN thresholds Part B - Construction Permit Requramertb Permit is required snce facility -wide actual uncontrolled VOC emissions from all APEN-required points are greater than 5 toy. jleorletion 7 — Volatile Craang Cgmogyrdh SUP VOLATLE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS This source is subect to this section since it rs located in a nonattanment area. XVI1.D STATEWIDE CONTROLS FOR CIL AND GAS OPERATIONS atory Review 07WEDB61 Issuance 2 123-0098-031 Per Reg 7, Section XVII.B.5, dehydrators subject to an emission control requirement under 40 CFR Pert 63 are exempt from Section XVII. However, as discussed below In MAR NH, this deity Is rat subject to a control standard under MACT because It is meeting a work practice standard for optimal recirculation rate. Thus, the dehy must still be evaluated under Regulation 7 XVII.D. This deity is subject to XVIID.3 because per XVILD.4.. the aehydrator will be constructed offer 6/1/2015 and uncontrolled actual emissions of VOC are greater than 2 tpy. Rtgumon -cCQnbgl of HAP% Part E - MALT 11H Since this facility is a natural gas processing plant, all emissions horn the facility are aggregated when determining major HAP status. Thus, the site is a synthetic minor source of HAP, and is then an area source of IIAPs per MACr Igt. As specified in 63.760(b)(2), the only affected sources for wee sources are TEG dehydrators. The TED deity does not qualify for the benzene exemption so, as spoctfied in 6.3.764(d)(2) his subject to the optimal glycol recirculeUon rate requirement snce the facility is not located in an UC boundary or In a UA plus offset area. Facilty is located within an Urban -1 county since it is located in Weld County which contains the Greeley, CO Metropobtan Statistical Area with a population of 252,825 based on 2010 census data. Analysis Notes, •hug vent emissions are routed to a condenser prior to the flare, however applicant is not requesting to claim arty additional control credit and is requesting an overall control efficiency of 9594. `Flash tank emissions ere recycled in a dosed bop rystem via VRU Of routed to the enclosed combustors. A limit was not included on the gas processed during VRU downtime since permit limits are conservatively developed assuming the entire Rash gas stream is routed to the combustor. 'Applicant initially calculated secondary emissions IRO., and CO) assuming maximum capacity of the flare, however this over -estimates emissions . rather I suggested caluulatiog using the estimated Itchy waste gas flow from the flash tank and the still vent from ghosts. Applicant agreed with calculation using actual tow rates from Givens ('flash tack off gas smeared. "condensor vent stream") and an estimated stream HMV based on the waste gas composition calculated in Glycalc. •Per O&M, emissions from the DENY will be routed to the reboiler burner when they are unable lobe collected by the VRU or muted to the combustor. This control scenario is not coveted during sonnet operations included in this permit, and wig only be used by Aka during operation that would qualify as a malfunction per AOCC Common Provisions Part II.E. (Affirmative Defense Provisionsfor Excess Emissions During Malfunctions). •Applicant did not provide a regulatory applicability analysis with application and on 03/15/16 discussed applicability of MILT HH with applicant. Joe Miller indicated that the Deity *Is to be located outside of any UC boundary or UA plus offset area. I evaluated Boulder ❑A, Brighton UC, Fort Collins UA, Greeley UA, Lafaye ttrlouavige UA, Longmont UA, and Windsor VC, which are all I the vicinity, and the closest area to the Ggcresl facility is the Greeley UA, which is aporosimatelv 6.5 miles to the NE of the facility. (The Gilaest facility is therefore approximately 4.5 miles outside of this 'UA plus 2 -mile offset' area.) •A recent site -specific wet gas temple was used for Glycalc calculations submitted. Therefore, an initial sample is not being required lobe submitted with self- certifation. An intuit compliance test for outlet concentrations of VOC/HAP is not being required since Dehy is controlled with EC0 (notdaiming 095% ORE). `Compliance shall be demonstrated for VOC and HAP using a monthly GM Glycalc version 4.0 or higher on a monthly basis using the most recent wet gas analysis from the site and recorded operational values specified in the O&M Plan. Compliance shall be demonstrated for NOa and CO using the emission factors calculated above and included in the "notes to permit holder'. Emission factors are based on TCEC Flare Emission Factors and the Glyalo model submitted with this application (IOW & MMsd waste gas/hrl. K.\PA\07\ 07WE0Bg1.CP2.sism 123/0107 005 & 033 (permit limits) The engines assigned to AIRS Os 005 and 033 are being permitted to be used interchangeably. Specifically 033 will replace 005 should the need arise. As a result the points are being permitted with a combined fuel consumption and emissions limits. The summary calculations below are taken from the respective PAs for each engine (07WE0881-005.CP2.xlsm & 07WE0881-033.CP2.xlsm) to provide a summary of the source of each limit included in permit 07WE0881.CP2 for points 005 & 033. En • ine Informati',y.:. Engine date of mfg: 6/30/2007 Manufacturer: Model Number: Serial Number: White Superior 8G825 18478 Compression 4SRB 4SLB 6/30/2007 Caterpillar G3508B TB0 Compression Engine Function Engine Type: Mfg's Max. Rated Horsepower @ sea level(bhp): 800 Horsepower used for calcuations (bhp)' BSCF @ 100% Load (btu/hp-hr): Site - Rated BSCF @ 100% load (btu/hp-hr): Fuel Heating Value (btu/scf): 708.56 690.00 8000 7243 8000 7243 1000 8760 Annual hours for Permit : Max Potential Annual Fuel Consumption (MMscf/yr) White Superior 8O825 45RB 43.779589 Point Summary of Criteria Emissions (tpy) Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NCx 82.1 ;v; 82.1 91.7% V0C 2.7 1.4 2.7 50.0% CO 75.3 ^V�wvuarzi 75.3 81.8% 50x 0.0 0.0 0.0 0.0% TSP 0.5 s4y� _ - ", 0.5 0.0% PM10 0.5 0.5 0.0% PM2.5 0.5 ,r. i 0.5 0.0% Total HAPs' 0.0 0.0 1.0 50.0% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above Point Summary of Hazardous Air Pollutants (Ib/yr) HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 1368 684 1368 50.0% Methanol 274 137 274 50.0% Acetaldehyde * ' 139 50.0% Acrolein 131 50.0% Benzene * * 78 50.0% 1,3 -Butadiene * * 33 50.0% Toluene * * 28 50.0% 07WE0881.CP2.xlsm 005 & 033 (permit limits) 005 & 033 (permit limits continued) JAilf_t s3mi , The engines assigned to AIRS IDs 005 and 033 are being permitted to be used interchangeably. Specifically 033 will replace 005 should the need arise. As a result the points are being permitted with a combined fuel consumption and emissions limits. The summary calculations below are taken from the respective PAs for each engine (07WE0881-005.CP2.xlsm & 07WE0881-033.CP2.xlsm) to provide a summary of the source of each limit included in permit 07WE0881.CP2 for points 005 & 033. ;11Caterpillar G3508B 45L8 Point Summary of Criteria Emissions (tpy) Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 6.7 6.7 6.7 0.0% VOC 5.5 .................................. 5.5 50.0% CO 20.7 10.4 20.7 50.0% SOx 0.0 0.0 0.0 0.0% TSP 0.2 0.2 0.2 0.0% PM10 0.2 0.2 0.2 0.0% PM2.5 0.2 0.2 0.2 0.0% Total HAPs* 2.9 1.4 3.1 50.0% "Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above Point Summary of Hazardous Air Pollutants (lb/yr) HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 5064 2532 5064 50.0% Methanol 366 50.0% Acetaldehyde 366 183 357 50.0% Acrolein 225 50.0% Benzene " 109 50.0% 1,3 -Butadiene 57 50.0% Toluene 357 178 49 50.0% Analysis Notes: "Aka Energy provided manufacturer's catalyst information indicating a new catalyst is capab€e of perfo efficienciesfor this permit at lower pre -catalyst temperatures than those required in the O&M plan. As a result,.A#a r.., the ability to establish lower minimum precatalyst temperatures via pene c is reference method testing forthe engines.: result,stack test language was developed through consultation with the Divsion stack test coordinator to allow for annual reference mehtod testing on the engines in question. This language deviates from the Division test protocol in thatthe testmgis not required at maximum load, and may be run at the. 'as found' operating conditions (since the lower temperatures are observed when the engine is operating at <100% load capacity). Condition 41 was also added to clarify the allowable minimum pre -catalyst temperature(prior to required maintenance) based on results of the testng.The language is meant to allow for <. operation down to the minimum temperature observed during a reference method test donein accordance with.condition 46. It should also be noted that any reference mehtod testing done in accordandcewith condition 46, may substitute fer portable analyzer testing for the monitoring period specified in the O&M plan . for which the test was conducted. Update:On 7/28/2016 this request was retracted by Aka Energy and source agrees to perform appropriate mainetnance when the pre catalyst tempearture is observed outside of the range prescribed in the O&M plan 07WE0881.CP2.xlsm COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION FACILI EMISSION SUMMARY 12310098 Aka Energy Group, LLC Gl Icresi Gas Plant 13472 Weld County Road 40. Platteville Mesa County PTE - WITH ENFORCEABLE CONTROLS PTE -UNCONTROLLED POINT PERMIT Poxrpeon TSP PM10 SO2 Max VOC Fug VOC CO TOW HAP! NOx VOC Fug VOC CO Total NAPa REMARKS TOTAL prior no October 2015 package 94.1 35.2 48.7 W,7 175 eoW6 1Ca for X115 px9pe 90.9 30.04 46.7 8407 17.13 001 881 M'E0001 ansk?19035160E 4$91 tap 100 10 115 0.5 1 02 002 07WE0081 Wauk1197 24 02 I6 01 185 05 241 2 02 203 07WE001 W 2 d 0 2 tfi 0.1 15 1 0.5 24.1 0.3 64 O. W.0682. '2774242 171147 _rTA,YL NA'!?AL _RS E 00 7970 P'Czn,,0,,072007tl i.6— 005 07WE0081 3upenOr 80825, 708np q¢;; 46 h :p7{;: . 38, 137 '9 .1F 02 .. 52 .. :.: a' - - -' '1T5:01i�rt/114 famR emn41NRNIWI 043 00 t �snce V27 20!”1 007 O7WE20 57 GS 215np 62 47 117 09 129.1 9d 939 10 0 00 00 r's 360 00 00 A angel .._.oa 010 07WE0881 Plan Blonnawn Vent 53 00 53 00 011 07V/00881 Wauk07044051E 16 41 102 12 212,5 01 1898 - - - - oB 00 LtJ 0 .e. _v.,, 9 a„pe,,,,,, arias a0 00 3L - .tear., ,,,tc,. Hart ax M. 01 2.)0.5 n:er.ary 014 O7WE0081 Fugitive VOC (KKK) 20.1 31 606 6d 0 216 ,27WE080 akesn 05790061, 1215np 82 d] 117 0 0 129.1 9A 3 99 0'7 01W=d'8' 2,p99-7 97825 00 00 00 c a!I¢O=emmde,2.'<M'3 .1/ - _ 00 00 - -• + 00 00 P'00^1a 00 0 0 Jicu:on ao�Wo v.m rvov.mnaremOaoounaoon 22' 07WEa01 - anaa.za,r m vD aBL.0m 00 00 022 mwege0l rlNWwae5m Ss a1 59 6T Updated throughput sole EF. re m (routed to plant remove cordial 00 00 .. — — — 66 026 7201 Fuorbve VOO poen) l06 22 22 988 4A _- 2 -222 -000.0 osdo, 00 00 37909,19 7,1114022a re. oar; 00 00 0B o0 00 00 031 074E001 Ellenan 50m 14 TEG Deny 10 5 10 32 72 300.3 1444 New 7EGOehy 032 07WECaterpillar1 ar 1340 tap Caterpillar 259 34 139 21 25.9 6.7 278 4.3 New RICE 033 0TJJE0B81 02000 00E CaterpillarG3500, ar 690 tap •• :::::•• ::: • " " " " " ••: �• QQ , 00 — - "0266 9' *WINCE R7$FP 1jyy In4anlficenn p0 4 IW vY N4 XA Regan Gas Heater H-750 (3.00 um11 1 3 0.1 1"1 02 1 3 0.1 11 0 2 May06 Pk) NA 210 BBL produced waterlank0 1 I5 00 00 Aug 2012pkg NA XA Hot 00 Heater 41770 14 mmbNlnrl 18 0.1 15 02 10 0.1 I5 01 based on data aubmMed in May 0pkg 04 0d 0 4 0d based on data supmme4ln Oct 20150109 NA 20 210 BBL4op tank 04 00 04 0.0 FACILITY TOTAL 94.4 40.5 46.7 780 21.4 937.5 369,5 99.4 5562 173.9590 Minor PS WNA556. LU Syn Minor OR 000,00C, CO, form, bens. toluene, xylenea. total HAPS; MACS ZIIZ HH: area source Peon0ed Foo0ytNN 462 46.7 753 II 3 6344 329.1 99.0 0526 171.7 Pudle common requir.dae this Bme,pwlM emissions Increase a 25 tyy VOC however permit contains new synthetic minor limits Cnanoe in permMeo tole! -05 035 00 .130 39 (pdn0031) Modeling not required: NANSR Review not required toes Paint, associated Permitted emxions wllll the expansion associated witho00eoaton resulting elIssuance {June 18,20141 were nevrinstalled per converse0On WMOle9 Busch. 0000ellalm questa were submtlbbr points referenced above [cancellation 10/2812015) are combined for points 005 and 033 i5 allow the en9nes 10 be us 6 interchangeably permanent replacement of 005 wall 03 I HAPs are not listed ler pont 033 and the Hideo HAP emIa0n rate is Included an pont 005 to account for both points Page 8 al 10 Printed 7/28/2016 COLORADO DEPARTMENT PUBLIC IEAITH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY- HAPs 1210090 Aka Energy Group, LLC Gilcrest sPlant 3472 Weld Coupe? Road 40, Platteville Mesa County OCR 707 753 100 4094 555 e d R POINT PERMIT 0escnpeon 1 11110000..wens0 0enlze e401i01010 Toluene E.nylumrseu XyIe^es n-Hewee 224 IMP MCOH ' "^ 001 0774E0401 162E '.297 hp 361 56 222 — _ .E i .1u& 002 107 a 5 0a al CO34 273E0001 0TN60Be1 wapk llw '61 10 '7 1] 4 _2 s 0' 0.1 005 STNE0661 Super or 80025 700hp 232 ,03 .9 113 h 373 17 4 006 207 07WE0001 Wekesne 5/90651, 1215hp 1'73 119 66 112 a T 224E 20 09 07 COO 000 m0 PwE0881 Plant Slowdown Vent 01' 073E0001 WSW _7044001E 1523 157 09 140 _2 _ 2 _25 750 -z u 02 014 .e 17�. 014 074E0881 Fugitive 002 000 52 102 4094 000 0 31 23 015 05WECC10XP Hot Oil Heeler 2 C. 00 016 OTNE0081 Wakeslla 579C6911215M1p 1'73 110 fiB 212 24 69 07 022 [OTWE0001 —rues loa4oul 026 CTNE2801 Fugitive 002 411 _24 120 28390 4i 4 22 l a' 031 07WE0001 6lerean 50mincm TED Deny 2001 0 302 , ..a 594.0 032 0TNE0001 Caterpillar G3516TALE 1340 hp 3105 376 56 231 34T Ec 3 033 CTNE0661 Caterpillar 0358813 4025 690 OP n, >IAma 00 NA Rages Das Heater +750.306 M151400 22 22 _9 z: 07 36 480 77 __ 0 02 00 NA X? 210 BBL pm4ucea'ewer snk o0 NA Hot 0il-eater R-77014 Mm010400 20 24 _o _0 4 ._ 420 WO 4 11 02 2C NA 20 210002 owe law 00 ]O TOTAL 58 07 2.7 05 45 0] 1.8 4.0 O.1 1E 01 214 113 OAPs where 4nconeoll04 emissions> de re emus values Red "0000 uwonsuiles mis0ols < he mmm_s 07WE088LC➢2.rlsm 7/18/2016 COLORADO DEPARTMENT OF PUBLIC HEALTH 4240 ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY HAPs POINT PERMIT Deecnp0On 705ttett. 1 auem'an Benzene Acrdnn Toluene EIMloevene Xylenes n -Hexane 224 TMP MCOH TOTAL _ nF39� 001 07WE0881 Caterpillar G3516LE 1297 Op 6513 722 112 444 704 16 9fi 22 216 23 44 002 07WE0881 Wauk1197 321 ]7 21 34 5 54 9 02 02 003 07WE0881 Wauk1197 321 37 21 34 , 5 64 9 02 02 004 07'NE2881 NGEPS444 ,SAND NA TLRAL GAS NGN'E 005 0 E0OO0 Superior 80025 706 50 004 5.3 357 78 225 ]57 273 $ $.9 005 OIWE0880 4064674 6455.enV is 41 007 C7WE0001 Wakesha L5790001 1216np 2346 238 135 224 48 2 33 469 55 18 1.5 008 mWEc44l . 009 0'WEc881 7257072,msbesrs 010 070540881 Plant 616585mm Vent 011 07WE0001 Wauk17044001E 3245 314 178 296 62 3 45 549 750 24 21 012 M3 Os 0 N 470 0 Ho _s.,...eo tan✓S 014 05WE08O0 ON0 500 1219 1555 276 0444 1165 A4 6 2 015 OSWETOITXP Hot HMO0464161 OC 0 016 07WE0881 Wakesha L5790G51 1215np 2 346 238 135 224 46 32 860 56 18 15 022 G:WE.2GAr 210 WS 70584000214 O TT Tr 00 022 0]WEOBBI Truck lcaOpN 21 1618 01 0.1 026 07WE0881 Fuy1Ne VOC 848 1 076 261 5926.0 046 44 39 030 070550881 Genelanve pas neater o.0 0.0 031 070550661 Etlnren 50mr080 TEG Oeny 77745 133 1+1 3 847 62079 118900 144.4 389 1032 07WE0881 Caterpillar G3518TALE 134011p 6211 753 117 463 735 100 0 225 00 O 033 0]WEOB82 Caterpillar 6350880D 690 hp 00 00 0 Irel4nifi2A 0.0 NA %A Regan Gas Heater H-]501308 Mm01W10 27 30 20 27 Sz 96 40 0 77 26 5 00 C 0 NA xA nk 219 eeL produced water tank 0 NA XA Regenerator Bar gas haler 11 1O l0 n 28 r 23 0 '3 01 00 NA M 210 BBL slop tank 00 00 TOTAL 102 14 ml 10 86.0 2.a ms uJ oa ]2 pa 9ns ass 10 07WE0809.002. ds 7/28/2016 G C Ct L a/te� FN C E cia 0-4 O V L O C U L a c A z z cip M Emission Source AIRS ID: 123 [Leave blank unless APCD has already assigned a permit # & AIRS ID] O m 0 w N- O [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] >- 0 L 00 .0 9 E a nested Action (Check applicable request boxes) Section 02 — Re Section 01 —Administrative Information reported emission source t for NEW permit or newl t MODIFICATION to Change process or equipm Change permit limit CY 0 > 04 a 0❑ a a❑ ❑ HE 0❑ Aka Energy Group, LLC 9 E 0 m Gilcrest Gas Plant 13472 Weld County Road 40 O 0 • 0 A Z • 0 5 -] u 0 0 • 0 0 v LL hN- a" O O U N ing Address: 65 Mercado St., Suite 250 Durango, CO .0 u 00 CO CD C; Person To Contact: 970-375-2216 gbusch@akaenergy.com E-mail Address: one glycol pump is for backup use only 4z < Section 03 — General Information an 0 N For new or reconstructed sources, the projected startup date LO 0 0 O 3 3 o Cc -0 O O ❑ ❑ ❑ 0 0 0 z z z ❑ ❑❑O al 0 r r r 0 0❑ 7. XVII.D (total uncontrolled actual VOC emissions from all dehydration 0 Zo- o O y N 0 O C N 0 c O .4v R c Al 0 sI = 0 o •v A w =e 0 o G o FL," W C U CC c a.= L d ' z Y o g z E C T k .CC .. C O'O CrJ z O 0 0. o 9 O W a c ` o e m v o v o 0. �0. z m o' v o u O u o L m R o w c G 0 0 o v C ^ - E R 0 o C" V / y. 0 0 rr„ Q' F4 y 0 N .F s v I -.5—i •� 0 C " O A € 4 3 z'2, w° z C7 ♦ ♦ ♦ v 0 00 La rn C M M C. NNN a:ND a 9 C 0 ^m O 0 Z O oi s▪ a 0 9 Tid = ▪ E u = 0 v C e m 0. 0 °'' " o ± C OV > U tit 0 ^ O R L N S O¢ roo 0 V y p; O 0 0.5 :a L :a W . a c_ U 0 C 00 :, F _ O ://www.ailorado. 0 -0 7 0 O ate -0L en cr. C 0 ti Z w 0. ¢ Serial No.: TBD Model: TBD C w Ct N H 0 0 e e Requested2: 10 j - 0 T o v ' 0. EaJG ❑ P •0 0 n o a t y � � 5 w' 2 79 T T T T in O U o O U' -no 78 r 2 .j 12 2 m m 0 o 0. a 0 • T5 9 H N N 9 o y Y • ❑ Dehy. Gas Throughput: 0O a N h J C. 3 V R E E 0 H H 00 0 CO ❑ m 00 O. 0. 00 2 0 CO 0 a 0 00 v0 Oz . F H S w HE m 13 T C U i 0. `0 0 33 is' H 3 mu 0 0 O u c`;,' O O C 0. C O t m c c0 o " m 0 O O µ. ti F 0• � c� 0] ¢ on t o 5. � E � � R m� 9 'o a 2 o J Ca C E `202 O 0 0 ¢ • ¢ ¢ FonnAPCD-202-GlycolDehydratorAPEN-Ver. 10-11-2013. does 0 0 a Co gal O M FORM APCD-202 a O R a O V E L V 0. C O u L (14 O S C. d W z 0 cop ICI cz 0 Emission Source MRS ID: m m 0 N 0 Permit Number: Section 06 —Stack (Source, if no combustion) Location (Datum by either Lat/Long or UTM) Section 05 — Stack Information (Combustion stacks must be listed here) c CET - v CO CO W o) C7 '$ y F o 0 Ncj co CD N N Oa CO LO 11) r g z g'e Direction of stack outlet (check one): Circular: Inner Diameter (inches) _ Section 07 — Control Device Information (Indicate if a control device controls the flash tank and/or regenerator emissions) Section 08 — Emissions Inventory Information & Emission Control Information Estimation Method or Emission Factor Source o U >- U 2 O GRI-GLYCaIc 0 Ta 0 >- U 2 CD GRI-GLYCaIc GRI-GLYCaIc GRI-GLYCaIc O m 0 CD 2 U 1 GRI-GLYCaIc _J Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Pennitted Emissions vv la ca O O U F 4.6 ton/yr I 15.0 ton/yr C a N m 3,887 lb/yr T n co In co cD 1192 lb/yr 13,104 lb/yr 595 lb/yr Uncontrolled 1 (Tons/Year) 300.3 ton/yr T c0 N N 1133,172 lb/yr 13,847 lb/yr T a O) o co T a 0 m Actual Calendar Year Emissions' N u O b U F Uncontrolled (Tons/Year) o .. m Wr G A Units Ib/MMBTU U 2 2 a Ib/MMBTU U 2 2 a U 2 2 a U 2 2 s-23 Ib/MMSCF U 2 2 Uncontrolled Basis i 0) a 32.9 0.2755 co N V O Ca) 1- r N O O V m N N O Control Device Description Control Efficiency Primary Secondary (%Reduction) It PO ti, e C .'.. Pollutant 0 7> l_ 0 O U v N a`, m u 0 O H 0 G p o r W p T p `�x� x O -5 G O T ae G N L d a O e m' E N A 01C ro o m j Z N d m L co ✓ p L y C C el 0 0 V o .A • IC E \ o O O O E Q ra .e 'to i It' O 0 V on Legally Authorized to Supply D 0. Internal Combustion Enai tCa Ca 0.i C p u < o C < 4-a h k 0 U 2 L � a w m 0 c y G a z a d _ w U Q � zz a Fy w 6 co CO Z< >w F 0 0 U a A O a L F 2.0 6 5 A C W .5 Ca N p ci 0 00 0) O Emission Source AIRS ID: 9 `0 0 T.? C E C 0 0 nested Action (check applicable request boxes) Section 02 — Re Section 01 —Administrative Information -`a O C ) O. a o u Z E L .. -0 O - E e r.. a• E 'o' .u. G m U o .`E_, -7 0. Y '2 N 5 < -' Z u E 4E 6 Z L O a o 0 a L_ u u u U U u i > > C C > z zY s` 0 z C. m 0 u cri ". 0 0 <0 z� Aka Energy Group, LLC Gilcrest Gas Plant ZIP Code: 81301 65 Mercado St., Suite 250 O 0 m 0 O 970-764-6661 Phone Number: to C CD y Co a E a 0 18 U 0 V a C a L N n V _ O C N 'J 0 ≤ 0 E 0'P. C 0 rij N O a cc a Lin o o O > ` O e a 0 o 0 E u, 0 o E `o F. 3 o z,; u zult- J O Y ❑ = O <z N n C m Fax Number: gbusch@akaenergy.com 0 .. vi N- u co < N 0 < cL a m E O. y 2 Section 03 — General Information np T j2 En Y U T e, 0 N natural gas compression 0 0 0 y o = E 0 o p.,,, L. oao.r. v Z v ..-1. al a 00 Q M o. = a ..2...-2. O' , < A y *:.t. '0'0 0' G V U V V �- 'V V' V' C 0 6 a E 0 0 o o 67-; Z O u O ....°. . E" oo L o 0y 61 Z a^ a aa N YOn E L a ¢ N C C 0L a z 0 Co cA V' a y u a >' E _ L V O 6 A'� o o m ^'0 L E a = 0 O a•2. c > N.0 3 a 0 a C) a -> J C C C d V 6, :4!: , a> i 74 u-er i? o o E C > �_ - E .=0E) a.. O, o U" N 0 2 � u � ^•i. o t88 ^O 2 O 6 N, 0'C0 ci) L` 5 O O 2` : C La J > cL a C! •n .a a .q C o.° C V V Lev U<e o '? G n O :/howw.colorado APEN forms: hit d 2 o 0 Jo N = w a o a O 2 6 CO. 0 = 0 0 a 6 C E T T 6 6 O O 0 o 0 O O X O _ .O 0 V V N ❑0 El before 6/12/2006 Date engine construction commenced: before 6/12/2006 C Date of any reconstruction/modification before 7/1/2007 > = o O z 0 ❑o a, E .2 74 co O' o C' < vi 0 0 o Z E E• 0 z 0 m a U2 - on V O C m D 0 U C 9 E =O m E 'O O U E. O2 'O A a .= m u 0 a 0Q. 0 $ 0 0 o O V 0O O v L O 8 C g 0 3 3 ti 0 `o o c to a o O 0l = `J Eh 0A 7 r GO Q 0 0 u _ V 0 =' X n V C C u V __ 2 z O O 4 c, to 0 e R a C, c S 4- m CO 0 Z ea CZ 6 V] on before 7/1/2007 Ca hi C CD White Superior ❑❑ 6 J > a a 00 ❑ Ca a E m a 0 a` -4 N C .72 Cr-) 0 • O CO 0 a co O 1 E 0 a o E o 'n o V O G-7:2 = o❑ N 0 E o " = E y J O F o 0 E _ 0 .;ro 0 E a n N Ca 1 V Jo E 7 2 u 00 rv, V r_a 0 V ❑o 0 0 8 o 0 6 7 F 'a 1 0 2, C 0 E to 0 Y L 0 „ a co. El El E V X E.' C C 0 O U a ra C m J .E u ,p m 3 s- 0 Form .APCD-201-RICEAPEN-Ver.02.1020I4.docx w 0 N C N M e M FORM APCD-201 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Reci Lf) CO C) 0 0 Emission Source AIRS ID: Permit Number: 07WE0881 Section 05 — Stack Information (Attach a separate sheet with relevant information in the event of multiple stacks; provide datum & either Lat/Long or UTM) c 3 • s C 0. n V U E • 0o o u o � raC7 30 C L2 8 cn C7 40 16' 31" N 10448' 15"W co CD 30 0 Horizontal 0 Down 0 Other: Length (inches) = n h h U C L on C 7U Direction of stack outlet (check one): Exhaust Opening Shape & Size (check one): ion Information Section 06 — Fuel Consum Seasonal Fuel Use (% of Annual Use) O 0. N N OD 3 c 3 N v3 2 N .0 U C Cf) N 3 Cd) U 1000 Btu/SCF U ct 0 W 000 0 3 C C 0 U 3 Requested Permit Limit 50 MMSCFlyr 5,660 SCF/hr to W m c 0 ❑ y 0 8 w U ❑ c •rN W.1 .021 15 O 2 • c m m = 8 to 0 • i 3 to 'O 0.. e CD on r- 0 v • U C/J Estimation Method or Emission Factor Source AP 42 AP 42 AP 42 AP 42 manufacturer G3508B limit a`, 3 ' co a c E G3508B limit G3508B limit I, G3508B limit N V < Please use the APO.) Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Controlled (Tons/Year) 0.5 tons/year I 0.5 tons/year 0.5 tons/year iii co C O N o 6.8 tons/year 2.8 tons/year 13.7 tons/year 2,532 lb/year 183 lb/year 113 tb/year 139 lb/year Uncontrolled (Tons/Year) 0.5 tons/year I C s Oin 0.5 tons/year 0.02 tons/year 82.0 tons/year I 75.2 tons/year :a m coo I - Actual Calendar Year Emissions2 Controlled (Tons/Year) Uncontrolled (Tons/Year) 0 y S w lb/MMBtu CO 2. m lb/MMBtu d. a a dti Ilb/MMBtu CO � _ Ilb/MMBtu Uncontrolled Basis N 9 Vr T e- N O d r,- N 9 5. C O O to u'1 N .- V O O O C') O 0) N in O 9 C O N C') 0 o N Control Efficiency (% Reduction) e A rn p 40 a co. CO o 0 o 0 e 0 o 0 Control Device Description Secondary NSCR E a` 0 Z NSCR o z INSCR INSCR co z Pollutant TSP i CL. V3 Z> I Co u c w y a ti [ Q IBenzene U C hui0 L b u coo C) 0 U Lo - Lo -0 0 t.. EHS Technician Ill L U N m rn /w V y to L,. 0 z w 0 0 w U H O Z Z O U) w z La F-- 0 a. w J m I- O a w Na w I- ce O z E 0 U) 0) a 0 E O 0 C 0 0 co 3 a) 0 a) a) a) AIRS ID Number: 123/0098/005 c0 co O w Permit Number: Aka Energy Group, LLC Company Name: a) 0 U 0. N 13472 Weld County Road 40 Plant Location: Person to Contact: gbusch@akaenergy.com E-mail Address: Controlled Actual Emissions (lbs/year) 178 lb/yr (G3508B) 137 lb/yr Uncontrolled Actual Emissions (lbs/year) 273 lb/yr Emission Factor Source GRI LITERATURE I- a O I - co w I - a J W U- Fe cD Emission Factor (Include Units) co 2 C G 33 v 0 di co tri 0.02 g/hp-hr Control Equipment / Reduction (%) %09 .-.3L' LO Chemical Name toluene methanol Chemical Abstract Service (CAS) Number CO a O ,-- (0 r:- Co Data Applies: which Actua Calendar Year fo EHS Technician Ill (476 0 a. O D a) N .` O L z Q a) J 0 U) (1) Title of Person Legally Authorized to Supply Data ti Name of Person Legally Authorized to Supply Data (Please print) ri! 14. 2014 Form Revision Date: A C rocatinn Internal Combustion En n Permit — Reci Emission Source AIRS ID: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] C z Z W co a CO e t 0 0 0 m c 0 E. 0. a 0 s a z W = o l" o y o. ?P. Co. uested Action (check applicable request boxes) Section 02 — Re Section 01 —Administrative Information U d V 0 Ea .a d L. _ N d U ya T E 0 0 0 o r u a o n u 0 S -0 y 'E 0 a o a ` U [- L. . 0. 0. Q CO a. a.X ° ❑ ❑ r E 3 Zle Gol e 0 S d Z o O V d d 0. W V 3 L. d m 0 V CdO zL. L E u v 0 0 = 0. P P 2) O U a 0 U Z Aka Energy Group, LLC Gilcrest Gas Plant Change fuel or equipment 0. U. E 0) CC d E m CC 63 m 0 a 0. Q .. y 9 0 P ❑ ❑ x z ZIP Code: 81301 65 Mercado St., Suite 250 Emissions data must be completed. Blank A PENs will not be accepted. 0 U o6 m 0 m 0 0 N- an Phone Number: L N m m CD C V 5 0. L u 0 0 an tt cc `0 E W to Y E t ` ❑ Q a z add G3508B to permit; limits apply to this engine and to Point 005 (White Superior 8G825) Section 03 —General Information For new or reconstructed sources, the projected startup date i U) T U) Er) N v 0 E 0. .0 ` C ° °_v ° A a o c a c ti= o 0. O U a 0 v .O o 0 r: 2E o ° 3 3 o ° •c ,c c 0 00 'aD ° c '0 d 0 v v 022 c ° z O O r_O o v a 0 ° E ILI a Z 0 00 00 c r- , E Z v d 3 n fo n 2 e W C u ¢ f N r l au y o - m U. C (to. O. T CC i 'O V 0" o. E ^ O 0 D 0 E ^.. m 0- 0 mV c C. = °°°z ° 0 0 0 e _ �w = < ";0r N ` F `" a a �o �m'0 220 o V.. v a .= a °° c o dJ z a o `V V a 0 tli 0 N v ° N .`. 2 3 5 a <° � E o 2 CO. 0 v E V L V t v co m 0 0'3 u 0 C c 0 FC Q « E y h o °, o E 0 _ 28 Q t 0 ,E N 3 `_ c A- O 3 d .° m E Cd e a0 o . =TV >4-a s_ C., o° c$ L E m w o a, m q c7 t.'c. O 5 5 c .4 c i ° o � 0 a m `o a d V J .0 .o U 0 ro o ... i G V d O. Z a L, a O cC . O CU: 0 y 0 L E 6. a FE o '.74c..)<'4'.=..,,<,.Q Q 0 co H C v ,o E co co E 00 c 2 O O yV g d U G a C U O 0 co CO H into Colorado: c 0 O 1 O 0 co H N N v t r Pach co N co U) E E m 0 a c c .E 0 C ar ° U O O v a O G md o, 0 3 t 3 3� Me Information C C0 O Ch 0 u before 7/1/2007 cc co 0 CD a 0 a 3 a ❑ 0 N s a E c. a a t 3 ❑ ❑ m E 3 ° a a O O o > T E E o G. O El El CO N N m cc 0 cal CO a a o .E s a co ` .^ E_ E c' E,E` ❑0 A ° = E a N V i` co .. .. 0 E d (0 ill u '' �O H c0 E 0 ° N . ea 5 'm o "c m w u °D a E t = U m O U ❑ E E c] A z ED = O a `° Ea UQ ) c 0 0 A V � a N E U Jd A E a 0 00 6.6 a E E -o O O o n 0 0 co Q a O 0 s o 0 V V ❑� U) T 0 0 What is the maximum number of hours this engine is used for emergency back—up power? Form APCD-201-RICEAPEN-Ver.02.102014.docx N w O a W lf, ger FORM APCD-201 Internal Combustion En C3 CJ .0 M M 0 O) 0 0 M Emission Source AIRS ID: 00 00 O Permit Number: 0— iv — F` o O � n v O O 2 co 0 U 40 16' 31' N 10448'15"W co N C� > 3 U < Li. E C c C 0 D Circular. Inner Diameter (inches) = Section 06 — Fuel Consumption Information 0. Fh a w Seasonal Fuel Use (% of Annual Use) P.. s tw _ C R c�3 N N N C) w 8 0 N O 1000 Btu/SCF Requested Permit Limit 5, U Ci) C 2 E 03 4,998 SCF/hr W co rn m C) C 0 C E L � 4 E c, W C . o C) Q E E a • ~ LL o a g � C .5 d▪ l .t a in F C N 0 O C ▪ •O N O Estimation Method or Emission Factor Source 86825 limit E 03 co 86825 limit 86825 limit 03 co N a m 3 C t I 86825 limit manufacturer AP 42 AP 42 E co Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Controlled (Tons/Year) 0.5 tons/year 0.5 tons/year 0.5 tons/year 0.02 tons/year 6.8 tons/year 2.8 tons/year 113.7 tons/year ill N in N [ 183 lb/year 113 lb/year 139 lb/year Uncontrolled (Tons/Year) 5.5 tons/year 5,064 lb/year 366 lb/year 1225 lb/year Actual Calendar Year Emissions' Controlled L (Tons/Year) 8 o N 0 O 0 tons/year 0 tons/year [ 0 tons/year ii ,��. C 0 0 1 0 tons/year I0 tons/year 0) ZS O 0 lb/year 0 lb/year 0 lb/year Uncontrolled (Tons/Year) LO tons/year ta 0 O 43 9 o cis 9 O tit- 2 O I0 tons/year 43 9 o 0 lb/year O O 1 0 lb/year Emission Factor Units = COCOCO w $ [Ib/MMBtu 1 =arj 2 3 a 6. rn a. Zs) c 6. -a = 22 2 3 o 2 lb/MMBtu Uncontrolled Basis 9 0) T a 0)0 CO CD 9 00) 0) 0 al 03 m t to O 4-4 0D a .- r1 LCI 0 LU 9L1.1 r0) O 9UJ a It) 0 Ill 0 CI '- Control Efficiency (% Reduction) N I50% I � 10 10 0 � Control Device Description Secondary Primary oxidation catalyst oxidation catalyst Ioxidation catalyst Ioxidation catalyst Ioxidation catalyst Co g 0 a 10 O Pollutant &_ Formaldehyde u r C Benzene E O v .y 'C3 C C O OO •� U J q aJ ca. 4.c wo U O M N C tEJ 0• �•E 6i v RE •R N �• r ` r0 O • • c ,C a) O -0 i A a"2. C) ecs o's s rn L aJ E 0 L Co`a 0 .n Co 544 • m 4 {= e� u LO 0 TJ .. (0 4E. U ' 9 TV E .47 •-• €a:r b o $ d oa a C p C4 • F' yie u 0 U E Q w :.a co E a .o . u 3g0 D c v to D c Cf) sue. EHS Technician III L U LA O m O) R..' 0. ed to Supply Data Form APCD-20l-R)CEAPEN-Ver.02.10.2014.docx 2 z uJ L1.1 U H O z z O U, w 1- r - O I.f PPPr Q w J CO 1 - CL O 0 W CL L.L w 12 O z E 0 U) C E O C O a) U C Co O 5 0 a) a N m a) a a) 0 a) Permit Number: Aka Energy Group, LLC Company Name: ai D a U a N County: Weld 13472 Weld County Road 40 Plant Location: Phone Number: 970-764-6661 Person to Contact: gbusch@akaenergy.com E-mail Address: Controlled Actual Emissions Ibs/ ear 178 lb/yr 137 lb/yr (8G825 limit) IIG r Emission Factor Uncontrolled Source Actual Emissions (lbs/year) 357 lb/yr GRI LITERATURE GRI LITERATURE Emission Factor (Include Units) 7 CO 33 M O L.1.1 1-1O CIO O m --.43 Cr) O uJ N Control Equipment / Reduction e/o) e O 1O 50% Chemical Name a) C N 0 methanol Chemical Abstract Service (CAS) Number M CO OD O •-- <D l? 1- co Calendar Year for which Actual Data Applie V7 EHS Technician Ill Title of Person Legally Authorized to Supply Data Name of Person Legally Authorized to Supply Data (Please print) Form Revision Dat GUIDANCE FOR NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM asen- L O C O co co- To Q) 0 R O C 3 C C 3 3 O O N O O) O R O o cC Q)8 a O 0 C O O O a) a -a a d a a O C 3 E O y- 3 a .c 3 '� O o 5 -O C 0 E a) a a) R a C N E -0 C >. O R C C a E 45 `0 E om a) o EN a y W O E O o N Y O as C co a) a) R O �a co a E. a) r a) v) EE E L O a E O 0 0 a O L R a) 0 a) a U a) > a a m a ca O L. - Lai E a .= a D(Co n E o 8 0) 00 E ° ;.. c - 7 a a c m Q c a a C '5 U m CO R j> a) a. UN c EV° N Q.o Os E O c E a E O a) 3 O N 3 N C co 0 d 0 OO C `E 3'- 0<U) H O o cs c aR) U +-' Eo E o_o ..O a) 3 C > , O) Co W Z O y (n w a E¢ m a) cz a in c Q a) Z l O QN a) —.0 R3 T y r. c 00 j c) a a) r w . O c •E c (9 O 2 0 d .0 co a) t N — a co > o CO (.) .N U o a) a) m_ a E.F a .y Q as N = O C O W C 5 0 a7 W N C Q. a E L 45 Su a 9 a) ,n E 2— m 0- Q. � 4 Zr, O O Q o rn a) a to a o Nz o 00.9 E <aa) 0C° E' d N L O N E QE 3 c C)�o "° ° RC Zw� a m Z a) R O a) () C a 0 U LL ❑ W co0 VR.. U aR 0 � Rau) a) a i.: a. 0 a j-„ o L Q' a) 0< a aj 0 0.i_ m o a .` m E. c E < iis m •i. 0"O Za ❑ _a U_.Oa co =a E e co —z 00 ® �_ a a a 3 N a Z c< c .0 Q Q O 2< O C O a E a C a) U a) N X 0 R L F — d a) E_ O Z ed. co a a a) 3 C a) a 3 O a) O C O U C O EO a.a o cr -C N G O O U m a) .C T m C O :c 0 3 a U 4C ) � O.. E c• U 3 a) Wa O C C O Co C O Cr) Ia.) O a) O C U p R ,n a) 0 E a c E \ 3 - a a) O 0 o OR@ C Q y C co 0 C O' O N O W¢ d to c c o O D. y . m vi LO o Q ) O '— w R E 7 aa)) oc 0 -o •- o • O N a) F m — U E- Z w 0 E } 3 Q C Zi- U d a N R O E 0 a° 8 a) a ca a._ IEL a) y .� co c a w LL 1 a a) O 7 Y o a o w 0 Z C d C ~ O Est.= H N OU i- }°J- E a 7 •- an 3 d E c -I •.32a W O o O c -I w.E a a. U w a) a) n Q N E O Q "= o -O c Z a) o Z 2 a) C m .9 Q -0 3 W o o m >,Q C a y0 a V S - a a O w a Q) m O.- 8, .a) 0 o - -w >C a 2a`z 0 o co a) 0 O O W .C 0 U O Q' Q a) CO V) — 3 C C N E C U C a s m a "C .0 a) — i.. E R a o c O co 00 a O U O O C V a) N fn C . 3 7 a) N C O. U 3 E O a m" O a m Q a) O C 7 = 0 a) C a) c a) .9 ❑ E 'C c O Oct (n N -O Z -O L N .c c. 0 W E m O O E a O E- O 7 a a) .E a) = .w Q) ❑ -irc .E O C 3 a C ¢ C O ai W x E 0 (n D 0 R C '6 a C h o O a c = a R a C O 4) LL a Q O x R c u W 0] 'N D E .C `� JO � f° al °gym cn •E5 0E0 Q ZED_ r2 w EO.N I- CI. ink E w_r'E a �_ •E ` R '"' O . a) a) m ° E '° 3 v a a 0 d .. Z m v O a C V y _.. D p c ina. O co @ m o. a„_ c mQ m Ti c C C 0' 0 C Q C N R O r a) p O Z v— cn O E C ' la-) N L a) a 92 EE co 0-E.5 WW 7.= O a)W Q was ://www.colorado Copies of this form may be obtained on the Internet under Construction Permit Forms and APENS: Mt Form Revision Date: April 14. 2014 Ci Internal Combustion En Section 02 — Requested Action (check applicable request boxes) Section 01 — Administrative Information z .C) a: m E n ❑ L N a e a K d C7 t' e g a • S 'a) > w E d g o • e Y a o G u 5 w A - t C o E m• ix `. E E t t • o v U 4g, a 0. L _T Si E G ` v u L y qC..dr E m E - c c A U o W ; w a a F z 0 L o CO 4 w C C f, C A a • a V U aOJ P C' G' P x a x ❑' ❑ x o❑o ID ID y0E. a .0 o z u V U > • v w z Company Name: Aka Energy Group, LLC Gilcrest Gas Plant 13472 Weld County Road 40 Request APES Update Emissions data must be completed. Blank APENs will not be accepted. 0 U co O 970-764-6661 Phone Number: C add engine to faciity-wide permit Section 03 — General Information For new or reconstructed sources, the projected startup date is O o00� Mm• N N N • Nr- • C • h C 0 b Y rO,a,anw 0 0 Z rn an C C w ¢ a z s > ://www.colorado O H co Date the engine was relocated into Colorado: C O 3 z 3 (n Engine date of manufacture: TBD G3516TALE Manufacturer: t o❑ 7 J a, p P. C J P. aa rd m a. v u 3 ❑ ❑ Y • a a E'. tu 4 i g en O O 1:1 E. 0 U ❑ O M Co Combustion: O AN a 4 a) v o a e 5 E To n O J 2 4 U N V g o ' o❑ a C! ft Sv 5 o y 0 U r- 8 .5 9 v v i - N ✓] V • C C J p • a 9 o `0_ ❑Ni G 0. o • O 0 o o " v a) J E v ^. O O p p O OP -C -0 a) a O What is the maximum number of hours this engine is used for emergency back—up power? 0 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx 0 v a FORM APCD-201 ae C Internal Combustion En C 4-. R 0 L co OP co N 4.4 " W 4 r V L L P1 • C y U_ 8 • W C U C C Cl u C. w W V F� O W z o N- r )ll 1-1 O F4 Permit Number: F 00 O 7 V a -74 'O -o 0 C4 Y M N a j 0 N c CO w .— E v t C N V Ci Q. V Jal CC e 0 V O O V UP N N or cn N O Ln N E ❑ R 2 0 ection 06 — Fuel Consum a .0 C' v 0 o a 0 C' C • Estimation Method or Emission Factor Source N v a a AP 42 AP 42 N c a a manufacturer manufacturer/AP 42 manufacturer manufacturer N v a of AP 42 GRI LITERATURE Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions O O q 2 O O U F " 03 0 o L0 O 0.5 tons/year c c O I O 0.03 tons/year 25.9 tons/year 3.4 tons/year 139 tons/year 3,105 lb/year 376 lb/year 231 lb/year 59 lb/year Uncontrolled (Tons/Year) 0.5 tons/year 0.5 tons/year 0.5 tons/year N o CC C o m O O N N y a co Lri N N 6.7 tons/year 27.8 tons/year 6,211 lb/year 753 b/year 463 lb/year 117 lb/year Actual Calendar Year Emissions2 Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor ai--- 0 2 2 a 0 2 2 a 0 2 2 a = 2 2 a r L a L L a L a of L L a 0 2 2 D 0 2 2 a 2 2 a Uncontrolled Basis.'. co 0 W 0)000 0) rn n 0 U) O) O) Co 9 W O (Si or 0 W <O Cd O, N N` Un O N 0.24 m O LEI (o )n W a o W V 1(I in 9 W O n Control. Efficiency (%Reduction) VI a in e On o in in e ON Control Device Description gi 0D a oxidation catalyst oxidation catalyst Ioxidation catalyst Ioxidation catalyst oxidation catalyst oxidation catalyst II TSP Formaldehyde IAcetaldehyde O '- o 0. V 9 V m CL iO 4 y C • V • , E o O O O CC O O J U t t N U m 3 a E O O f] N C v B L . O E cicc a m C `u o▪ w z a a O t v - 3c� C t L N " CO `v m E x 9 .0 0 a CO W a v 0 3_y 0 o 0 ci C' a EHS Technici N 0 m C) (7 F Ct APCD-201-RI CEAPEN-V er.02.10.2014.docx 2 z W Q w C-) H O z z O - �C7) VJ y W m Hv a Z E Q I I- U r O J o J a O rn a `o re 43 av `62) d CO 0. re U O AIRS ID Number: 123/0098/ CO CO O W O Permit Number: Aka Energy Group, LLC a) O U n N a) O U 13472 Weld County Road 40 ui E m o z co T U O o N J d w E c O 0 0 a Person to Contact: gbusch@akaenergy.com E-mail Address: Controlled Actual Emissions Ibs/ ear 368 lb/yr Uncontrolled Actual Emissions Ibs/ ear 735 lb/yr Emission Factor Source GRI LITERATURE Emission Factor (Include Units) 5.15E-03 lb/MMBtu Control Equipment / Reduction (%) 89- o Chemical Name CD C) O Chemical Abstract Service (CAS) Number M ib CO C) 0 Calendar Year for which Actual Data Applies a) co 0 EHS Technician Ill Title of Person Legally Authorized to Supply Data Name of Person Legally Authorized to Supply Data (Please print) N Form Revision Date: A GUIDANCE FOR NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM O (a co -- C C _c o N Two -o co w a) Oct 2 w 0 2 E 9 oc E a) 7 C C 3 T = 7 a O- C O O O) -O N N O O. 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O a `' E E W ial E 0 ° a a o 00 Q r '6 041 O t .C N N_ P P U O P P P V V .- z rt x z 0� x 08 3 ❑ ❑ S ED 13472 Weld County Road 40 Source Location: Co C U Mailing Address: 65 Mercado St., Suite 250 CO O cLi D CD m co E ❑ O Person To Contact: gbusch@akaenergy.com E-mail Address: N N N O a m N O O 0 a° C) 0 a 0 N N 0 0x N 0 0 0 a, E 0 0 0 U 0 E m Addl. Info. & Notes: Section 03 — General Information Ca 3 an v 3 Co a 0 v ° N Normal (lours of Source Operation: condensate loadout 3 O ❑ Q O O El ODD 0 z 0 z z z E ❑ o❑o <N 6 a >-a >6 'T > >- ❑ ❑ ❑o❑ 0 N N Ca a C 0 0 N a Ca v g ci 0 n - a 0 v c O O s 'OU NO O d o c p 0 o >-)a J O C `o a v J 2 s E 2 G N - n a O c N 0 0 V 0 Ca .^� 004 V c ai c 0 = o a v s > o 42 E z 0 0 c V1 ay a �e Z m a M M M O1 Q- y p T a P a, a a Ng —u r', o g c' m 0, y a E 0 0 0 m ti 0, r 2 L m q,� - o d 1 6L O c4 a- 7 C p i a 3 m ca _ cy t Y u " a 02 Ca _:'''.1? -'; R U, u eo u Cs c a- x - E 3 p n i, c` E. a .E � 0`6 G (.5 s 0 O m Ti ). 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N . en ° ° a p p, u v a 2 -araE v Q, o o ..7 7 >. v J y y 0 v 4-2 Ida, ca. o N$ Y aI o A -5 a3 o o Er, Ca O O♦ 1 A A< m a D 3 - r U e s a 0E Q F o 5 a n 0 ,s L U 0 ❑ a O O y O 4c e o y 6 V L V �x O � U m L ❑Ca 1 0 0 L C - a z aWE zt F+ J - y J U ca a . a E 0 e a 3 o E 0 c a a S Y ma E 0 p. — J O ^ 0 m E c U w0. 0 a N L 0 Ca VN 0 h E V V .`91 m8 U O V a 2 TA L 0 .2 0 N C FORM APCD-208 rmAPCD-208-IlydrocarbonLiquidLoadingAPEN-Ver.4-14-2014 (1).docx O OO uid Loadin 0 .44 L O „ bo 0 Q I w — L C .ca P. -I C L' O A 0 C o O L y to — c E 0 U ot; V 00 5 u a 0 z Co t W U Q tra w � 4 2A rl m 0 i O W O N- 4 a aN O Permit Number: Ce C➢ V .23 0 C 0 R 0 O C .0 O OC 0 L C a C 0 Section 05— Stack Information (Combustion stacks must be listed here) 0� C c E 8Lk u 'o y o 0 c 9 O U t 0 C W 0) CD v n -104.801584° O Ct 0 1. 0 a_. N F v .0 it L N J 0 3 O h O n4 Section 07— Control Device Information Section 08 — Emissions Inventory Informa E a O C O C O E c. L V Y L a C C C) cd a C 0 C) CC R U7 rn O y V 0 a F7 .0 L 0 c c w a .i cn N O C Condensate -a 724 X 0 CC .0 C9 C 0 C) N c a o V C C V L U Data year for actual calendar year emissions below & throughput in Sec. 04 (e.g. 2007): C- O E L G CL C CC ti i .0 CC C O C C E Ce .O. C V C O E w El Estimation Method or Emission Factor Source U a Q APCD APCD Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Controlled (Tons/Year) 5.9 ton/yr IS r NI 15-1 00 r Uncontrolled (Tons/Year) 5.9 ton/yr 21 lb/yr co Actual Calendar Year Emissions Controlled (Tons/Year) `Uncontrolled I (Tons/Year) Emission Factor CC 43 43 p.. _0 _0d .0 _.�.. .0 _0 Uncontrolled Basis Co C) N0 V 0 r0 0 O 0 0 Control Efficiency (%Reduction) { h ki fG,12 Li ah 4i' r.. r }'; O CA Control Device Description b 0 'r' E a'I i IG tyE a cc di7 tu R : '5 0 ... _: X coo z U > V V V 3 R X 3 L C R u a E dE u L o.- § CC O Ln 0 0 0 .= CC C R C Ce s 4 3 'C E `C 00 z • O EL 0 0 EA_ g C? C_ . Ea E C CC C A u R L Ce E d e e W L " a c S C 03 4. C R O C V c � E N c O Z Y y � c,C e C y r 0 T F u O u Z > cit.)ecit.) c.4 z c 3 4 S 4.V V y 2 ag a 5 • C7 e C 9e La V O .- 0 '1.= T gi m g-' L G u C d L a 0 CC S G CO VL c E .0 G E k a Y Q � Q\ L CO .J .0 A for coverage and EHS Technician III 0 0 N CC Hello