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Home My WebLink About20131006.tiffSTATE OF COLORADO John W. Hickenlooper, Governor Christopher E. Urbina, MD, MPH Executive Director and Chief Medical Officer Dedicated to protecting and improving the health and environment of the people of Colorado 4300 Cherry Creek Dr. S. Denver, Colorado 80246-1530 Phone (303) 692-2000 Located in Glendale, Colorado http://www.cdphe.state.co.us Weld County Clerk & Recorder 1402 N 17th Ave Greeley, CO 80631 April 22, 2013 Dear Sir or Madam: Laboratory Services Division 8100 Lowry Blvd. Denver, Colorado 80230-6928 (303) 692-3090 RECEIVED APR 2p 2'013 WELD COUNTY _WELD Colorado Department of Public Health and Environment On April 25, 2013, the Air Pollution Control Division will publish a public notice for Sterling Energy Investments, LLC. — Centennial Gas Plant, in the The Greeley Tribune. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the date the public notice is published. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health & Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure rplitit 0e0740 q/1, PL, yixe 2O13-1OO6 STATE OF COLORADO John W. Hickenlooper, Governor - Christopher E. Urbina, MD, MPH Executive Director and Chief Medical Officer Dedicated to protecting and improving the health and environment of the people of Colorado 4300 Cherry Creek Dr. S. Denver, Colorado 80246-1530 Phone (303) 692-2000 Located in Glendale, Colorado http://www.cdphe.state.co.us Laboratory Services Division 8100 Lowry Blvd. Denver, Colorado 80230-6928 (303) 692-3090 Colorado Department of Public Health and Environment Website Title: Sterling Energy Investments, LLC. — Natural Gas Processing Plant — Weld County Released To: On: Published: The Greeley Tribune April 22, 2013 April 25, 2013 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Facility: Sterling Energy Investments, LLC. Centennial Gas Plant Natural Gas Processing Plant SESW Section 25, Township 9 North, Range 61 West Weld County The proposed project or activity is as follows: The applicant proposes to construct a new natural gas processing facility with a throughput of 10 MMscf/day The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section IILC due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, including supplemental information, the Division's analysis, and a draft of Construction Permit 12WE2117 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at www.colorado.gov/cdphe/AirPublicNotices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Stuart Siffring Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 CONSTRUCTION PERMIT PERMIT NO: 12WE2117 Issuance 1 DATE ISSUED: ISSUED TO: Sterling Energy Investments LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Centennial Gas Plant, located in SESW S25 T9N R61W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description C001 001 One (1) Waukesha, Model L7044GSI, Serial Number To Be Determined, 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. C002 002 One (1) Waukesha, Model L7044GSI, Serial Number To Be Determined, 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. G001 003 One (1) Waukesha, Model L7044GSI, Serial Number To Be Determined, 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 power production. AIRS ID: 123/9966 Page 1 of 28 NGEngine Version 2012-1 Colorado Department of Public Health and Environment Air Pollution Control Division Facility Equipment ID AIRS Point Description G002 004 One (1) Waukesha, Model L7044GSI, Serial Number To Be Determined, 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 power production. P001 005 One (1) Caterpillar, Model G3306, Serial Number 07Y02221, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 220 horsepower at 1800 RPM. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for Propane compression. R001 006 One (1) Caterpillar, Model G3408TA, Serial Number TBD, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 400 horsepower at 1800 RPM. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for residue compression. R002 007 One (1) Caterpillar, Model G3412, Serial Number TBD, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 600 horsepower at 1800 RPM. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for residue compression. DEHY001 008 One (1) Triethylene glycol (TEG), natural gas dehydration unit (custom built, serial number:TBD) with a design capacity of 9.92 MMscf per day. This emissions unit is equipped with one (1) electric glycol pump, make, model, and serial#, TBD, with a design capacity of 2.5 gallons per minute. This unit is equipped with a flash tank, reboiler and still vent. Still vent emissions are routed to a condenser and then to the thermal oxidizer. Flash tank emissions are routed to the thermal oxidizer. AIRS ID: 123/9966 Page 2 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division Facility Equipment ID AIRS Point Description AMINE001 009 Methyldiethanolamine (MDEA) natural gas sweetening system for acid gas removal with a design capacity of 9.92 MMSCF per day (custom built serial number:TBD). This emissions unit is equipped with one (1) electric amine recirculation pump, make, model, and serial #, TBD, with a design capacity of 40 gallons per minute.. This system includes a natural gas/amine contactor, a flash tank, and a natural gas fired amine regeneration reboiler. All emissions from the still vent and flash tank are routed to the thermal oxidizer. FUG001 010 Equipment leaks (fugitive VOCs) from a Natural Gas Processing Plant. TO001 011 Thermal Oxidizer as a control for waste streams of Amine unit and Dehydration unit. TL001 012 NGL Truck loading These engines may be replaced with another engine in accordance with the temporary engine replacement provision or with 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. 2. Within one hundred and eighty days (180) after commencement of operation, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, 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 AIRS ID: 123/9966 Page 3 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division deadline per Regulation No. 3, Part B, 111.F.4.b. (Reference: Regulation No. 3, Part B, I I I. 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 1II.E.) 5. The following information shall be provided to the Division within fifteen (15) days after commencement of operation. • manufacture date • construction date • order date • date of relocation into Colorado • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, II1.E.) 6. 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 7. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Monthly Limits: Facility Equipment ID AIRS Point Pounds per Month Emission Type NO,, VOC CO C001 001 730 357 935 Point C002 002 730 357 935 Point G001 003 730 357 935 Point G002 004 730 357 935 Point P001 005 109 40 108 Point R001 006 198 85 196 Point R002 007 298 108 294 Point DEHY001 008 --- 109 --- Point AMINE001 009 --- 88 --- Point FUG001 010 --- 7577 --- Fugitive TO001 011 753 --- 1142 Point TL001 012 --- 1573 --- Point (Note: Monthly limits are based on a 31 -day month.) AIRS ID: 123/9966 Page 4 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division The owner or operator shall calculate monthly emissions based on the calendar month. Facility -wide emissions of each individual hazardous air pollutant shall be less than 1,359 lb/month. Facility -wide emissions of total hazardous air pollutants shall be less than 3,398 lb/month. Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type NO, VOC CO C001 001 4.3 2.1 5.5 Point C002 002 4.3 2.1 5.5 Point G001 003 4.3 2.1 5.5 Point G002 004 4.3 2.1 5.5 Point P001 005 0.6 0.2 0.6 Point R001 006 1.2 0.5 1.2 Point R002 007 1.7 0.6 1.7 Point DEHY001 008 --- 0.6 --- Point AMINE001 009 --- 0.5 --- Point FUG001 010 --- 44.6 --- Fugitive T0001 011 4.4 --- 6.7 Point TL001 012 --- 9.3 --- Point See "Notes to Permit Holder' for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility -wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. 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. 8. Point 008: 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, VRU downtime and other operational values specified in the AIRS ID: 123/9966 Page 5 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division 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. 9. Point 010: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent extended 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. 10. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled C001 001 NSCR catalyst and air/fuel ratio controller NOx, CO, VOC C002 002 NSCR catalyst and air/fuel ratio controller NOx, CO, VOC G001 003 NSCR catalyst and air/fuel ratio controller NOx, CO, VOC G002 004 NSCR catalyst and air/fuel ratio controller NOx, CO, VOC P001 005 NSCR catalyst and air/fuel ratio controller NOx, CO R001 006 NSCR catalyst and air/fuel ratio controller NOx, CO, VOC R002 007 NSCR catalyst and air/fuel ratio controller NOx, CO DEHY001 008 Condenser and Thermal Oxidizer VOC, HAP's AMINE001 009 Condenser and Thermal Oxidizer VOC, HAP's PROCESS LIMITATIONS AND RECORDS 11. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 days) C001 001 Consumption of natural gas as a fuel 98'25 MMscf/yr 8.35 MMscf/month C002 002 Consumption of natural gas as a fuel 98.25 MMscf/yr 8.35 MMscf/month G001 003 Consumption of natural gas as a fuel 98.25 MMscf/yr 8.35 MMscf/month AIRS ID: 123/9966 Page 6 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division G002 004 Consumption of natural gas as a fuel 98.25 MMscf/yr 8.35 MMscf/month P001 005 Consumption of natural gas as a fuel 12.29 MMscf/yr 1.04 MMscf/m/month R001 006 Consumption of natural gas as a fuel 21.17 MMscf/yr 1.8 MMscf/month R002 007 Consumption of natural gas as a fuel 32.67 MMscf/yr 2.8 MMscf/month DEHY001 008 Throughput of natural gas 3620.8 MMscf/yr 307.6 MMscf/month AMINE001 009 Throughput of natural gas 3620.8 MMscf/yr 307.6 MMscf/month TO001 011 Consumption of natural gas MMscf/yr 18.6 MMscf/yr TL001 012 Trucks loaded 4,157 loads/yr 354 loads/mm onth 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. 12. Point 008: This unit shall be limited to the maximum lean glycol circulation rate of 2.5 gallons per minute. The lean glycol recirculation rate shall be recorded weekly in a log maintained on site and made available to the Division for inspection upon request. (Reference: Regulation No. 3, Part B, II.A.4) 13. Point 009: This unit shall be limited to the maximum amine circulation rate of 40 gallons per minute. The amine recirculation rate shall be recorded weekly in a log maintained on site and made available to the Division for inspection upon request. (Reference: Regulation No. 3, Part B, II.A.4) STATE AND FEDERAL REGULATORY REQUIREMENTS 14. 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) 15. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) AIRS ID: 123/9966 Page 7 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division 16. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 17. Points 001-006, 007: This equipment is subject to the control requirements for natural gas -fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas -fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Maximum Engine HP Construction or Relocation Date Emission 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 ≥500HP 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. 18. Point 008: The flare covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). If a flare or other 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. The operator shall comply with all applicable requirements of Section XVII. 19. Point 008: This equipment is subject to the control requirements for glycol natural gas dehydrators under Regulation No. 7, Section XVII.D (State only enforceable). Beginning May 1, 2008, 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 an average of 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 XVII. 20. Point 008: This source is subject to the 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: AIRS ID: 123/9966 Page 8 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division • §63.764 - General Standards o §63.764 (e)(1) -The owner or operator of an area source is exempt from the requirements of paragraph (d) of this section if the criteria listed in paragraph (e)(1)(i) or (ii) of this section are met, except that the records of the determination of these criteria must be maintained as required in §63.774(d)(1). • §63.764 (e)(1)(ii) — The actual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere are less than 0.90 megagram per year, as determined by the procedures specified in §63.772(b)(2) ofthis subpart. • §63.772 - Test Methods, Compliance Procedures and Compliance Demonstration O §63.772(b) - Determination of glycol dehydration unit flowrate or benzene emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate or benzene emissions to meet the criteria for an exemption from control requirements under §63.764(e)(1). • §63.772(b)(2) - The determination of actual average benzene emissions from a glycol dehydration unit shall be made using the procedures of either paragraph (b)(2)(i) or (b)(2)(ii) of this section. Emissions shall be determined either uncontrolled, or with federally enforceable controls in place. • §63.772(b)(2)(i) — The owner or operator shall determine actual average benzene emissions using the model GRI- GLYCaIc TM , Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCalc TM Technical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI-95/0368.1); or • §63.772(b)(2)(ii) The owner or operator shall determine an average mass rate of benzene emissions in kilograms per hour through direct measurement using the methods in §63.772(a)(1)(i) or (ii), or an alternative method according to §63.7(f). Annual emissions in kilograms per year shall be determined by multiplying the mass rate by the number of hours the unit is operated per year. This result shall be converted to megagrams per year. §63.774 - Recordkeeping Requirements o §63.774 (d)(1) - An owner or operator of a glycol dehydration unit that meets the exemption criteria in §63.764(e)(1)(i) or §63.764(e)(1)(ii) shall maintain the records specified in paragraph (d)(1)(i) or paragraph (d)(1)(ii) of this section, as appropriate, for that glycol dehydration unit. AIRS ID: 123/9966 Page 9 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division o §63.774 (d)(1)(ii) - The actual average benzene emissions (in terms of benzene emissions per year) as determined in accordance with §63.772(b)(2). 21. Point 008.and 009: The operating temperature of the regenerative thermal oxidizer used to control emissions from this dehydration unit and amine unit shall be greater than 1400 °F , or the temperature established during the most recent stack test of the equipment that was approved by the Division, at all times that any dehydration unit or amine unit still vent emissions are routed to the thermal oxidizer in order to meet the emission limits in this permit. 22. Point 009: The concentration of amine (MDEA plus DEA plus piperazine) in the lean amine stream shall not exceed 50 weight percent on a monthly average basis. Records of the concentration of amine in the lean amine stream shall be kept according to the operating and maintenance plan for this point and shall be made available to the Division for inspection upon request (Colorado Regulation No. 3, Part A, II). 23. Point 009: The permit holder shall measure and record the following amine unit operating parameters for each amine unit. Records of these operating parameters shall be made available to the Division for inspection upon request. (Colorado Regulation No. 3, Part A, II): a. The operating temperature of the regenerative thermal oxidizer shall be recorded daily. b. The lean amine strength shall be measured and recorded on a daily basis. The lean amine strength is defined as the combined weight percent of MDEA, DEA and piperazine in the lean amine stream. c. Fuel use by each regenerative thermal oxidizer shall be measured or calculated and recorded on a monthly basis. 24. Point 009: This amine unit is subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart OOOO, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution including, but not limited to, the following: • §60.5365 — Applicability and Designation of Affected Facilities o §60.5365(g)(3) - Facilities that have a design capacity less than 2 long tons per day (LT/D) of hydrogen sulfide (H2S) in the acid gas (expressed as sulfur) are required to comply with recordkeeping and reporting requirements specified in §60.5423(c) but are not required to comply with §§60.5405 through 60.5407 and §§60.5410(g) and 60.5415(g). • §60.647 — Record keeping and reporting Requirements o §60.5423(c) - To certify that a facility is exempt from the control requirements of these standards, for each facility with a design capacity less that 2 LT/D of H2 S in the acid gas (expressed as sulfur) you must keep, for the life of the facility, an analysis demonstrating that the facility's design capacity is less than 2 LT/D of H2 S expressed as sulfur AIRS ID: 123/9966 Page 10 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division 25. Point 009: The operator shall sample the inlet gas to the plant, on an annual basis, to determine the concentration of hydrogen sulfide (H2S) and total sulfur in the gas stream. The sample results shall be monitored to demonstrate the amine unit qualifies for the exemption contained in §60.5365 listed above. The sample results shall also be monitored to demonstrate that the total sulfurs concentration, including H2S, in the gas stream is equal to 0 ppm. 26. Point 010: The fugitive emissions addressed by AIRS ID 010 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). 27. Point 010: The reciprocating compressors grouped with the fugitive emissions addressed by AIRS ID 010 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: • §60.5385(a) — Owner or operator must!replace the reciprocating compressor rod packing according to either paragraph §60.5385(a)(1) or (2). (i) §60.5385(a)(1) - Before the compressor has operated for 26,000 hours. The number of hours of operation must be continuously monitored beginning upon initial startup of your reciprocating compressor affected facility, or October 15, 2012, or the date of the most recent reciprocating compressor rod packing replacement, whichever is later. (ii) §60.5385(a)(2) - Prior to 36 months from the date of the most recent rod packing replacement, or 36 months from the date of startup for a new reciprocating compressor for which the rod packing has not yet been replaced. • §60.5410 — Owner or operator must demonstrate initial compliance with the standards as detailed in §60.5410(c). • §60.5415 — Owner or operator must demonstrate continuous compliance with the standards as detailed in §60.5415(c). AIRS ID: 123/9966 Page 11 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division • §60.5420 - Owner or operator must comply with the notification, reporting, and recordkeeping requirements as specified in §60.5420(a), §60.5420(b)(1), §60.5420(b)(4), and §60.5420(c)(3). OPERATING & MAINTENANCE REQUIREMENTS 28. Points 001-009: 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.) 29. Point 008: The condenser outlet temperature shall be recorded as per the frequency required in the approved O&M Plan. This information shall be maintained in a log on site and made available to the Division for inspection upon request. The condenser outlet temperature shall not exceed 160 °F on a monthly average basis. 30. Point 009: The inlet gas temperature and inlet gas pressure shall be measured and recorded monthly. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 31. Points 001-007: A source initial compliance test shall be conducted on emissions points 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. Volatile Organic Compounds using EPA approved methods Formaldehyde using EPA approved methods 32. Point 008 and 009: A source initial compliance test shall be conducted on Points 008 and 009 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with in this permit. The operator shall also demonstrate the thermal oxidizer achieves a minimum destruction efficiency of 99.0% for VOC. The operator shall measure and record, using EPA approved methods, VOC mass emission rates from the thermal oxidizer inlet and outlet to determine the destruction efficiency of the thermal oxidizer (ProMax/Amine Calc/GlyCalc models shall not be used to determine the flow rate or composition of the waste gas sent to the thermal oxidizer for the purposes of this test). The natural gas throughput to the dehy unit, natural gas throughput to the amine unit, lean glycol circulation rate, lean amine circulation rate, MDEA/DEA/piperazine concentration, and sulfur content of sour gas entering the amine unit shall be monitored and recorded during this test. The flow rate of supplemental fuel AIRS ID: 123/9966 Page 12 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division fired in the thermal oxidizer shall be monitored and recorded during the test, and the Btu content of such gases shall be determined using the appropriate ASTM Methods or equivalent, if approved in advance by the Division. The operator shall also measure and record combustion temperature during the initial compliance test to establish the minimum combustion temperature. The test protocol mustbe 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) Volatile Organic Compounds using EPA approved methods. Hazardous Air Pollutants using EPA approved methods. Sulfur Dioxide using EPA approved methods Oxides of Nitrogen using EPA approved methods Carbon Monoxide using EPA approved methods 33. Point 008 and 009: In the event that supplemental fuel or any additional gas streams are used during the initial compliance test required by Condition 32, the owner or operator shall apply for a modification to this permit to modify emission limits to account for supplemental fuel firing as necessary, and to add the requirement to install, maintain and operate inline flow meters on the following: waste gas feed to the thermal oxidizer, and supplemental/make-up fuel feed to the thermal oxidizer. The application shall be submitted within 60 calendar days following the completion of the compliance test. 34. Point 008 and 009: Within 60 calendar days following the completion of the compliance test required by Condition 32, the owner or operator shall update and re -submit the O&M Plan for this unit to include the minimum combustion chamber temperature established during the compliance test. The O&M Plan shall be updated to require daily combustion chamber temperature monitoring 35. Point 010: The owner or operator shall complete the initial sour gas analysis testing required by this permit and submit the results to the Division as part of the self - certification process to ensure compliance with emissions limits. (Reference: Regulation No. 3, Part B, Section III.E.) 36. Point 010: 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. 37. Point 010: Within one hundred and eighty days (180) after commencement of operation, the owner or operator shall complete the initial extended gas analysis of gas samples and extended natural gas liquids analysis of liquids that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as AIRS ID: 123/9966 Page 13 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division fugitive emissions. This extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the gas and liquids analyses and emission calculations to the Division as part of the self -certification process to ensure compliance with emissions limits. Periodic Testing Requirements 38. On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples and an extended natural gas liquids analysis of liquids that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis OR gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. 39. Points 001-007: This engine is 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 40. Point 008: The owner or operator shall complete an extended wet gas analysis prior to the inlet of the TEG dehydrator 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. 41. Point 009: The operator shall sample theinlet gas to the plant or the inlet gas to the amine unit on an annual basis to determine the concentration of hydrogen sulfide (H2S) in the gas stream. The sample results shall be monitored to demonstrate that this amine unit qualifies for the exemption from the Standards of Performance for Onshore Natural Gas Processing: SO2 Emissions (§60.5423(c)). ADDITIONAL REQUIREMENTS 42. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For 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 AIRS ID: 123/9966 Page 14 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division 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. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative -operating scenario and is installing a permanent replacement engine. 43. 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). 44. MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this stationary source at any such time that this stationary source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of Subpart HH. (Reference: Regulation No. 8, Part E) 45. MACT Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of that Subpart on the date as stated in the rule as published in the Federal Register. (Reference: Regulation No. 8, Part E) GENERAL TERMS AND CONDITIONS: 46. 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. 47. 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 AIRS ID: 123/9966 Page 15 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division obtaining final authorization to operate are located in the Requirements to Self - Certify for Final Authorization section of this permit. 48. 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. 49. 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. 50. 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. 51. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 52. 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: Stuart Siffring Permit Engineer Permit Histo Issuance ry Date Description AIRS ID: 123/9966 Page 16 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division Issuance 1 This Issuance Issued to Sterling Energy Investments LLC. New Synthetic Minor Gas Plant. AIRS ID: 123/9966 Page 17 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division Notes to Permit Holder at the time of this permit issuance: 1) 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. 2) 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/regulations/airreqs/100102agcccommonprovisionsreq.pdf. 3) 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. AIRS Point Pollutant CAS # BIN Uncontrolled Emission Rate (Ib/yr) Are the emissions reportable? Controlled Emission Rate (lb/yr) 001 Formaldehyde 5000 A 2336 Yes 2336 Acetaldehyde 75070 A 318 Yes 318 Acrolein 107028 A 300 Yes 300 Benzene 71432 A 180 Yes 180 1,3 -Butadiene 106990 A 76 Yes 76 002 Formaldehyde 5000 A 2336 Yes 2336 Acetaldehyde 75070 A 318 Yes 318 Acrolein 107028 A 300 Yes 300 Benzene 71432 A 180 Yes 180 1,3 -Butadiene 106990 A 76 Yes 76 003 Formaldehyde 5000 A 2336 Yes 2336 Acetaldehyde 75070 A 318 Yes 318 Acrolein 107028 A 300 Yes 300 Benzene 71432 A 180 Yes 180 1,3 -Butadiene 106990 A 76 Yes 76 004 Formaldehyde 5000 A 2336 Yes 2336 Acetaldehyde 75070 A 318 Yes 318 Acrolein 107028 A 300 Yes 300 Benzene, 71432 A 180 Yes 180 1,3 -Butadiene 106990 A 76 Yes 76 AIRS ID: 123/9966 Page 18 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division 005 Formaldehyde 5000 A 292 Yes 292 504 006 Formaldehyde 5000 A 504 Yes Acetaldehyde 75070 A 69 Yes 69 Acrolein 107028 A 65 Yes 65 007 Formaldehyde 5000 A 777 Yes 777 Acetaldehyde 75070 A 106 Yes 106 Acrolein 107028 A 100 Yes 100 Benzene 71432 A 60 Yes 60 008 Benzene 71432 A 61860 Yes 620 Toluene 108883 C 77320 Yes 780 Ethylbenzene 100414 C 20480 Yes 200 Xylenes 1330207 C 61780 Yes 620 n -Hexane 110543 C 10580 Yes 100 009 Benzene 71432 A 13100 Yes 131 Toluene 108883 C 5550 Yes 56 n -Hexane 110543 C 1450 Yes 15 010 Benzene 71432 A 78 Yes 78 4) The emission levels contained in this permit are based on the following emission factors: Points 001-004: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr NOx 3.78 13.3 0.095 0.30 CO 3.18 11.2 0.095 0.30 VOC 9,9E-2 0.35 3.6E-2 0.13 5000 Formaldehyde 2.05E-2 7.2E-2 2,05E-2 7.2E-2 75070 Acetaldehyde 2.7E-3 9.8E-3 2.7E-3 9.8E-3 107028 Acrolein 0.00263 9.2E-3 0.00263 1 9,2E-3 71432 ' Benzene 0.00158 5.5E-3 0.00158 5.5E-3 106990 I 1,3 -Butadiene 0,000663 0.002 0.000663 0.002 Emission factors are based on a Brake-Spec'fic Fuel Consumption Factor of 7744 Btu/hp-hr, a site -rated horsepower value of 1680, and a fuel heat value of 1160 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 5000 Formaldehyde AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 75070 Acetaldehyde AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 107028 Acrolein AP -42; Table 3.2-3 (7/2000); Natural Gas No Control AIRS ID: 123/9966 Page 19 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division CAS Pollutant Uncontrolled EFSource Controlled EF Source 71432 Benzene AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Point 005: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors- g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr NOx 6.93 23.27 9.0E-2 - 0.30 CO 0.47 1.6 8.91E-2 0.30 VOC 3.27E-2 0.12 3.27E-2 0.12 5000 Formaldehyde 2.05E-2 6.87E-2 2.05E-2 6.87E-2 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 7396 Btu/hp-hr, a site - rated horsepower value of 220, and a fuel heat value of 1160 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 5000 Formaldehyde AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Point 006: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr NOx 7.32 26.27 9.51E-2 0.30 CO 0.50 1.6 9.41E-2 0.30 VOC 3.46E-2 0.16 2.81E-2 0.13 5000 Formaldehyde 2.05E-2 6.51E-2 2.05E-2 6.51E-2 _75070 Acetaldehyde 2.79E-3 8.86E-3 2.79E-3 8.86E-3 107028 Acrolein 0.00263 8.36E-3 0.00263 8.36E-3 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 7008 Btu/hp-hr, a site - rated horsepower value of 400, and a fuel heat value of 1160 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 5000 Formaldehyde AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 75070 Acetaldehyde AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 107028 Acrolein AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Point 007: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr NOx 7.11 23.27 9.25E-2 0.30 CO 0.49 1.6 9.14E-2 0.30 VOC 3.36E-2 0.11 3.36E-2 0.11 5000 Formaldehyde 2.05E-2 0.067 2.05E-2 0.067 AIRS ID: 123/9966 Page 20 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division CAS Pollutant Emission Uncontrolled Ib/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr 9.12E-3 75070 Acetaldehyde 2.79E-3 9.12E-3 2.79E-3 107028 Acrolein 0.00263 8.60E-3 0.00263 8.601E-3 71432 Benzene 0.00158 5.16E-3 0.00158 5.16E-3 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 7210 Btu/hp-hr, a site - rated horsepower value of 600, and a fuel heat value of 1160 Btu/scf. Emi CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 5000 Formaldehyde AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 75070 Acetaldehyde AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 107028 Acrolein AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 71432 Benzene AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Point 008: The emission levels contained in this permit are based on information provided in the application and the GRI GlyCalc 4.0 model. Point 009: The emission levels contained in this permit are based on the following emission factors: CAS # Pollutant Emission Factors Uncontrolled lb/MMscf Natural Gas Throughput Emission Factors Controlled Ib/MMscf Natural Gas Throughput Source VOC 28.47 0.287 Promax 71432 Benzene 3.618 0.0387 Promax 108883 Toluene 1.535 0.0166 Promax Note: The controlled emissions factors for point 009 are based on the thermal oxidizer control efficiency of 99%. Point 010: Component Gas Service Heavy Oil Light Oil Water/oil Service Connectors 1472 0 1844 0 Flanges 568 0 791 0 Open-ended Lines 62 0 87 0 Pump Seals 0 0 0 0 Valves 627 0 785 0 Other* 80 0 87 0 VOC Content (wt %) 33.8161903 100 100 100 Benzene Content (wt %) 8.73E-2 0 8.73E-2 0 Toluene Content (wt %) 4.08E-2 0 4.08E-2 0 Ethylbenzene (wt %) 3.05E-3 0 3.05E-3 0 Xylenes Content (wt %) 7.40E-3 0 7.40E-3 0 n -hexane Content (wt %) 0.495 0 0.495 0 AIRS ID: 123/9966 Page 21 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 • Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA -453/R95-017 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas analysis. Point 011: The emission levels contained in this permit are based on the following emission factors: CAS # Pollutant Emission Factor Source NOx 40.4 lb/mmscf AP -42 CO 61.2 lb/mmscf AP -42 Point 012: The emission levels contained in this permit are based on the following emission factors: CAS # Pollutant Emission Factor Source VOC 4.45 lb/truck loaded Engineering Estimate 5) 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, 6) Points 001-007: This engine is 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: htto://www.epa.gov/ttn/atw/area/fr181a08.pdf 7) Points 001-007: This engine is 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 AIRS ID: 123/9966 Page 22 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ja08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: NOx, CO, VOC PSD Synthetic Minor Source of: NOx. CO MACT ZZZZ Area Source Requirements: Applicable 9) 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 XXXXXX 10) An Oil and Gas Industry Construction Permit Self -Certification Form is included with this permit packet. Please use this form to complete the self -certification requirements as specified in the permit conditions. Further guidance on self -certification can be found on our website at: http://www.cdphe.state.caus/ap/oilgaspermittincrhtml AIRS ID: 123/9966 Page 23 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9966 Page 24 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division 2.1.2 The owner or operator may permanently replace the existing compressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that "based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: http://www.colorado.cloy/cs/Satellite/C DPH E-AP/C BON/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: 123/9966 Page 25 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above -mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ 5O2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State - Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/9966 Page 26 of 28 Colorado Department 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 NOx 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: 123/9966 Page 27 of 28 Colorado Department of Public Health and Environment Air Pollution Control Division requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9966 Page 28 of 28 Construction Permit Application Preliminary Analysis Summary I Section 1 — Applicant Information Company Name: Sterling Energy Investments LLC . Permit Number: 12WE2117 Source Location: SESW Sec 25 T9N R61W Equipment Description: TEG Dehydrator, Amine Unit, Thermal Oxidizer, and NGL Loadout AIRS ID: 123/9966/008, 009, 011, 012 Date: 11/2/2012 Review Engineer: Stuart Siffring Control Engineer: Carissa Money Section 2 — Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt Section 3 — Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no' to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? 04/10/2013 Section 4 - Source Description AIRS Point Equipment Description 008 One (1) Triethylene glycol (TEG), natural gas dehydration unit (custom built) with a design capacity of 9.92 MMscf per day. This unit is equipped with a flash tank, reboiler and still vent. Emissions are routed to the thermal oxidizer. 009 Methyldiethanolamine (MDEA) natural gas sweetening system for acid gas removal with a design capacity of 9.92 MMSCF per day (custom built). This emissions unit is equipped with one (1) TBD amine recirculation pump. This system includes a natural gas/amine contactor, a flash tank, and a natural gas fired amine regeneration reboiler. All emissions are routed to the thermal oxidizer. 011 Thermal Oxidizer as a control for waste streams of Amine unit and Dehy un't. 012 NGL Unloading Is this a portable source? Yes X No Is this location in a non -attainment area for any criteria pollutant? Yes X No If "yes", for what pollutant? PM,o CO Ozone Is this location in an attainment maintenance area for any criteria pollutant? _ Yes X No Page 1 If "yes", for what pollutant? (Note: These pollutants are subject to minor source RACT per Regulation 3, Part B, Section III.D.2) PKo CO Ozone Is this source located in the 8 -hour ozone non - attainment region? (Note: If "yes" the provisions of Regulation 7, Sections XII and XVII.C may apply) Yes X No Section 5 — Emission Estimate Information AIRS Point Emission Factor Source 008 ProMax 3.2 009 ProMax 3.2 011 AP -42 13.5.1 012 Engineering Estimate Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit (PTE) AIRS Point Process Consumption/Throughput/Production 008 3620.8 MMSCF per year, 2.5 gallons per minute glycol circulation rate 009 3620.8 MMSCF per year 011 25,000 scf/hr 012 4,157 truck loads per year Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 008 3620.8 MMSCF per year, 2.5 gallons per minute glycol circulation rate 009 3620.8 MMSCF per year 011 25,000 scf/hr 012 4,157 truck loads per year Does this source use a control device? X Yes No AIRS Point Process Control Device Description % Reduction Granted 011 01 Thermal Oxidizer 99 Section 6 — Emission Summary (tons per year) Point NO„ VOC CO Single HAP Total HAP PTE: 008 302.57 38.7 (toluene) 302.6 009 51.55 6.55 (benzene) 12 011 4.43 --- 6.72 --- --- 012 9.26 --- --- Uncontrolled point source emission rate: 008 302.57 38.7 (toluene) 302.6 009 51.55 6.55 (benzene) 12 011 4.43 --- 6.72 --- --- 012 9.26 --- --- Page 2 Controlled point source emission rate: 008 3.03 0.4 (toluene) 1.2 009 0.52 0.07 (benzene) 0.11 011 4.43 --- 6.72 --- --- 012 9.26 --- --- Total APEN Reported emissions: 27.5 67.2 29.8 5.5 (HCHO) 9.9 Section 7 — Non -Criteria / Hazardous Air Pollutants Point 008 Pollutant CAS # BIN Uncontrolled Emission Rate (Ib/yr) Are the emissions reportable? Controlled Emission ib! r Rate ( y ) Benzene 71432 A 61860 Yes 620 Toluene 108883 C 77320 Yes 780 Ethylbenzene 100414 C 20480 Yes 200 Xylenes 1330207 C 61780 Yes 620 n -Hexane 110543 C 10580 Yes 100 Point 009 Pollutant CAS # BIN Uncontrolled Emission Rate (lb/yr) Are the emissions reportable? Controlled Emission Ib! r Rate ( Y ) Benzene 71432 A 13100 Yes 131 Toluene 108883 C 5550 Yes 56 Ethylbenzene 100414 C 247 No 2 Xylenes 1330207 C 779 No 8 n -Hexane 110543 C 1450 Yes 15 Note: Regulation 3, Part A, Section I1.B.3.b APEN emission reporting requirements for non -criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8 —Testing Requirements Will testing be required to show compliance with any emission rate or regulatory standard? X Yes No If "yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 009 01 VAC' HAPS Regulation No. 3, Part B., Section III.G.3 Stack Test Section 9 — Source Classification Is this a new previously un-permitted source? X Yes No What is this facility classification? True Minor X Synthetic Minor Major Classification relates to what programs? X Title V X PSD NA NSR X MACT Is this a modification to an existing permit? Yes X No If "yes" what kind of modification? Minor Synthetic Minor Major Page 3 Section 10 — Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If "yes", for which pollutants? Why? VOC For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? Yes No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 — Modeling Is modeling required to demonstrate compliance with National Ambient Air Quality Standards (NAAQS)? If "yes", for which pollutants? Why? Yes X No AIRS Point Section 12 - Regulatory Review Regulation 1 -Particulate,-Smoke, Carbon Monoxide and Sulfur Dioxide 008, 009, 011, 012 Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2 - Odor 008, 009, 011, 012 Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 3 - APENs, Construction Permits, Operating Permits, PSD 008, 009, 011, 012 Part A-APEN Requirements Applicant is required to file an APEN since emissions exceed2 tons per year VOC in an attainment area area for ozone. 008, 009, 011, 012 Part B — Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 5.0 TPY threshold (Reg. 3, Part B, Section Il.D.3.a) Regulation'6 - New Source Performance Standards 009 NSPS OOOO: Each sweetening (amine) unit and each sweetening unit followed by a sulfur recovery unit; manufacturer date after August 23, 2011. Applicant is not subject to NSPS 0000 because ... This source will have a design capacity less than 2 long tons/day H2S in the acid gas based on the information submitted in the application. This source will be required by 60.647(c) to keep for the life of the equipment an analysis demonstrating that the facility's desiqn capacity is less than 2 LT/D of H,S expressed as sulfur. No other requirements apply. Page 4 Regulation 7 — Volatile Organic Compounds 008 Is this source subject to the control requirements of MACT HH? (Regulation 8 -Hazardous Air Pollutants review). No Is this source subject to the exemptions under MACT HH (i.e. throughput exemption less than 3 MMSCFD or benzene exemption of less than 1984 lb/yr)? Yes Even though this source is subject to some requirements of MACT HH, it is not subject to control requirements. Therefore, it can also be subject to Regulation 7 control requirements. 008 Section XII.H: Is this source located in the non -attainment area? No This source is not subject to this regulation. 008 Section XVII.D (State only enforceable). Applicant is required to reduce VOC emissions from this dehydrator by at least 90% since uncontrolled VOC emissions are greater than the 15.0 TPY threshold. Regulation 8 — Hazardous Air Pollutants 008 MACT HH: If facility is MAJOR source for HAP (summation of HAPS of dehydrators and fugitives greater than 25 TPY total or 10 TPY single HAP), then all glycol dehydrators at this facility are subject to MACT HH. If facility is an area source of HAP, only TEG dehydrators are subject to MACT HH. 1. Is facility a production field facility per 63.761 (Refer to Section 14 for definition)? No 2.If facility is defined as a production facility, then is it a major source of HAPS when summing up dehydrator and flash tank emissions? No 3.If facility is NOT a production field facility (i.e. natural gas processing plant), then is it a major source of HAPS when summing all HAP emissions from ALL HAP emitting units? No 4. Is this facility considered MAJOR for HAPS? No 5. Is this source subject to MACT HH? No 6. WHY? . This facility is an area source of HAP and MACT HH area source requirements apply to this TEG dehydrator. However, since benzene emissions from each unit will be less 1984 lb/yr, this source is only required to calculate and keep records demonstrating that benzene emissions stay below this level. Section 13 — Aerometric Information Retrieval System Coding Information Point Process Process Description Throughput limit Emission Factor Pollutant / CAS # Fugitive (YIN) Emission Factor Source Control (%) 008 01 Glycol Dehydrator 3,620. MMSCF per year 35.08 lbs/m inscf V0C No ProMax 3.2 99 2.621 lbs/mmscf Benzene / 71432 No ProMax 3.2 99 1.422 lbs/mmscf Toluene / 108883 0.0817 lbs/mmscf Ethylbenzene / 100414 No ProMax 3.2 99 0.264 lbs/mmscf Xylenes / 1330207 No ProMax 3.2 99 2.444 lbs/mmscf n -Hexane / 110543 No ProMax 3.2 99 SCC 31000304 -Glycol Dehydrators: Ethylene glycol: general 009 01 Amine Unit 3,620.8 MMSCF per year 28.50 lbs/mmscf V0C No ProMax 3.2 99 3.618 lbs/mmscf Benzene / 71432 No ProMax 3.2 99 1.533 lbs/mmscf Toluene / 108883 No ProMax 3.2 99 0.0682 lbs/mmscf Ethylbenzene . / 100414 No ProMax 3.2 99 Page 5 o 0 T•� UI CO N '0 0 w ti n a SL ox 0 a a N C y E •• n H 0 a ❑® , 0 ,,14 ;5.) paq n A O l.- CAD 0 0 9 4 0 .. w G - rn o < wa R a ro CO O CO T0-9Z-90-ZT0Z-N3dV-T00-9966-£ZT 0 0 .m co loo m 0 mo':' rTi m I �D n aJ t�]J /bJ � o o 0 0 ®® 0 0 co o F Cr a' Cr O 0 o O as rn rn 00 0 0 '0 '0 O 0 M M as O O' 0 '0 co CD O 0 0 • m • g 0 a O N a P ^ rn a - 0 a' ^ 9 ao H �° oroi y Co y m. • Pt ngi 0 a o a tl a g p n O C E C 0 a g. a 0 S H t7 w G y Ts, -a 0 a ua - b0 uol;aa5 uol;em.to}uJ au; d � n o O o £ 0"01 00 0 O 0 0 a Co 0 e 0 N 0 o 0 PP 0- co 9 co 0 O e/snoo.a;ets-aq g O CO ja. .' 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Location: Latitude: 40°, 43', 10.6" N 0 En 0 9 9 Z z oP R R ;vela sup leluua;ua3 est for coverage under GE Sterling Energy Investments LLC ® Request for NEW permit or new Section 01 — Administr, um;emio;ul a 0 r O NTS N •y H O 0 toco- .H m h 0 w_ '▪ O w" G a 0 a O w rY 0 rip • o m K 5 .� C CD. O C) W 0 0 013 071 N CD O w . -0 . N 0 -. • .d IQ a 6' 8'g n o AD 0-• 0- I• tIt 44, • Er C9 g, ?� m ts.) G n g cm Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. IBenzene II II Formaldehyde • 1 I • X°N 1 I I I m m p m A. to m - 1 I . l n acw� uucwucnaa uvu o..o.. - Control Device Iaeacriptlon : Primary Secondary I 1 I I I I I I I I I -4 e w e.... O OD Control • Efficiency :.:. (% Reduction) t-, .rt-iggAtakvvrtii N N N v:10 CPJ N.4 V J p •-• co Emission Factor 5 2- Fr Miff' a erl C 5 a. wsis " 7' ez R' i ir 2- I 2- 2 . co .. Actual calendar. 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Z 5 m C a z Y Longitude: 104°, 9', 10.7" W N „9'0I '.£6 '°06 °aPname'I mum sun leluualua3 Company Name: Sterling Energy Investments LLC tn En w 0 0n $ n ,O y .2 n o A A N 2. 6 H p O G ❑ ❑ ❑ ❑ P,, • a. 0 m a 5.0 a 2. „, 0 • La° z y 0 d Y ., 0 c Y n 0; OE m o c, r :, o^ n y m rt b o 0 5' a H ,0 0 z :1st o z N ; n y Er it O y0 S 00 R r. 5 n 'C B f h' o H n .n, O y 0 0# o o & A Car: 01 n n 9 ;+1 b ❑ w ' .O, `< n - O O S 0 9 _.. m .. < v L N a • O O `< ❑ C S C< E.. w 8 .n, t 0 a ❑® CD • CD A .c G 0 ✓ 0 n z m A n R 0 I. 6 S F, Ci • R O ✓ o tO 0. Ly n CD 5 0 En 9 e w 0 'C aaanos HOISSI Section 01 —Administrative Information 311— ZO uogaag nested Action (check applicable request boxes) n N C' y Q O j O E 0 0 0 a m B o 'TT ✓ `6 r. R • w 0 O £ 3 a - o r T 5 Rio O z h1 y�y CJ O O 0 y Emission Source AIRS ID: CZI O ICC N N 7J O. E. n g. er � O a O c p' _a 4. ~� .y .13 0-g• 4 H 10 O. O o C o o 0 a � M m 3 A. -n oto .O.o p Of° g. IPlease use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. uro5 Acetaldehyde O a . VOC • CD I I I lCatalyst DO .B- m CO3 OT IS, .B- .m LO T 1 1 t j�ac[or 1.V1'u.oCYu.{WU .... Control. Device Description.: Primary Secondary I I I I 1 l I I I I \l eee W 00 in V W m G W •*--a O W ; O N. 1.0, 1-1 f~r1 0, 1/4.1--, �c , '.0. 7- A lqq� C!� U Uncontrolled Basis 7.71E-05 • f o m 5.„ lb/MMBtu ir.,,,...,,..,111 C o _.......... a - R" •B- c. a Un its lb/MMBtu Actual Calendar Uncontrolled oils/Year Year Emissions) :: Controlled .•. Tons/Year O o 4 O w U: O w O1 F+ i-, •-4 W r .4 !A Rs co H U 00 o O. W f @ A o 0 a Requested %Em UncontroIled (Tons/Year) 0.004 1 O 4 O U O O1 DTI - YX :Tl N I—. lh. +T' S Z O W P A. O- A O A Permitted CZ N I EPA AP -42 J Manufacturer Manufacturer EPA AP -42 EPA AP -42 p EPA AP -42 EPA AP -42 EPA AP -42 EPA AP -42 Estimation Method or Emission Factor Source m O A y CD CD O N �, m CZ O •O a o o o• 4 O z. O ,a'. 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O 0 a 0 Y 0 R ^ _r. 3 rt O n2 ^ T ro o 0 - yA a- d a= a CO O a e n N Co O m 0 1 a O Section 03 — General Information asselin@sterlingenergy.us 10IL-ISS-OZL gassi+l.renns 00IL-T88-0ZL opeaoloO- `.ianuaQ g Address: - 1225 17th Street, Suite 2520 N CoO -Co 0 o Zr a id 0 o m 0 w AA „L'0I `,6 `0P01 :ap :uopeoo7 aoano5 Latitude: 40°, 43', 10.6" N o M d ❑ ❑ ❑ ❑ ❑ FE; e a H R° • o ❑ ❑ e Co ❑ ❑ 0 Co e s s s cation ofAOS permanent replacement s Co Co Co Co Co a 4" 'N a LL,' n n y x N c%). d N b o w 0 R o 0LA Co z Z Co o 0 m O . ..,g, o a t 1 (;:,1) 0 m Co 5 Co0 H 0 3 0 c to Co ^' •o- 0 Co R o Co .Z. R R z -' 1 o 0 -Co w o o C. fin., S y o.°' ¢ —..❑❑ T g 0 3 C .1 r z oo y o 3 O O O m H Co.re n T O -o C 'G fn o' o o• ? tti;m 1 r 1 5 - or o R O 0 N o e ❑ F v o 0 C Q w R to m zo 0 Z. y C. v v Section 01 —Administrative Information 311— Zo uollaaS uested Action (check applicable request boxes) mob, Co m n 9• m z 'G G Qo ft O d [ H!� o TS °rxi O n F" ,10 O O n O m B rt C 8 O n ity Equipment ID to identify how this equipment is ferenced within your organization.] [Leave blank unless APCD has already assigned &permit ti &AIRS ID] 0 W N CD cr r a. y I 'iJ I I 0 •a • • CD CD-. N 5. m 5 -0 m "O rn • Cy O cu y in ry CD • . w fB z g w. a � _a' 4 • O � e N ti W ILO O m �19n a • w o• g. a .+ lam' rnb 1. O 0 O • ro OQ CD c▪ v: - • C a • 0 �t R• N R. CD 0 O . CS • Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. ui 4 a. Formaldehyde CO "Old 1 I I I m m - �0 m' w I Catalyst I 1 1 I • Control Device Description Primary Secondary I I I I I I I I I 1 1 y %L6 . • Control Efficiency (% Reduction) ►+ gym{ N.. ON W�{ a N U) .-mss • . a U 0O0. v �- -1 -i:i -1 - a;. o : p 'ro 'HU flu .. C a g/bhp-hr i t ti.iiii -, R a G IR'. C Actual Calendar • Uncontrolled .. (Tons/Year) (ear. Emissions' Controlled (Tons/Year) c'. . 'r0 to 0 r . F•4• i-• . ►. J C, CO bU N to on C o W O- 0 4, O 0 A b 0 A Requested Emis (Tons/Year) O D o a P CT r -1 ��Ap -1 LA s► t'l I, i'p --l- x Cm pa W P. 0 0 o CD 0 C Permitted ssions Controlled (Tons/Year) EPA AP -42 I EPA AP -42 11 N EPA AP -42 I 12 1 4 ti 0 ti co EPA AP -42 EPA AP -42 EPA AP -42 11 EPA AP -42 Estimation Method or Emission Factor Source E. a a gLI a iv Section 07 — Emissions Inventory Information & Emission Control Information TM 0 0 w C) rn CD b CO 8 0 CD w 0 suD lelnle Scco co no 0 cn 0 Fit l�J g 0 0. C O 0 CD CD. O y IA/immix sZ8G ps/urn 09I1 N CD CD N O IJ ° Section 06 - Fuel Consumption Information 'CI 0 Oa co U S A ^ o n a a A n .. n 0 vi Ei n2 n ❑ CD B g. Q. 0 4 II c0i N 5 U) d b ( m P o iosls}o no[0a1l( U) N 0 O D O 0 CD a. co d 0 • I- I • 0 • 2, CI 0 II .. 00 N rn n '0 ts4 0 w N... W 0 0 J 0 0 oro (17 2 77 1 TM O 0 •a. 7 �.• s. m C) 0 co 0 p m y CC ro F fA co 0 Cr CD 0 *fi C b CD C 0 act P.° eo �r :.taquinx grand OP 0 Sc CA) EIZ =nn 0 CD CO- N W D0 CS 0> rn C ; 0 0 ro z N D. O d Ni O S Ni 5 J rn � 0 N 0..C as 'S- a 0 G 0 o a 0 0 p -d7 N D van R o- 71, m 2. P g g CD N En n ` N 0 Hoya0,4 CT a. o iJ R ro 0 57 CO 55 ro 0 C w m a .'l ❑Z 'C o CD. m 07 P 0. izt ❑ Po imb G CD n x to H E E T tgi dc• o c m a CD _y •a °= 0 a co co IN CP ^ i a. a R '•,G.• 5' rob 0 PA w o o o -c " o. a o b m C '0 y 0 w rn R y r° a 7 a O a - • a a ▪ 5 O 0 0. O 0 0 0 4 O N O tO '3 ,, d 0 -0 O F'' y 'J ro v`a a.z y .b,'.COnOO= iliay p z O_ 0 n d v c s w r '5• 0. 0 . I I. :z a rn o p N Lt 2 a a n s z ro ac+ y y w 2 O.. ttl C 2 o o n y w^ m n o m i-+,� n •+ c .. F ▪ O T EP 0 3 a .. 0 o d o w C F. _w n �' " 0 y. Op C < .w.... < �' O.^eo a cn m oa c • Q3No 0, u, CP=. �' o� rn a vaml • S' c p7w a £ 0 w m n 0 o. o b7 : •i ❑ rn op 0 m • •.. z jF e' w ., to0. 0. 0 e oN.7' w O N , 0 l e\ FD w < w p N• r `.C ro o •/0.n b \�O L^ l n g •9GO ll0 c' 0 0 Section 03 - General Information tal IC ,a y O P C, w .y w 0 0- any a B ct 0. o 0. 0CID Et: 0 0. O pp o a3 y CD n t o R 0 sasselin@sterlingenergy.us ul[assy;.ren;S :aaqurnN auogd. ope.aoloj '.ranuaq 00IL-I88-OZL 1225 17th Street, Suite 2520 0 m C N N z Y Longitude: 104°, 9', 10.7" W n o. 5 3 a 'x1 co co re 0. 0 zz rn rn vivid set muma;uap Sterling Energy Investments LLC �z o iii 0D • O µ ❑ ❑❑ ❑❑® w p ❑ ❑ A �. ❑ ❑ A .0 .0 .:9 y C C C 0 y N. Ci iy a a nn y a o y. o. N. y ro m g 4 a c 0 ',4 as D N.. U c H. y .`�°y .. o 0 G < O ppPOC bj •q Cen ra w '0 w H .. 0 0 R ad ,w. 0 g. P H o Y Cn d 0 O 'CD Q d C. 7. 5 `G m z T 7 v ,. '0 o 0 a = - z tai 0 pp _ 3' ❑ ❑ w to C 3 ,. ^ e N o � S PO m 5 cc -- .0 r " y o HH.O `'4 iv c ▪ 0 0 c I a 3 p7 r2_, R w o' o y �' 0 a ,S o n 0 0 5 T G m• 3 y tD w g `< n g• C 7 N P 0 y 9' 3 0 O 0 X S ro 0 C O ❑ C S � O' . -C 5 w ro 0 0te 0. IT number CP02 (Natural Gas Only) Request for NEW permit or newly reported emission source Section 01 —Administrative Information ail — Z0 uopaag nested Action (check applicable request boxes) O N [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] [Leave blank unless APCD has already assigned a permit # & as Inos uo]ss]uaa 122 N 0 0. *.n o o O0 b co N co P d • y C no • 0 - 'o w a te co Fi am • Y. O or • ea P coCp aco • c n z 0 N R O IP U a Please use the APCD Non -Criteria Re ortable Air Pollutant Addendum form to report pollutants not listed above. madcc, 6n 0 o a a • a so co Formaldehyde n 0 0 0 x 4 4 o 0, b I t I ICatalyst on v eT w D .. I I i I 'C - a G\ W e b W e oata Control Efficiency (%Reduction) A GA CO t+1 0 N 01 AI ci W N LI PO th w N .0O [N=1 N CM �'. ca 4L+. "j U GO P7 A -1 !NI ta.i LI, J LI H U. J LA tai U.RRRR igiift- C C C 0 R g/bhp-hr 6666 C F C o Actual Calendar `. Uncontrolled (Tons/Year) H• n vi 50 O N pa d o O e e U' w 0- O e c -o -a -] e j ut. 0 CO " 1 tb e 0 • W. co 0 a 0 0 a 0 0 a Requested Emis Uncontrolled (Tons/Year) O V O CM O a A J) ItA v; l Al N IA J s. W 0 W 0 A 0 A .ggA 0 Permitted sions Controlled (Tons/Year) EPA AP -42 EPA AP -42 EPA AP -42 EPA AP -42 4 O d Co Manufacturer Manufacturer EPA AP -42 EPA AP -42 EPA AP -42 EPA AP -42 Estimation Method or Emission Factor Source a re 71 a o a vq. yI '3 b O a In 5. PH A - 0 O C• CI < CI • F- O 5 • o a a 0 C •- tZ Hp 5. 0 0 o 7 0 m' O 0 M 0 O ins u ro S O O 0 6 a,S/Jasmm SZ'86 Jastllat 09f i 0 a N U 0 0 N a CA e ' N U! e 0 P 00 Ut co 0 mnsuoj ian3 — 90 uogaas uoqumaojuj no! It N ry W 0. W ta N 0 N 0 El 4w 0 m Ka 0- ID 0 P. C 0 na oa N P O oo N y t7 m to e o a N z w N 0 W J to J O 4_� q • H • O En � ' q to 0 -a 0 UG S CFI CD P :aagmnm 4imaaa Y COCD 0 0 w P P n 0 0 0 ^' 5 O y w O N 0 O a m n 0. 0 P- a 'rT ti 0 0 T0-9Z-90-ZT0Z-NhdV-S0.0-9966-£ZT,, pa w N a D a nxem arp Sr;elm fiber of hours this engine is used for emergency back—up power? C a -n n .. 0 0 0 O O X x O 0 .o a 0 y 00 0 00 0 PG M as frp DP IG 'c Pc •0 b o' o - 0 'O y c 0` 0 o 0 0 0) 0 0 0 0 op 0 ni., a, o o 0 p 4. .w . CD o — yx. CP 0 Co O o 0 C m co '-do c m pp O O 0 0 C 0. 0 O •O ° H .0 p 0 p°. 0 •O 8,. " a 2 ca ` P. 9 ca oo 0 Co g. PCp It OP C] c a ° 0 o c o. 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O C C C. - S y 0.' 0 0 N 0..- pa n f° Li) 0 z y ,71 a <i 2y 0 ogecc"8, _" tz] tz on , p y a O> if 2 - e.g.5- 7,- e d 0 U d ° _ c -°q 0 y. o C n 'o-n'o F it Cl) ro:AD o y m Q 3 ° o c - v ro y 0 W sq. too O z �o. a 0 Ul N Section 03 - General Information o k, • t'i] ro 0 0 ` o G. o rr o w ' 0 o rn '< g z z' w 0 0 0) n P a g 5 0. o a O 0: o a td 0o w C 0 o C ° r o 0 sasselin@sterlingenergy.us ope.rolo3 '.ranuau 1225 17th Street, Suite 2520 ❑ - ❑ o ❑ ❑ C K b 0 " o Ia y a o z w 0 ' U Y ,.1.< z O P Ca a ro tri N O G a w wi S O m m ° 2 0 5 5 y' o 0 g g G 0) — ^ o ,o c 'G 1 P. z Longitude: 104°, 9', 10.7" W M a 0 a a 0 z }ueld Su° Ieiuua}uaa Sterling Energy Investments n r.nz n o n g(9, Na ❑ ❑ ❑ NI c. ❑ ❑ r. .0 .0 ,- G C C y n s T T ro M 0 w 0 0 , ; Y s it 2. c H a 'O 0 d n H Z o 0 y Z < tz 3 ❑ ❑ 5 Oa .z r o y n sr S y w 3 t c. a ay " °a° 3 2 0 0 Rii ° d Ir4r°E. 0 C' "�G 0 P o m a S " -, •o 2 o n co k V (6lep sno IeanluN) Zed Cal a 0 5 0. 0. 5' F.! K R a 0 a. O °0 CID m K 0 y N I 0 CD CD a 0 5 0 n. DO 7 y 0 0 s e co Cc DC 0 a .0 3 • U O d M y rn 2 Pi O O t) R 0- �. s R7 r' � M O v O 6 1 G w � S'b h co gm 3 n o rt - O CD m b 9 a rt g . I 5 o' c n • 00 0a. n 0D !De -D. gCID W o- O N 00d 10i n N 0 CI. a.o b(y,... O a' O n0 O ❑ P N n • ❑ p a 3 om a . • Co y z M — Co g a E O' M a 0.t, 'd O ry WF Co t Co jud O yCr a n n " a. o : , o a" ❑ m °. O O ❑ a a' • p • a c go N Co • q t ow CD 0 ❑. • o ao oa CD A "t7 O O w ro N a O x m w m Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. U Acetaldehyde Formaldehyde o 0 0 4 c< I I I Catalyst Co Co - Co Co T I i i i Control Device Description Primary Secondary ?. O0 F+ W t!!' O c ' W J - Control Efficiency (% Reduction) F+ M- O W N til O W N P7 O W N tt O N H c © ' la iJ J cio go [l1 O A J i 1 G CA J 7 O LA J tri O CA Uncontrolled Basis Emission Factor Fd G C C Ilb/MMBtu a g/bhp-hr S G ill G C G Units Actual Calendar'. Uncontrolled'... (Tons/Year) Ho po p ,C'o R O C a O C N o O N O r, cm W "4,.N O o Uo ct O fa O o a O o s O e fa O o a O 0 y O.. a I;O5 Er w Requested Permitted Emissions O O Y+. o O N co O Na O r U O A 0.25 O O, A A a a O O O co co O laa O O Controlled (Tons/Year) EPA AP -42 m ro A EPA AP -42 EPA AP -42 Manufacturer Manufacturer Manufacturer EPA AP -42 EPA AP -42 EPA AP -42 EPA AP -42 Estimation Method or Emission Factor Source C _ Co M `o y CD o p pc,* t=i CD rad. Fa o O a co y G • Co O a C P iP Op - o Cc . n O • CO cn , +f O a • - 5 • ❑ o O o - Y 0' 0 tiLL N U N cn v 0 Seasonal Fuel Use (% of Annual Use) Section 06 - Fuel Consum nollaur.rodul uol 'y ure!Q aotrui :repot -O O R M Co O Po . O O g. 7 n z O m 0 Co 0 C y F O' H J acm O O 0 O J o v 2 co co w� w r J a U V J mina al9oo3 n o - O ut M m o CD a" m i M 5 C Pc P' C O CD 0- •4 N CD N w a+ 0 N OnL H O 0 5 CD CD O C Co 'U 0 R. rn P. O 0' Co CD I Emission Source AIRS ID: rip IH n O a 0 ^1 0 0 0 i C a O Co co f> O n 0 ua uop 5nquio3 Iwui CP ro 00 Co 0h N 454 rix O Co C or n 0 on Croa or w i 0 0 ZZ n n 0 0 Er cr 0 0 �, • x N o 0 a w 0 CO m co ED y T I o 0 0 o o ae ° ° op d d N G ✓ O o ,0 00 Ni y 'O .0 O d C' G' Z N O O I 'Co '0 w 0 01" °vv c N ,w Ni -1 o Co m o - o• I o - m N co 0 '--Co Co Co t °a H w Pit P' 5 N Co Y 0 a Co o m' on Co S C 3 3 Vl N Co- b N n Ft Ft rn n o a m o 7' o oc co O Co Co Co c 0 C '4 ca O tg m 0 0 e w rn Co • 0 S ta- m v 0 t Co 0 u'r,I-60 uogaaS uogemJOJUI au! b o 0 D m or n b O Co w P. Co S' Co Z. 5. p 0 c E Co T w w 0 O Co d 0fpg S E. .mow o ° ° P e O w 3 n 4 Co R O C • y O h C y y 13231 . ° d Co O o Co L] ° N R F 'O Co N 0.'0 O 0 S' ° O. P o 0 o v ° 0 0 o c 0 4 N N z'11 0 N C 0 Co 0 ca O Co co is 0 co' 0 R En Section 03 — General Information a :.ragmuN xed I0IL-ISB-0ZL Co Co :lagmam audgd opeaoloj 'Januau 1225 17th Street, Suite 2520 0 0 o c o. ❑ ❑ o a �' c ❑ ❑ Cry = C. 'Co Co m P' 0 0' ^' 0 Co O O 5.tei Oh7 O O „ a z o ❑ Con g Co w 0 el m e 7 5 . E o w n 5 Co Co P- .5 B. k m m•n y o Co 0 T ro"e, Co E' o Do -o o" OS permanent replacement 0 ° o- 5 o 0 to ° 5 w F N Co z Longitude: 104°, 9', 10.7" W et w Co A a ro er ❑ ❑ _ T Y n b o O• OQ 0OG • a G' • g. H O) a o P. G a 9 y 3. ❑ ❑ Weld Sep leluualu0D O Co DO C Co C z 0 y 0 A '0 r c y 3 ▪ LS 3 m HO. F C Coo 0 3 0 S = _ , n S A st k y P O Y e .w. w m y c▪ 0 e4- :ameN AuedtuoJ Sterling Energy Investments LLC Section 01 — Administrative Information a2L- Zo uogaaS nested Action (check applicable request boxes) 0 O -is 'b Cry CP .0 3 Cr 6 Co 0 Co 3 En m n a � 0 a O O O 0 O mn lac iy 5 CID [Leave blank unless APCD has already assigned a permit# & 0 tn CID • yn 1..1 Ro • A '4 Ci yA rt n. CD W0 En -4• 3 rnG fr N 02I I I0Z'LZYL°A-N oo 00 n 0 0 D 3 0, co ac D R n .w J e 0 ]. n nInt tl9 0 v O A'm v co o' V w a A I 0 0 CD rn m oe N o x in. b w .Of w a N E. I2L O P 10. N 0 g 3 w � y Co o a 2. Eg 0 m 0 g$ 0 0o m b ti n yP F4. w 7 co a C � O O O 5U rn ' 0 ¢ m5 ° 0 0 a' m tc m' w O D O m p O N cra o 0 5 < w N co It w g o_ n p 'O d ry fD o J o CJ 0 P O R C Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed. above. 0a�a P 0-" co cc n o z 0 L7 b b TSP Liu Pollutant I t I 0 0 rt Catalyst 0 In I l l s Control Device Description Primary Secondary CC A w e A m cc e ‘0 00 Ea o on W al W N W al W N l.0 al W N CA V N o- .O .„-- 5' N N J .> C U 00 Cy a J - C+7 COlf - A C=1 Lfl J J ' + C� i LM Uncontrolled Basis Emission Factor. C C F F Qq 1 UO Si 01 CM GI cl C W C W G C Units Uncontrolled (Tons/Year) Actual Calendar Year Emissions' 0 0 co 0 0 O q.a o N e W 0 W 0 UNi a W 0 N 0 H Ip J 0 0 O O 0 O 0 0 Uncontrolled (Tons/Year), Requested Permitted Emissions C N O W O W SZ'0 H O\ O 0 'H a O I O G 0 O O 0 O O 0 Controlled (Tons/Year) EPA AP -42 EPA AP -42 EPA AP -42 EPA AP -42 Manufacturer Manufacturer Manufacturer EPA AP -42 EPA AP -42 EPA AP -42 EPA AP -42 Estimation Method or Emission Factor Source J 0 0 O 0 0 s 0 On 0 0 e0 F p D m D Ca 0 R 0 N 0 s 0 ❑ z d O w Is this engine equipped with an Air/Fuel ratio controller? O c 0 9 CID ;as/nlg 0911 o E En m 4 5 N U O O N U 4 N Ui e P a N U 0 O 0 h PD P C 0 0 O d I Section 06 -Fuel Consumption Information &quad° isnegxa ❑ o O o ti 0 a 0 el Co O g II 0 0 K re rn 0 K e go a 0 N W 0 J O co ?ae W N 0i ,- O O H J co. A U V J CPS O C.p CO O (10 y 0 O 0 d a $383S — SO not}aaS O Prop 4 C P m m 'b 0 G. CO >v PD w 0 ;uana Mil ur 110 • LC 1-1 0 GI C CI O P O (ej < co 0: aC E ti F° .. 0 0 O O gmoj Ieu.la;ui O O O a 0 hN O1 tV CAD CD 8 - es, 05- 5- a 0 a 00 a O' n 55 ®® Z.. 01 0 0 Cc 0 O 0 - X k N O O co Po m uo A R In a a m n n O 0 0 CD 1 `e `< o 0 0 7 , 0- D a n Co IP N 0 Po Zon fig. Z n N ;n . b d o O. H1 01 O ' Ni z o 0 I O O W O ., P P. N o ? I o 0 CD 0 o N Ixeui aql ST;egM KK a a C: ` Gig. 0 0 3 O .14 g rn rn N 8 • cn 0 5 5 '-y' 7- i. n 5 I. s..,-Li G C 5 5' <I'''. y N n its a o o n rn rn 0 y a N 6 5. . m m 0 ❑® O 6 n ra o \ w y O < R. .cis a -44 0 -4 a O a ro 0 0 0. 8 3 On O ▪ o ❑ w '0 0 ro E G R b 0 ❑ ❑ Y 0 v 0 CD to W ELJ m 5 0 • m • o' 0 O O o y w m " &5' g. 5. • `� e E G G 7 00 M G a 01 5' T 9 w o o a Ps 0 - 0 4 N 0 0 I' CI os O rn p G 0 a 0 w 0w Fs o g O 5. G O 0 a G O 0 P. Er R ❑ a 0 6 a S 2 /str oa'aans'aq g o ctt,�o '< ono 14 E2 -0 0i n 0^ 8 00 t7 0 ao a on d 5 ?,7 LT,. ,the DD O Cr O a a ".C' A b d O cOil Ps 0 0 5 m . 0 0 n ro - c E. d' T - y C ua A A d n r S 0 P' o e M. co O' O ❑p l ww" 1 A\ z C a 1.41 N 9 For new or reconstructed sources, the projected startup date Section 03 —General Information u!Ja;s@atlases CD c :JagwnN xe,3 ullassy penis :aagwnN auogd OOTL-T88-02L opeJolO taanua f. 1225 17th Street, Suite 2520 Longitude: 104°, 9', 10.7" W :uotleao7 aamoS Latitude: 40°, 43', 10.6" N Sterling Energy Investments LLC 0 M 0. ❑ ❑ ❑ ❑ ❑ RD" erio,,,Diiirt. 'b :0o yC a n n faaC N n 5 o y'a :4. yy "dig i e 0 0 °» b 0 0 0 4 o O y ° z$4 b c o ° co ▪ a r n w yy a d H .� 0 a m n o 5 • m d e - 'e .o O G, C• o Z' N O '� 7i M P r A 0 tt F • y N El ^ r O 5 r h o y n -I It T 5. 0 o` a a' 5 [=J c w 5 . 0 o 0 rn D' 5 c° <. o 0 T H y G 0. mg`GG n C p ▪ 0 "p - N Q M _om'. a. se < 9 0 cx 0 O a Q O N o 5. G m O ;. m a it v 0 r o a Section 01 —Administrative Information Section 02 — Requested Action (check applicable request boxes) :Ql;uawdmba 6;lllond Emission Source AIRS ID: Haag —; 111-Iad Ito I ,I ; ro In. e p3 a O • 0 0 - I- °I) O y. ca ao V co O. p . C- .. R. 55 E 1 a.'1j F-1 7 C `7 o n c/a o w Cr t Cr y d . N a. pp. y� d W t9, 0. a d C `� E. ,o 0a0 1 W D. Si 7 cio O" IV B g. .oro p'0 -� CD g, p a N• z•� FL g, o c•.... N 0f O O• W .-+I g- ao W `-. p. O 0 O `<.' ��r� � R rn Q O cnc o. ga.P a 'v g 7 W st L F . 0 Q C W p- 5J W N b pl b g n 5' N O 0. w co •4 m 0 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. - l R P Formaldehyde •', Acetaldehyde 11 CO VOC I NC -IX K N o *b 1• I m m w m U C C ? 1 1 1 1 r sC{ua 11.111.U111Cul.s.l.LOU alt Control Device Description. Primary ' • Secondary . I I A . W O-9` O \ CC (1 o Control Efficiency (% Reduction). ►' OU�iOy NQ�� p W N pNp !h 23.27 ll1 000 --1 • N d r-+ :-4 ►-+ Uncontrolled Basis Emission Factor •F ri- C C g/bhp-hr g/bhp-hr a a a C • Actual Calendar! Uncontrolled (Tons/Year) 0 0: c. O W pp. f1s O M 0.39 I 9.27 pbp�� A' I 134.82 O �' O r O ;-L. C .0..• Requested . Emis Uncontrolled, (Tons/Year O W 4 VOA O o a O : 0 H• O A I 1.74 4 10+ e o 0 f-+ o g> ° 0 .� Permitted lions til V N 171 Mt N EPA AP -42 EPA AP -42 = gy'' a Manufacturer Manufacturer EPA AP -42 EPA AP -42 EPA AP -42 EPA AP -42 Estimation Method or Emission Factor Source '1 m 0 5 O 0 0 0 ra 8 O m IA J ue n 0 1 C . CD � m ua 0 0. a z 0 C�9 0 PO o co coo .r/C/psmm L9'Z£ 0• ;as/off 09TT • EA U U .ao U co a ection 06 — Fuel Consumption Information VJ 171 a b o0 A) W n1 C IICD W O N -41 n'F a d W 1� U O v b J -4 q;_rei al;looD • o N b :aagiunH I4uraaa O CD M_',1 ot DO UZI O Na og ual has 1 .. m zo fiaaV xda 0 rn 0 1 3 i D J 5n N N N • Y O o n rn 0..3to Fr a a a' w } y R La n 2P. 0a eli 600 kd R'LL=0 a � xR CD 0 ' • CD O O • '0 G CD v IL ' 0 0 CD a• n O 0 • 0• 0 O N N e e C' T O 0 'O '0 O 0 0. a 0.. 0 0' R R CD CD I-I Cr n 0 ❑ m 0 m QCs dc) ap, Lti-46 gg 9. fl,R•. PF O rt CJ py. O' O 'O y O o. o y y �° y 6i g°99,2 El CD ❑ .. .. .. .. v m �w g w •H8- 00 R R bo 0 C G z 01 w n 0 v H H 0 n rn v ry�101 w ,n 7 n CO 1 (1stw y v m rn w w 6 n'n' O 4 B 0 is 0 0 :aauuae;nuen C C A ❑ ❑ 0 00 rn nn•C O O EE ro vac( — PO uot;aaS tuna ;tun lingua uottem10p114uam Iry v 5 ..CD d En X d O N y r 2 0, 0 O C w G R b d O ry 0 rt O w • ti ] N • V �Y• i G 0 O O O 9 -. R b 3 y o rn E. °' rn o 0, m CD 0. S' o Z' n ❑ a • < 5' o ` N z a o O �G� gz3 0 • 0 0 m? o 3 0. V n O a Gsd O 20 N a o� o tha oyob 0 • a 0 Nz o azardous Air Pollutant ( CD a. 1/SIT 00'atets an ❑ ❑ y ILD (total uncontrolled actual VOC emissions from all dehydratio ® ❑ 0 0 0 ❑ ❑ ❑ 0 a O. zm 0 0 I 0 o ❑' 0 0 py C � R nN 0 v N 2 O. a rt0 C a A CD J a y CO Section 03 — General Informatio 0 a0 001L-188-0ZL opaaoto3 'aanuaq ng Address: 1225 17th Street,Suite 2520 00 O N A H FL FL d R. ❑ ❑ c OO1 0 ❑ ❑ 0 a- m CD Hn n m • o a $. latl c 4 w y• F7 . 0w0 C Pi . N 0 CD Z '_.'. 'O R d. CD M H Ne. 8 m a ". P oii• n 01 01 a ,....TV a,• -2. y o a. 0' 2y 3 m w re 0. 0 1 SPr C' a 0 0- - - ❑ ❑ o Cn ..r n 3 c ao' A i n n :. rn 000 . 0 " w o• 3 • P N 0 a n o grt.,., O 0 m en •co 3 0_ C w m y R R y O S c 5' ? o g q '. S0• a n' o 'wi `0- 0 m . E' v H K OO 0 t •R 3 roc 0 O Longitude: 104°, 9', 10.7" W Source Location: Latitude: 40°, 43', 10.6" N ;ink sup Igtuuaivaj z n o n a o w R O 4 ❑N OV ❑ S w C v G 'p 0 Y N Section 01 —Administrative Information all— Z0 not;aaS CD CD O CD CD CD tri n bJ CD co n 0 0 C] O 0 r r ; n'i CD _ wf, a'0-: O a.oro 4 -_ co =Ix G. 0,*- Co c o co m n co fi CD R m 0 A X. Q C,) c, m CC 0 O 0 n OG 0 CD t, tJ a.: e e CD CD 0 0 5+ '4 o . o O '. • 0 trn too 0 I0. 0 o' s 0 co A 3 • m C. C m rjJ �n ?0 0 ,--3 .o O CD C A G b •0' ID m O m P IP • A 0 0 N A r`W . 0 N` U) co A ,P Z0-IO 0 = w a. a s w w IJ [J lJ C CD U C g 8 an suoissnua) p : ouatofg prupaoD oe e co CC 0 0• U 0. m O m C 0 93O 1cuy aquosaa ❑ 0 o n n b' 0. p C 0 0` 5 y Q .a (7 N • � trig O rig a n o n p' o "C'B 0 ¢, 4 0 n c G razrprs0 !emragy ocn CD e b E3 m asn 1 D!A (J uo! U) t7 ranoga2I pug vela OD t0et nom. o' b 0 I 0 r ' W r co CD CD R° ED E tl o I O V El O CFr�. rn o ,-o) O O o P C If o E gt CD Pr a O" n m . � b U m p O ❑ K. 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B r '.7 43 O R ❑ M o0 5. z G m n N n 0 O G G N O 09 On 5 y a N rl CO a Le 7:i w L N P O n NA .S ;iufl;iing mo;sn3 V/N :10pofs N w z 0 Section 04 — Amine Sweetening Unit E uopemno;al.;oam ® y o 0 v w c O c a O 0 3 ? y y y M O rn ,nn 'to O O O .O, v 0 ''0 m 2 S g" 5- •ai E o A. w S. O 0 28_ •�0 d gas? Provide documentation. co o O a 0 co N 0 55 - Iunqulu;uluumiu;le DO ❑❑ O O O as Co O y C O \ TPo P. m 0 N 0 0 J a R Section 03 — General Informatio 0' o= E-mail Address: sasselin@sterlingenergy.us m z I0IL-T88-0ZL :MILTED oy uoSJag ullOSSV Inen;S Phone Number: 720-881-7100 openolo3 'nanuaq 1225 17th Street, Suite 2520 0 Co W N N Longitude: 104°, 9', 10.7" W a 0 a a r PPM. :,i;mtoa OD G 0 won y 7 O- ay r' r H = w O z 3. r. b 0 o O y - y y b. m Co o Co cG S to co Com n n 0 4. mH O F y P Ypp N 0 0 d�; T o o 3 v y .2 O b. ;ueld SE9 leluua;uaD Sterling Energy Investments LLC Enz O 0C' 0 o H 4.1 r c c y y o O O q H 01 zz o o 0 <E. O ;w Ti 3, o 1 3 c • 3 a O_ m n F, Co 0 0 a to Section 01 -Administrative Information Ct O N C h a 0) 0 m n -CoO 't] m C N y O' 0 I-4 m z F 9 O A T00HNIWV I!! O 0 M 0 B 5 W E. -V N ti am' CD 0 gl V' 0. 0 ye. to tEr, ' Zff CP O CDm '4 . d a 48 0 G -. g• o a' z go ,--;- 5. 0 n g o o w m. 5 5-B CP CD L7,. 'V I a, K CD CD g CD CD " C pp N zm 5' 8g. °, i 0 -a g :°IQ t 5'g. r 0:03 cp 1-1 . o E a_ ..4. a.O . g ir. P M.' fF m V n 0 I a n o yC '° e ;b CD C CD 0 G -i CO I ..-, ro -to O " n O Co 4 oo . 4 O n C S P O 4-4 d I 0 co a p� S I n O O n 5 9 a CD 0 CD CD p CD 7 T A CD 0 0 O 0 DJ y . O 0 'O R. n 0 p C7 y 0 '0 a .tggri m.. 0 H 3 C3 a 9 0 n A ' 2 w m O Ci CD 0 cell" c. o O W V' O 142 01 N 000 U N CA ti0 '.p Oco co O; A N o 0 c . 2 0. M. m kg a.. n Z'E XNIoid Z'ENlosd. a 00 a ' fD 0 5 5 a(( 5 DP m a. 0 5 0 C Bt. O cr tc1 a vi 'CD p a 0, o co 0 a C uatog3g 100 0o ao3 pasn a O O' C, O ❑ O w .=j :,Couaiog3a louuoo W CP m C I-3 c 0 4 9 O p C CD C CD 0. .azIp!xp 1UUX- a1LL 00 5 0 9 oi}uo3 LU.uol;aaS Device Information (Indicate if a contro CD CD 0 •O m co DD CD DD ti CD g. 0 co 00 to 4 n o rn CD C N b cn U Up 0 -o (haulm 8ugoiu sqo y;iM IaoniaA o Co co w n ,CA cD co 0 C CD • CPI -�z Vc4' ry 5 00 CO 0 O :F° O R. O 0 00 RR M s 0 O Cif : 3.� m :K a i a N:3 Csn 0 CO CI) DD O •s O O I 0 cn co - N (D CD b O, cn y n C7 0 0 Cf O O n m O a s R. C. 0 0 d oa 0 9 CD a z cr co ro 0 cep H izy r' o p ra o C CD CD C• CD I'4 I 123-9966-010—APEN-2012-06-26-01 0 O C Pc 0 N ❑ ❑ 0 e- co 0 O- C - k k ss a a ED 3 3- d - 0 0 •-e'< 0 0 J M 0Y 3 R R d R R a y0 tl CI 0 0 0. . 0 Di O O a a O .O O O- 0 0 u c n O • b R J 0 EL utssaaoaa — pp uol;aag uuntaujnueW ment Information & Material Use 5 60 m � 0 o -go 0 w rn _ R D o 7 m C0 y p o 8 a El y 0 0G E T 1 � 0 o o m m M CO 0'' . 0 0 p ❑ O o Y 0 W CI o I o_ iii7 0 0 G . 0 O 0 b a 0' o p 8 a uc 0 R 4O -4 Pc 0 I011 188-OZL 0- :;oe;uo3 oy uoSJad 0 T 0 :iaquntN auoga OOIL-I88-OZL opu.toloD '.tanuUQ m 0 0 0 - OD 0 0- 60 w 6 040 0 co co cco a i m rn z 'a 1225 17th Street, Suite 2520 0 6 Longitude: 104°,.9', 10.7" W t�1 0 w C 0 A C c ;uula sup leluualuap Sterling Energy Investments LLC yz n on 0 a 0 N ❑ ❑ ❑ ❑ El ❑ ❑ s ❑ ❑ 0 0 c o m rt m e ^ C] O g dCC CD, ' ro 0 O o' H 3 a act C 0- in c Z B. ,C o ,CD i en y EP— ° d w m - E o Y `o' 0 m m = 0 H E 0 -'' 2 O 0 n 0 0 0 - S y 0 : 08 2< `' t 0 mtr C 0 S O o 0 x 'e 3 0 o e - o o ci H h ;. pa 0 m m o d 0. 7 O o T Y n 2 vo ? T 0 F E w 3 0 n n iv v S cr o O 'J -33 0 r7; '- C v ? O C t=1 'O 2S 1 §. oS ❑ T .. 9 ills 2U all — ZO uol;aag uested Action (check applicable request boxes) C CD 0 m 0 3 CD 5 8 CD 0 0 C 0 CD 5 . E 5' y.. S O 0 CD o 0 o'v a_ N n ', o y 1 d Cr. N 100gnd 8002-01-6.1 m H < m.• • :lo l0 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Co VOC k z p DACWi vocumeui iluu niu uuou • . Control Deyice Description Primary• 'Secondary.' w I None See Attached W 0 Emission Factor 0 Units .... Actual Cal, Fmia' Uncontrolled (Tons/Year — O C o: V O mm I 44.61 :.Requo Emi Uncontrolled: (Tons/Year ' steel Permitted . saions4' Controlled ons/Year I See Attached Y . Estimation Method or Emission Factor. Source . 1, 0 o Col C E • o o � O ▪ w. s m N 5 O ; � C o o O O rt y OO (D R m s M o o l S 0 C) C) ro _ `1 y . K C co co tn.� CD E. 0:. Company equipment Identification No. 4 m • p O ' D snquio3 — gp not;aas tTl co co E. cn m • g. • co rt 5 CD O (] N. 5 CD ▪ CD `�` 5- g II G aka •1 P C) Direction of outlet (check one): Go Go CD to DD y A U 013 54 w W J -4 41. col -4 -4 J J gi.0 al;loo9 wOp.p i7 a • tr 03 CD CD CD cD 0 o' re - to 0 ▪ O CD w 5 M CD O t-" Ctw O�y F-i CD CD CD d aaanos uo1setara 0 CD CD � m i-i 00Z-a3av N1xo3 O ocY R.$I 0 0 0 D0 c" 7C O 0 0 �9 re 3-3 0 8. 0 0 .0 O 0 g. et O G y � ryGry�� 6 N 0• C . 6••• y iJ I I 7y a 4 a. 0 n pN Fri E.O: a d — p0 uolpaS R cr S h• a O • C. M 0.0 h 0 M-: ° C •t.. R O CCD w co M '• � m -__• ¢ o 0. g a ra o a O D �a • a b o • 7 . 0 C] 5 ' rOi „ 0 FF� •.� 0 0.l .0 im I $v I O *. F ...G CDC y 0 CD 0IN 0z 0. g. a p k 43 w g `.4 �•n C E O E. r• O 0 ca ppm� SO 0 00 pgim 0 00. �t LI OA byi GC 31:1 C C, ti �0 Z.'71 x0. structed sources, the projected startup date is: 06 / 01 / Section 03 -General Information :ssa.TPPV I[UW-H :yauiaoJ 0j, 1.10SIOj C to 0 :re 0 c0 n 313 g a A CD 4 E 10IL-rss•0xk :saquynN quayd 0 00 00 V 4' ro 8: 0. 7 0. O 0' O. ' c a o0 0 a- 0 0 CA Do In Nn O os8Z atlas `1a 1S mu our 00 0 O Longitude: 104% 9';10.7' w tri re A 0 0 cD 0 0 a CD O N N zit ❑ ❑ - ❑ ❑ IZI 2 if? P. CD 0 0 • CD CD CD O C 0 0 G 9,2� ebb8. r • 0 S . ai 'GO.: a gy ii! ▪ • C O• �o . Oo O to ,D23 g gN"I�o 4 f:. • c. 0, 0. • .off Z 0 E. 0' z r m.to �0.o . ^ � 0 c ;1p 2 g co :, m o o p� �s • ❑ ❑ " ve 'V n '! y rG•• G. Qv cto oo g. C �1. g:$* �= - 01 s• t t L.GD A S' N . O O A O.vi v mR. O to nr `� '�' C. eD d • R. `e p Y LC 0' T e • q 0 ie �ii a a'E v i G I °, p '° F i•- 0 o � o .ti ,d O :1TT uotudnth A q tosa 4-3 O :ataquznN;rauad :.d W (O co Cr) Q) 0 N 0 N H CD 0 P CO K E▪ i co O N c C. to ❑ A b P b y Do -M H -mow 5 c !� V I'D a A fE o O 0 ..a0 O C/ N A con G ▪ m rtz C 0co o C P. Q m a 0 1-c co fro "0 :. C T O H �7 5 G m A to 0 a 0 "1 r^ O4uapt u -- Please use the APCD Non -Criteria Re ortable Air Pollutant Addendum form to report pollutants not listed above. n p O O O "c.' -0 I•TSP 0 c o on q Control Device Description co o: o. Overall Collection Efficiency Control Efficiency (%Reduction) Uncontrolled Basis Emission Factor E Uncontrolled (Tons/Year) r Actual Calendar Year Endssions3 Controlled (Tons/Year) 0, N 0 r a W o 0 Uncontrolled (Tons/Year) Requested Permitted Emissions4 0‘ J O YJ 4.43 too Controlled (Tons/Year) N t+ b Estimation Method or Emission Factor Source 9 tea E. a a 0 • o 0 = • n O O O O �. 'C' 0 o v n o a O O o • O- y a o 0-`1 0 d c O G O n ▪ o o 9 o a d m a y CD Section 07 — Emissions Inventory Information & Emission Contro 8 O ted values will become permit lim d level should consider process growth over the nex 0 rt O a El 0 in e v. CD K0 ”1.1 4 4 c co CO O J ai CP N 5 Company equipment Identification No.: :3amlautnumN Section 06 — Combustion E tunsuo3 land ag Iuam uolyeutaodul not m P U "O J. CO vo Ro ti 0 0 O no ®l. 0 Circular: Inner Diameter (inches) = U d :(a ❑ Horizontal 0 Down 0 Other: Length (inches) = a O F Yo r 4C y, 08 C y W 4 U J J 0 51.1 ro Section 05 — Emission Release Information (Attach a separate sheet withrelevant informat n in the event of multiple releases; provide datum & either Lat/Long or UTM) :aaqumN;nuaaa m J V Emission Source AIRS ID: w CD CO 0 C, AIR POLLUTANT EMISSION NOTICE APEN) & Application for Construction Permit — General VA O O a CD CD r. a a: �«, CD ro O. f3' C m 0 w °o p m'. rIt d'•s g �+ M 9i 0. on rD • ta .s CD A• C.. 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C O N r 4. trni • oC r�z. o pv a • a \ L Da y pro N a O z CD I. t. ▪ 8 R.- 0` ° u B an -,$)1 tI r a cLx es w O I Cr 0 0 ✓ 0 a Please use the APCD Non -Criteria Reportable Mr Pollutant Addendum form to report po t RH- 0 Lai o ea IBenzene CO Q (� ° x F a Y .Identify in Section 07 ,...,,.,..-,.:.,,4-,,,;.._.--...,_:,.:}T} y' a.. 5. Control Device Description o.. O., Q.' Control Efficiency (% Reduction) 0 E. G0. a m' Emission Factor•. Units .. : Uneontirolled ("Tons/Year) Actual Calendar. Year Einissions4 llutants not listed above. • Controlled (Tons/Year) .O rn Uncontrolled (Tons/Year) Requested Permitted Emissions O .O. 0 g. Estimation Method or •Emission Factor Source ® Emission Factor Documentation attached m m m '7 to o. C) a ' p gr O' e R 0 G G. 0 N CD on 08 —Emissions Inventory Information & Emission Control Information El El CD DC N< N g .O CD FO c. a o C o C P n O 4 mo. 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