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Home My WebLink About20151724.tiff * COPHt_ : COLORADO co Es . Department of Public • Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150O St PO Box 758 Greeley, CO 80632 R E C E I V June 4, 2015 JUN 1 0 2015 WELD COUNTY OOMMISSIQNER ► Dear Sir or Madam: On June 10, 2015, the Air Pollution Control Division will begin a 30-day public notice period for Kerr- McGee Gathering LLC - Hambert Compressor Station. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 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 -Publ.� 2015-1724 to—1-7 CC Ur- C;P1.J; k. tVio F <n�G 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe • John W. Hickenlooper,Governor Larry Wolk.MD,MSPH, Executive Director and Chief Medical Officer /A7fia , CAE Air Pollution Control Division CO Notice of a Proposed Project or Activity Warranting Public ' Comment Website Title: Kerr-McGee Gathering LLC - Hambert Compressor Station - Weld County Notice Period Begins: June 10, 2015 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: Kerr-McGee Gathering LLC Facility: Hambert Compressor Station Compression Station 18450 Weld County Road 35 Weld County The proposed project or activity is as follows: The source proposes to add one amine unit, and one additional natural gas fired compressor engine to the already existing facility wide permit. In addition, the source proposes to cover three already existing engines to the facility wide permit. The engines had previously been covered under GP02. The source is also requesting to remove fugitive emissions and the Low Emission Dehydration Units from the permit because both are below APEN reporting thresholds. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section IIl.C.1.a (25 tpy in a non-attainment area and/or 50 tpy in an attainment area) The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 12WE1210 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: David Thompson Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us &V COLORADO , STATE OF COLORADO of Coz w apt, COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT +-e Spy o AIR POLLUTION CONTROL DIVISION * r9 *` TELEPHONE: (303) 692-3150 �1816 CONSTRUCTION PERMIT PERMIT NO: 12WE1210 Issuance 2 DATE ISSUED: ISSUED TO: Kerr-McGee Gathering LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Hambert Compressor Station, located at 18450 Weld County Rd 35, Gilcrest (Section 36, Township 4N, Range 66W), in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point One (1) Caterpillar, Model G3606LE, Serial Number 4ZS00628, natural gas-fired, turbo-charged, 4SLB EU-53 007 reciprocating internal combustion engine, site rated at 1,775 horsepower at 1,000 RPM. This engine shall be equipped with an oxidation catalyst. This emission unit is used for natural gas compression. One (1) Caterpillar, Model G3606LE, Serial Number 4ZS00841, natural gas-fired, turbo-charged, 4SLB EU-54 008 reciprocating internal combustion engine, site rated at 1,775 horsepower at 1,000 RPM. This engine shall be equipped with an oxidation catalyst. This emission unit is used for natural gas compression. One (1) Caterpillar, Model G3606LE, Serial Number 4ZS00911, natural gas-fired, turbo-charged, 4SLB EU-55 009 reciprocating internal combustion engine, site rated at 1,775 horsepower at 1,000 RPM. This engine shall be equipped with an oxidation catalyst. This emission unit is used for natural gas compression. AIRS ID: 123/0059 Page 1 of 20 NGEngine Version 2012-1 Colorado Department of Public Health and Environment Air Pollution Control Division Facility AIRS Description Equipment ID Point One (1) Caterpillar, Model G3606LE, Serial Number 4ZS01177, natural gas-fired, turbo-charged, 4SLB EU-56 012 reciprocating internal combustion engine, site rated at 1,775 horsepower at 1,000 RPM. This engine shall be equipped with an oxidation catalyst. This emission unit is used for natural gas compression. One (1) Caterpillar, Model G3606LE, Serial Number 4ZS00972, natural gas-fired, turbo-charged, 4SLB EU-57 013 reciprocating internal combustion engine, site rated at 1,775 horsepower at 1,000 RPM. This engine shall be equipped with an oxidation catalyst. This emission unit is used for natural gas compression. One (1) Caterpillar, Model G3606LE, Serial Number 4ZS00281, natural gas-fired, turbo-charged, 4SLB EU-58 014 reciprocating internal combustion engine, site rated at 1,775 horsepower at 1,000 RPM. This engine shall be equipped with an oxidation catalyst. This emission unit is used for natural gas compression. One (1) Caterpillar, Model G3606LE, Serial Number 4ZS00804, natural gas-fired, turbo-charged, 4SLB EU-59 018 reciprocating internal combustion engine, site rated at 1,775 horsepower at 1,000 RPM. This engine shall be equipped with an oxidation catalyst. This emission unit is used for natural gas compression. One (1) Methyldiethanolamine (MDEA) natural gas sweetening system for acid gas removal with a design capacity of 60 MMSCF per day (make, model, serial number: TBD). This emissions unit is equipped with three (3) amine recirculation pump (make, model, TBD) with a A-1 020 total design capacity of 90 gallons per minute. This system includes a natural gas/amine contactor, a flash tank and a natural gas fired amine regeneration reboiler. Emissions from the still vent are routed to a thermal oxidizer. Emissions from the flash tank are routed to a thermal oxidizer or recycled to the reboiler for fuel. AIRS Points 007, 008, 009, 012, 013, 014, 018: These engines may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G3606LE engine 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 AIRS ID: 123/0059 Page 2 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division 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. Points 007 020: YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit or commencement of operation, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Points 012, 013, 014, 018, 020: Within one hundred and eighty days (180) after issuance of this permit or 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. Points 012, 013, 014, 018, 020: This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. Points 012, 013, 014, 018, 020: The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. Point 020: The following information shall be provided to the Division within fifteen (15) days after commencement of operation or issuance of this permit, whichever occurs later. • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment (Reference: Regulation No. 3, Part B, III.E.). 6. 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) AIRS ID: 123/0059 Page 3 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division Monthly Limits: Facility AIRS Pounds per Month Emission Type Equipment ID Point SO2 NO, VOC CO EU-53 007 --- 2,038 1,259 728 Point EU-54 008 --- 2,038 1,259 728 Point EU-55 009 --- 2,038 1,259 728 Point EU-56 012 --- 2,038 1,259 728 Point EU-57 013 --- 2,038 1,259 728 Point EU-58 014 --- 2,038 1,259 728 Point EU-59 018 --- 2,038 1,259 728 Point A-1 020 1886 688 187 578 Point (Note: Monthly limits are based on a 31-day month.) The owner or operator shall calculate monthly emissions based on the calendar month. Facility-wide emissions of each individual hazardous air pollutant shall be less than 1,359 lb/month. Facility-wide emissions of total hazardous air pollutants shall be less than 3,398 lb/month. Annual Limits: Tons per Year Facility Equipment ID AIRS Point Emission Type SO2 H2S NO, VOC CO EU-53 007 12.0 7.5 4.3 Point EU-54 008 12.0 7.5 4.3 Point EU-55 009 12.0 7.5 4.3 Point EU-56 012 12.0 7.5 4.3 Point EU-57 013 12.0 7.5 4.3 Point EU-58 014 12.0 7.5 4.3 Point EU-59 018 12.0 7.5 4.3 Point A-1 020 11.1 0.1 4.1 1.1 3.4 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 after permit issuance, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. AIRS ID: 123/0059 Page 4 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 8. AIRS Points 020: Compliance with the VOC emission limits in this permit shall be demonstrated by running a simulation model on a monthly basis using the most recent amine unit inlet extended sour gas analysis and recorded operational values (including plant inlet gas throughput, inlet gas temperature, inlet gas pressure, lean amine strength, lean amine recirculation rate, and other operational values as specified in the O&M plan). Recorded operational values shall be averaged on a monthly basis for input into the simulation model. The simulation package used shall be VMG, Prosim, ProMax or HYSYS. . 9. AIRS Points 020: The permit holder shall measure and record the lean amine strength on a weekly basis. The lean amine strength is defined as the combined weight percent of DEA, MDEA and piperazine in the lean amine stream. Measurements of lean amine strength do not have to be speciated. Records of the amine strength shall be made available to the Division for inspection upon request. (Colorado Regulation No. 3, Part A, II) 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 AIRS Pollutants Equipment Point Control Device Controlled ID EU-53 007 Oxidation catalyst VOC and CO EU-54 008 Oxidation catalyst VOC and CO EU-55 009 Oxidation catalyst VOC and CO EU-56 012 Oxidation catalyst VOC and CO EU-57 013 Oxidation catalyst VOC and CO EU-58 014 Oxidation catalyst VOC and CO EU-59 018 Oxidation catalyst VOC and CO A-1 020 Thermal Oxidizer VOC and H2S PROCESS LIMITATIONS AND RECORDS AIRS ID: 123/0059 Page 5 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division 11. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Annual Monthly Limit Equipment Point Process Parameter Limit (31 days) ID EU-53 007 Consumption of natural gas as a fuel 119.4 10.14 MMscf/yr MMscf/month EU-54 008 Consumption of natural gas as a fuel 119.4 10.14 MMscf/yr MMscf/month EU-55 009 Consumption of natural gas as a fuel 119.4 10.14 MMscf/yr MMscf/month EU-56 012 Consumption of natural gas as a fuel 119.4 10.14 MMscf/yr MMscf/month EU-57 013 Consumption of natural gas as a fuel 119.4 10.14 MMscf/yr MMscf/month EU-58 014 Consumption of natural gas as a fuel 119.4 10.14 MMscf/yr MMscf/month EU-59 018 Consumption of natural gas as a fuel 119.4 10.14 MMscf/yr MMscf/month A-1 020 Gas Throughput 21,900 1860 MMscf/yr MMscf/month The owner or operator shall calculate monthly process rates based on the calendar month. During the first twelve (12) months after permit issuance, 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. AIRS Points 020: This unit shall be limited to the maximum lean amine recirculation pump rate of 90 gallons per minute. The lean amine recirculation rate shall be recorded weekly in a log maintained on site and made available to the Division for inspection upon request. STATE AND FEDERAL REGULATORY REQUIREMENTS 13. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 14. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in AIRS ID: 123/0059 Page 6 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) 15. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 16. AIRS Points 007, 008, 009, 012, 013, 014, and 018: This equipment is subject to the control requirements for stationary and portable engines in the 8-hour ozone control area under Regulation No. 7, Section XVI.B.2. For lean burn reciprocating internal combustion engines, an oxidation catalyst shall be required. 17. AIRS Point 007, 012, 013, and 014: 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 Construction or Emission Standard in g/hp-hr HP Relocation Date NOx CO VOC <100HP Any N/A N/A N/A ≥100HP and January 1, 2008 2.0 4.0 1.0 <500HP January 1, 2011 1.0 2.0 0.7 ≥500HP July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 ' Maximum engine horsepower is the nameplate rating of the engine and does not account for deration. 24. AIRS Point 020: The 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 c- §60.5365(g)(3) - Facilities that have a design capacity less than 2 long tons per day (LT/D) of hydrogen sulfide (H2S) in the acid gas (expressed as sulfur) are required to comply with recordkeeping and reporting requirements specified in §60.5423(c) but are not required to comply with §§60.5405 through 60.5407 and §§60.5410(g) and 60.5415(g). • §60.5423— Record keeping and reporting Requirements o §60.5423(c) - To certify that a facility is exempt from the control requirements of these standards, for each facility with a design capacity less that 2 LT/D of AIRS ID: 123/0059 Page 7 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division 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. 25. AIRS Point 020: The inlet gas stream to the amine unit shall have a total sulfurs concentration, including H2S, of less than or equal to 15.0 ppm. OPERATING & MAINTENANCE REQUIREMENTS 26. AIRS Points 007, 008 009, 012, 013, 014, 018, and 020: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 27. AIRS Points 020: 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.) 28. AIRS Points 020: A source initial compliance test shall be conducted on emissions point 020 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with emissions limits and control efficiencies in this permit. The operator shall demonstrate the thermal oxidizer achieves a minimum destruction efficiency of 99.0% for VOC. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Sulfur Dioxide using EPA approved methods. Oxides of Nitrogen using EPA approved methods. Volatile Organic Compounds using EPA approved methods. Carbon Monoxide using EPA approved methods. Periodic Testing Requirements 29. AIRS Points 020: An annual source compliance test shall be conducted on emissions point 020 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with emissions 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 AIRS ID: 123/0059 Page 8 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division 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. 27. AIRS Points 007, 008, 009, 012, 013, 014, 018: These engines are subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. 28. All previous versions of this permit are cancelled upon issuance of this permit 29. This permit replaces the following permits, which are cancelled upon issuance of this permit. Existing Emission Point Existing Permit No. New Permit No. 123/0059/012 GP02 123/0059/013 GP02 12WE1210 123/0059/014 GP02 30. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOx) in ozone nonattainment areas emitting less than 100 tons of VOC or NO„ per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or AIRS ID: 123/0059 Page 9 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division 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. 31. 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). 32. MACT Subpart Z777 - 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: 33. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section 11.8 upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 34. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 35. 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. AIRS ID: 123/0059 Page 10 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division 36. 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. 37. 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 of a source may request a hearing before the AQCC for review of the Division's action. 38. 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. 39. 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: David Thompson Permit Engineer Permit History Issuance Date Description Issuance 2 This Issuance Issued to Kerr-McGee Gathering LLC Replacing GP02 coverage with a construction permit for Points 012, 013, and 014. Adding Engine, Point 018 Adding Amine Unit, Point 020 Low emissions dehydration units, point 011 and 015, are below APEN required thresholds due to the units VRU and interlock configuration. Point 004 fell below APEN required threshold after updating emission factors AIRS ID: 123/0059 Page 11 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division Issuance 1 January 2014 Issued to Kerr-McGee Gathering LLC. Replacing individual permits for Points 004, 007, 008, 009 and 011 with this facility-wide permit. Point 004— Increase VOC emission limit from 12.0 to 33.0 tpy Points 007, 008 and 009 - Decrease VOC limit for each point from 12.0 to 7.5 tpy and decrease formaldehyde emissions from 3,291 lb/yr to 2,468 lb/yr. Decrease consumption limit from 130.3 MMscf/yr to 119.4 MMscf/yr. Modifying Point 011 from traditional TEG dehy to low-emission dehy equipped with VRU(s). Adding new 50 MMscfd TEG dehy (Pt 015). AIRS ID: 123/0059 Page 12 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. , These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: http://www.colorado.gov/cs/Satellite?c=Document C&childpagename=CDPHE- Main%2FDOcument C%2FCBONAddLinkView&cid=1251599389641&pagename=CBONWrapper 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Are the Controlled AIRS Pollutant CAS# Emission emissions Emission Point Rate reportable? Rate (Ib/yr) (Ib/yr) Formaldehyde 5000 10284 Yes 2468 007, Acetaldehyde 75070 904 Yes 587 008, 009, Acrolein 107028 556 Yes 361 012, Methanol 67561 270 Yes 270 013, 014, n-Hexane 110543 120 No 120 018 EACH Benzene 71432 48 No 48 Toluene 108883 44 No 44 Benzene 71432 33600 Yes 336 Toluene 108883 26400 Yes 264 020 Ethylbenzene 100414 360 Yes 3.6 Xylenes 1330207 41800 Yes 418 n-Hexane 110543 940 Yes 9.4 5) The emission levels contained in this permit are based on the following emission factors: Points 007, 008, 009, 012, 013, 014, and 018: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 0.2220 0.7000 0.2220 0.7000 AIRS ID: 123/0059 Page 13 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division Emission Factors - Emission Factors— Uncontrol led Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr CO 0.7929 2.5000 0.0793 0.2500 VOC 0.2981 0.9400 0.1371 0.4324 5000 Formaldehyde 0.0951 0.3000 0.0228 0.0720 75070 Acetaldehyde 0.0084 0.0264 0.0054 0.0171 107028 Acrolein 0.0051 0.0162 0.0033 0.0105 67561 Methanol 0.0025 0.0079 0.0025 0.0079 110543 n-Hexane 0.0011 0.0035 0.0011 0.0035 71432 Benzene 0.0004 0.0014 0.0004 0.0014 108883 Toluene 0.0004 0.0013 0.0004 0.0013 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 6,951 Btu/hp-hr, a site-rated horsepower value of 1,775, and a fuel heat value of 905 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 5000 Formaldehyde Manufacturer Manufacturer 75070 Acetaldehyde AP-42; Table 3.2-2 (7/2000); Manufacturer Natural Gas 107028 Acrolein AP-42; Table 3.2-2 (7/2000); Manufacturer Natural Gas 67561 Methanol AP-42; Table 3.2-2 (7/2000); No Control Natural Gas 110543 n-Hexane AP-42; Table 3.2-2 (7/2000); No Control Natural Gas 71432 Benzene AP-42; Table 3.2-2 (7/2000); No Control Natural Gas 108883 Toluene AP-42; Table 3.2-2 (7/2000); No Control Natural Gas Point 020: The emission levels contained in this permit are based on information provided in the application and the Promax model. Note: The controlled emissions factors for point 020 are based on the thermal oxidizer control efficiency of 99% for the Still Vent and Flash Tank. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) AIRS Point 008, 009 and 012: These engines are subject to 40 CFR, Part 60, Subpart JJJJ— Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting — effective March 18, 2008). This rule has not yet been AIRS ID: 123/0059 Page 14 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf 8) AIRS Point 008, 009, 012, 013, 014, 018: 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 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/fr18ia08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html 9) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor of: VOC, CO and HAPs PSD Synthetic Minor of: VOC and CO MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Not Applicable MACT ZZZZ Major Source Requirements: Not Applicable Area Source Requirements: Applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A— Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE— Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN —Subpart XXXXXX 11) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: www.colorado.gov/cdphe/oilciaspermits AIRS ID: 123/0059 Page 15 of 20 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: 123/0059 Page 16 of 20 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.qov/cs/Satellite/CD PH E-AP/CBON/1251596520270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. AIRS ID: 123/0059 Page 17 of 20 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 SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/0059 Page 18 of 20 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: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date X NO CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500<Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § 1.8 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting AIRS ID: 123/0059 Page 19 of 20 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: 123/0059 Page 20 of 20 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Kerr-McGee Gathering LLC Permit Number: 12WE1210 Source Location: 18450 Weld County Road 35 Amine gas sweetening system to remove CO2 and H2S from field gas. Equipment Description: Amine unit vent stack and flash tank streams will be routed to a thermal oxidizer AIRS ID: 123/0059/020 Date: 10/1/14 Review Engineer: David Thompson Control Engineer: Chris Laplante Section 2—Action Completed Grandfathered x Modification APEN Required/Permit Exempt 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? April 7, 2014 Section 4—Source Description AIRS Point ( Equipment Description I One(1) Methyldiethanolamine (MDEA) natural gas sweetening system for acid gas removal with a design capacity of 60 MMSCF per day(make, model, serial number: TBD). 020 This emissions unit is equipped with three (3) amine recirculation pump (make, model, I TBD) with a total design capacity of 90 gallons per minute. This system includes a natural gas/amine contactor, a flash tank and a natural gas fired amine regeneration reboiler. All emissions are routed to a thermal oxidizer Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria x Yes No pollutant? If"yes", for what pollutant? PM10 CO x Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B, Section III.D.2) Page 1 Is this source located in the 8-hour ozone non- attainment region?(Note: If"yes" the provisions of x Yes No Regulation 7, Sections XII and XVII.C may apply) Section 5—Emission Estimate Information AIRS Point Emission Factor Source 020 Site-specfic using Promax Simulation Model (refer to Section 14 for calculations) Did the applicant provide actual process data for the emission inventory? Yes x No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/ThroughputProduction 020 60 mmscf per day, natural gas throughput, 90 gallons per minute lean amine circulation rate Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 020 60 mmscf per day, natural gas throughput, 90 gallons per minute lean 2008 amine circulation rate Basis for Permitted Emissions(Permit Limits' AIRS Point Process Consumption/Throughput/Production 020 60 mmscf per day, natural gas throughput, 90 gallons per minute lean amine circulation rate Does this source use a control device? X Yes No % Reduction AIRS Point Process Control Device Description Granted 020 01 Thermal oxidizer 99 Section 6—Emission Summar/ (tons per year) Point NO, VOC CO Single HAP Total HAP PTE: 020 106 20.9 (xylenes) 51.55 Uncontrolled point 020 106 20.9 (xylenes) 51.55 source emission rate: Controlled point 020 1.1 0.21 (xylenes) 0.52 source emission rate: Total APEN Reported 1.1 0.21 (xylenes) 0.52 emissions: Section 7—Non-Criteria/ Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS# BIN Emission Rate emissions Ibl r (lb/yr) reportable? Rate( y ) Benzene 71432 A 33600 Yes 336 Toulene 110543 C 26400 Yes 264 Ethylbenzene 100414 C 360 Yes 3.6 Xylenes 1330207 C 41800 Yes 418 n-Hexane 110543 C 940 Yes 9.4 Note: Regulation 3, Part A, Section ll.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. Page 2 Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory X Yes No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 020 01 VOC, Regulation No. 3, Part B., Section III.G.3 Stack Test HAPS Section 9—Source Classification Is this a new previously un-permitted source? X Yes No What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V PSD x NA NSR MACT Is this a modification to an existing permit? X Yes No If"yes"what kind of modification? Minor x Synthetic Major Minor Section 10— Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes", for which pollutants?Why? NOx and 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 Yes X No Air Quality Standards (NAAQS)? If"yes", for which pollutants?Why? AIRS Point Section 12— Regulatory Review Re•ulation 1 - Particulate, Smoke Carbon Monoxide and Sulfur Dioxide 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 011 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. Re•ulation 2—Odor 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 011 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. Page 3 Regulation 3 -APENs, Construction Permits, Operating Permits, PSD Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for 011 each individual emission point in an attainment area with uncontrolled actual emissions of two tons per year or more of any individual criteria pollutant (pollutants are not summed) for which the area is attainment. (Applicant is required to file an APEN since emissions exceed 2 tons per year VOC) Part B—Construction Permit Exemptions 011 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 ILD.3.a) Re•ulation 6-New Source Performance Standards NSPS LLL: Each sweetening (amine) unit and each sweetening unit followed by a sulfur recovery unit; manufacturer date after January 24, 1984. Applicant is not subject to NSPS LLL because ... 011 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 design capacity is less than 2 LT/D of H2S expressed as sulfur. No other requirements apply. NSPS 0000: 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 OOOO because ... 011 This source will have a design capacity less than 2 long tons/day H2S in the acid gas based on the information submitted in the application. This source will be required by 60.5423(c) to keep for the life of the equipment an analysis demonstrating that the facility's design capacity is less than 2 LT/D of H2S expressed as sulfur. No other requirements apply. Regulation 7—Volatile Organic Compounds 011 None Regulation 8— Hazardous Air Pollutants 011 None Section 13—Aerometric Information Retrieval System Coding Information Emission Emission Pollutant/ Fugitive Control Point Process Process Description Factor CAS# (Y/N) Factor (%) Source 9.7lbs/mmscf V0C No Process 99 Simulator 1.5 Ibs/mmscf Benzene/ No Process 99 71432 Simulator 1.2 lbs/mmscf Toluene/ Process No 99 01 Amine Unit 108883 Simulator 011 0.2 Ibs/mmscf Ethylbenzene/ No Process 99 100414 Simulator 1.9 Ibs/mmscf Xylenes/ Process No 99 1330207 Simulator 0.04 n-Hexane/ Process Ibs/mmscf 110543 No Simulator 99 SCC 31000305—Gas Sweetening; Amine process Emission factors include flash tank and still vent and that factors are based on natural gas processing of 21900 MMScf/yr. Page 4 Section 14—Miscellaneous Application Notes AIRS Point 011 Amine Unit The table below summarizes the inputs to the process simulation used to calculate the PTE for this equipment. TABLE 1 Parameter Value Emissions Inlet Gas Temperature 85°F Inlet Pressure 109° psig Uncontrolled emission factor calculations using ProMax VOC = (calculation) Benzene =(calculation) Toluene = (calculation) Ethylbenzene =(calculation) Xylenes =(calculation) n-hexane= (calculation) Does this amine unit have a reboiler? Yes If No, remove Note#5 in the permit template (exempt equipment associated with permitted source) If Yes, what is the reboiler rated? 1.5 mmbtu/hr If the source has a design rate less than 5 mmbtu/hr, then it is APEN-exempt(Regulation No. 3, Part A, II.D.1.k), and is therefore also exempt from construction permitting requirements (Regulation no. 3, Part B, II.D.1.a). Criteria pollutant emission levels for this unit are based on factors from AP-42, Chapter 1.4, Small Boilers < 100 MMBtu/hr(7/1998). If the source has a design rate greater than 5 mmbtu/hr, then it does not meet categorical exemptions and might need an APEN. Reflect this in Note #5 in the permit template. 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