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Home My WebLink About20171949.tiffCOLORADO 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 1150 0 St PO Box 758 Greeley, CO 80632 June 20, 2017 Dear Sir or Madam: RECEIVED JUN 232017 WELD COUNTY COMMISSIONERS On June 22, 2017, the Air Pollution Control Division will begin a 30 -day public notice period for Green River DevCo LP - Hudson CGF. 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 John W. Hickenlooper, Governor PO(O1; c Ry-v i e.w -7/S/I7 4300 Cherry Creek Drive S., Denver, Co 80246-1530 P 303-692-2000 www.colorado.gov/cdphe Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer cc : pLcmcn/TPJ( F-II.CPQx), P )CER/C-If f‘r (CK) Co('D$-1I7 2017-1949 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Green River DevCo LP - Hudson CGF - Weld County Notice Period Begins: June 22, 2017 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: Green River DevCo LP Facility: Hudson CGF Oil Et Gas exploration and production facility NW Section 22 T2N R64W Weld County The proposed project or activity is as follows: New central gathering facility, with natural gas -fired compressor engines, LP separator, vapor recovery tower, condensate storage tanks, produced water storage tanks, and one (1) diesel generator, 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 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, the Division's analysis, and a draft of Construction Permit 16WE1024 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: Andy Gruel Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us COLOR ADO 1 I C+"Fa tP'uwa Permit number: Date issued: Issued to: D t? trol Division Department of Public Health 8 Environment CONSTRUCTION PERMIT 16WE1024 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Green River DevCo LP Hudson CGF 123-9EE0 NW Section 22 T2N R64W Weld County Exploration Et Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description TBD 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. This emission unit is used for natural gas compression. Non -selective catalytic reduction (NSCR) system and air -fuel ratio control TBD 005 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. This emission unit is used for natural gas compression. Non -selective catalytic reduction (NSCR) system and air fuel ratio control TBD 006 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. This emission unit is used for natural gas compression, Non -selective catalytic reduction (NSCR) system and air -fuel ratio control TBD 007 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. This emission unit is used for natural gas compression. Non -selective catalytic reduction (NSCR) system and air -fuel ratio control COLORADO Air Pollution Control Division Page 1 of 22 Facility Equipment ID AIRS Point Equipment Description Emissions Control Description LP Separator/ Heater Treater 011 Flaring of gas from LP separator during VRU downtime. Enclosed Combustor --- 012 Two (2) 750 -barrel fixed roof atmospheric storage vessels used to store condensate. Condensate is loaded out from the tanks directly to a pipeline. Enclosed Combustor --- 013 Two (2) 750 -barrel fixed roof atmospheric storage vessels used to store produced water. Enclosed Combustor Surge Vessel 014 Flaring of gas from surge vessel separator during VRU downtime. Enclosed Combustor Points 004, 005, 006, 007: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Waukesha L7044GSI 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 Control Act (C.R.S. 25-7-101 et seq), to the specific 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 of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated COLORADO Air Pollution Control Division Page 2 of 22 rant extensions of the deadline. (Regulation Number 3, 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. (Regulation Number 3, Part B, Section III.E.) 5. Points 004, 005, 006, 007: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit: • Manufacture date • Construction date • Order date • Date of relocation into Colorado • Serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, III.E.) 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. (Regulation Number 3, Part B, Section II.A.4.) ) Monthly Limits: Facility Equipment ID AIRS Point Pounds per Month Emission PM2.5 NO, VOC CO Type TBD 004 --- 1,241 1,378 3,583 Point TBD 005 --- 1,241 1,378 3,583 Point TBD 006 --- 1,241 1,378 3,583 Point TBD 007 --- 1,241 1,378 3,583 Point LP Separator/ Heater Treater 011 --- --- --- --- Point --- 012 --- --- 2,005 --- Point --- 013 --- --- --- --- Point Surge Vessel 014 --- --- --- --- 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 not exceed 1,359 pounds per month. Facility -wide emissions of total hazardous air pollutants shall not exceed 3,398 pounds per month. COLORADO Air Pollution Control Division Page 3 of 22 Annual Limits: for hazardous air pollutants shall apply to all permitted Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO TBD 004 1.2 7.3 8.2 21.1 Point TBD 005 1.2 7.3 8.2 21.1 Point TBD 006 1.2 7.3 8.2 21.1 Point TBD 007 1.2 7.3 8.2 21.1 Point LP Separator / Heater Treater 011 --- 1.6 20.9 4.0 Point --- 012 --- --- 11.8 --- Point --- 013 --- --- 14.4 --- Point Surge Vessel 014 --- 0.8 10.6 2.0 Point ote: 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 not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. 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, for both criteria and hazardous air pollutants, 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 actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 8. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility potential emission limitations as indicated below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. (Reference: Regulation 3, Part C. II.E.) Total emissions from the facility, including all permitted emissions and potential to emit from all insignificant activities, shall be less than: • 100 tons per year of VOC; and COLORADO Air Pollution Control Division Page 4 of 22 9. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled TBD 004 Non -selective catalytic reduction (NSCR) system and air -fuel ratio control. NOx, VOC, CO, Formaldehyde TBD 005 Non -selective catalytic reduction (NSCR) system and air -fuel ratio control. NOx, VOC, CO, Formaldehyde TBD 006 Non -selective catalytic reduction (NSCR) system and air -fuel ratio control. NOx, VOC, CO, Formaldehyde TBD 007 Non -selective catalytic reduction (NSCR) system and air -fuel ratio control. NOx, VOC, CO, Formaldehyde LP Separator / Heater Treater 011 Enclosed Combustor during Vapor Recovery Unit (VRU) downtime VOC, HAPs --- 012 Enclosed Combustor VOC, HAPs --- 013 Enclosed Combustor VOC, HAPs Surge Vessel 014 Enclosed Combustor during Vapor Recovery Unit (VRU) downtime VOC, HAPs PROCESS LIMITATIONS AND RECORDS 10. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point > Process Parameter Annual Limit Monthly Limit (31 days) TBD 004 Consumption of natural gas as fuel 113.71 MMscf 9.66 MMscf TBD 005 Consumption of natural gas as fuel 113.71 MMscf 9.66 MMscf TBD 006 Consumption of natural gas as fuel 113.71 MMscf 9.66 MMscf TBD 007 Consumption of natural gas as fuel 113.71 MMscf 9.66 MMscf LP Separator / Heater Treater 011 Volume of gas vented from LP separator / heater treater 8.47 MMscf --- --- 012 Condensate throughput 547,500 bbl 46,500 bbl COLORADO Air Pollution Control Division Page 5 of 22 Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 days) 013 Produced water throughput 2,190,000 bbl Surge Vessel 014 Volume of gas vented from surge vessel 3.53 MMscf --- Points 004, 005, 006, 007: Fuel consumption shall be measured by one of the following methods: individual engine fuel meter, facility -wide fuel meter attributed to fuel consumption rating and hours of operation; or manufacturer -provided fuel consumption rate. The owner or operator shall monitor 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. 11. Points 011 and 014: The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from these separators using the measurement scheme presented in the approved O&M Plan. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 12. Points 004, 005, 006, 007, 011, 012, 013, 014: The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/9EE0/xxx) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 13. Points 004, 005, 006, 007, 011, 012, 013, 014: This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 14. Points 004, 005, 006, 007: 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 No. 7, Section XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1 Et 4.) 15. Points 004, 005, 006, 007: This equipment is subject to the control requirements for stationary and portable engines in the 8 -hour ozone control area under Regulation No. 7, Section XVI.B.1. For rich -burn reciprocating internal combustion engines, a non -selective catalyst reduction system and an air fuel controller shall be required. 16. Points 011, 012, 013, 014: The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2. 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, as defined under Regulation Number 7, XVII.A.16; 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. This flare must be equipped with an operational auto -igniter according to the following schedule: COLORADO Air Pollution Control Division Page 6 of 22 ces ins led on or after May 1, 2014, must be equipped with an opera ional au o �'m er upon installation of the combustion device; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 17. Points 011 and 014: The separator covered by this permit is subject to Regulation Number 7, Section XVII.G. (State Only). On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the date of first production by air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. 18. Point 012: This source is subject to Regulation Number 7, Section XII. The operator shall comply with all applicable requirements of Section XII and, specifically, shall: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for condensate storage tanks; and • Ensure that the combustion device controlling emissions from this storage tank be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. (Regulation Number 7, Section XII.C.) (State only enforceable) 19. Points 012 and 013: The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons except where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. 20. Points 012 and 013: The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Section XVII.C.2. OPERATING Et MAINTENANCE REQUIREMENTS 21. Points 004, 005, 006, 007, 011, 012, 013, 014: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEtM) 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 the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 22. Points 004, 005, 006, and 007: A source initial compliance test shall be conducted on these emissions points to measure the emission rates 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 COLORADO Air Pollution Control Division .;e t r Page 7 of 22 numb of operating hours for that averaging time. (Reference: egul;'Paion I . . ) Oxides of Nitrogen using EPA approved methods; Carbon Monoxide using EPA approved methods; Volatile Organic Compounds using EPA approved methods; and Formaldehyde. 23. Point 011: The owner/operator shall complete an initial site -specific extended gas analysis ("Analysis") within one hundred and eighty days (180) after commencement of operation or issuance of this permit, whichever comes later, of the natural gas vented from this emissions unit in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n -hexane, and 2,2,4- trimethylpentane content (weight fraction) of this emission stream. Results of the Analysis shall be used to calculate site -specific emission factors for the pollutants referenced in this permit (in terms of lb/MMscf gas vented) using Division -approved methods. Results of the Analysis shall be submitted to the Division as part of the self -certification and must demonstrate the emission factors established through the Analysis are less than or equal to the emission factors submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site -specific emission factor developed through this Analysis is greater than the emission factor submitted with the permit application and established in the "Notes to Permit Holder", the owner/operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). 24. Points 011, 012, 013, and 014: The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XII.C, XVII.B.2. and XVII.A.16) 25. Point 012: The owner or operator shall complete site specific sampling including a compositional analysis of the pre -flash pressurized condensate routed to these storage tanks and a sales oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site - specific emissions factor using Division approved methods. Results of site -specific sampling and analysis shalt be submitted to the Division as part of the self -certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 26. Point 013: The owner or operator shall complete site -specific sampling, including a compositional analysis and gas -to -water ratio analysis, of the pre -flash pressurized produced water routed to these storage tanks, in order to develop a site -specific emission factor for VOC, benzene, and n -hexane. Testing shall be in accordance with the guidance contained in PS Memo 14-03. Results of site -specific sampling and analysis shall be submitted to the Division as part of the self -certification. If any site -specific emission factor developed through this testing is greater than the state default emission factor listed in the "Notes to Permit Holder", the owner/operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). 27. Point 014: The owner/operator shall complete an initial site -specific extended gas analysis ("Analysis") within one hundred and eighty days (180) after commencement of operation or issuance of this permit, whichever comes later, of the natural gas vented from this emissions unit in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n -hexane, and 2,2,4- trimethylpentane content (weight fraction) of this emission stream. Results of the Analysis shall be used to calculate site -specific emission factors for the pollutants referenced in this permit (in terms of lb/MMscf gas vented) using Division -approved methods. Results of the COLORADO Air Pollution Control Division PLO Page 8 of 22 d to - Division as part of the self -certification and must emo tors - .lished through the Analysis are less than or equal to the emission factors submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site -specific emission factor developed through this Analysis is greater than the emission factor submitted with the permit application and established in the "Notes to Permit Holder", the owner/operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). Periodic Testing Requirements 28. Points 004, 005, 006, and 007: 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. 29. Point 011: On an annual basis, the owner/operator shall complete a site -specific extended gas analysis ("Analysis") of the natural gas vented from this emissions unit in order to verify the VOC content (weight fraction) of this emission stream. Results of the Analysis shall be used to calculate a site -specific emission factor for VOC, in units of lb/MMscf gas vented, using Division -approved methods. If the site -specific emission factor for VOC developed through this Analysis is greater than the emission factor submitted with the permit application and established in the "Notes to Permit Holder", the operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this inaccuracy. 30. Point 014: On an annual basis, the owner/operator shall complete a site -specific extended gas analysis ("Analysis") of the natural gas vented from this emissions unit in order to verify the VOC content (weight fraction) of this emission stream. Results of the Analysis shall be used to calculate a site -specific emission factor for VOC, in units of lb/MMscf gas vented, using Division -approved methods. If the site -specific emission factor for VOC developed through this Analysis is greater than the emission factor submitted with the permit application and established in the "Notes to Permit Holder", the operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this inaccuracy. ADDITIONAL REQUIREMENTS 31. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • 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 (NOr) 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 COLORADO Air Pollution Control Division Page 9 of 22 on- ` repo'"`: •' e 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. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 32. Federal regulatory program requirements (i.e., PSD or NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3, Part D) GENERAL TERMS AND CONDITIONS 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 Number 3, Part B, Section II.B. 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 Number 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. 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. COLORADO Air Pollution Control Division Page 10 of 22 38. .R.S r uires that all sources required to file an Air Pollution missii • ' ''= (A '' Fist pa .n 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: Andy Gruel, P.E. Permit Engineer Permit Histo Issuance Date Description Issuance 1 This Issuance Issued to Green River DevCo LP. ,COLORADO Air Pollution Control Division Page 11 of 22 No th this it 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. (Regulation Number 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: https://www.colorado.gov/pacific/cdphe/aqcc-regs 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. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions . (lb/yr) 004 Formaldehyde 50000 2,378 571 Methanol 67561 355 355 Acetaldehyde 75070 324 324 Acrolein 107028 305 305 005 Formaldehyde 50000 2,378 571 Methanol 67561 355 355 Acetaldehyde 75070 324 324 Acrolein 107028 305 305 006 Formaldehyde 50000 2,378 571 Methanol 67561 355 355 Acetaldehyde 75070 324 324 Acrolein 107028 305 305 007 Formaldehyde 50000 2,378 571 Methanol 67561 355 355 Acetaldehyde 75070 324 324 Acrolein 107028 305 305 011 Benzene 71432 2,969 148 Toluene 108883 3,091 155 COLORADO Air Pollution Control Division Page 12 of 22 AIRS Point' Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) Ethylbenzene 100414 475 24 Xylenes 1330207 713 36 n -Hexane 110543 21,006 1,050 2,2,4- Trimethylpentane 540841 2,810 141 012 Benzene 71432 2,069 104 Toluene 108883 2,253 113 Ethylbenzene 100414 325 17 Xylenes 1330207 541 28 n -Hexane 110543 15,010 751 2,2,4- Trimethylpentane 540841 1,978 99 013 Benzene 71432 15,330 767 n -Hexane 110543 48,180 2,409 014 Benzene 71432 1,747 88 Toluene 108883 1,889 95 Ethylbenzene 100414 198 10 Xylenes 1330207 495 25 n -Hexane 110543 12,768 639 2,2,4- Trimethylpentane 540841 1,597 80 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year ( b/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Points 004, 005, 006, 007: CAS # Pollutant Uncontrolled Emission lb/MMBtu Factors g/hp-fir Controlled Emission lb/MMBtu Factors g/hp-hr N0x 3.721 13.30 0.126 0.45 CO 3.133 11.20 0.363 1.3 V0C 0.671 2.40 0.140 0.5 50000 Formaldehyde 0.0205 0.073 0.005 0.018 67561 Methanol 0.00306 0.01093 0.00306 0.010958 75070 Acetaldehyde 0.00279 0.00997 0.00279 0.009991 107028 Acrolein 0.00263 0.00939 0.00263 0.009418 Note: Emission factors are based on a Brake -Specific Fuel Consumption factor of 7881 Btu/hp-hr, a site - rated horsepower of 1680 hp, and a fuel heat value of 1020 Btu/scf. COLORADO Mr PoUution Control Division Page 13 of 22 CAS # Pollutant Uncontrolled Emission Factors Source Controlled Emission Factors Source N0x Manufacturer Requested by applicant, supported by Archrock Compression Services. CO Manufacturer Manufacturer's spec is 1.0 g/hp-hr, but the applicant's request for 1.3 g/hp-hr was accepted. V0C Manufacturer Manufacturer's spec is 0.18 g/hp-hr, but the applicant's request for 0.5 g/hp-hr was accepted. 50000 Formaldehyde AP 42, Table 3.2-3 Requested by applicant, supported by Archrock Compression Services. 67561 Methanol AP -42, Table 3.2-3 (Not Controlled) 75070 Acetaldehyde AP -42, Table 3.2-3 (Not Controlled) 107028 Acrolein AP -42, Table 3.2-3 (Not Controlled) Point 011: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Controlled Emission Factors lb/MMscf Source N0x 366.2 CDPHE 3/22/2005 Memo (waste gas) and AP -42 Table 1.4-1 (pilot gas) CO 926 7 V0C 98,394 4,920 AspenHYSYS model output based on a non -site -specific gas analyisis, and Displacement Equation 71432 Benzene 350.531 17.5266 108883 Toluene 364.935 18.2468 100414 Ethylbenzene 56.026 2.8013 1330207 Xylene 84.040 4.2020 110543 n -Hexane 2,480.047 124.0024 540841 2'2'4 Trimethylpentane 331.759 16.5880 Notes: The controlled emission factors for this point are based on the enclosed combustor control efficiency of 95%. NOx and CO emission factors were calculated as follows: 1) Pilot gas: assumed 0.1825 MMscf/yr; applied AP -42 Ch 1.4 Table 1.4-1 emission factors for NOx (100 lb/MMscf) and CO (84 lb/MMscf) to that pilot gas volume; 2) Waste gas (flash/working/breathing): multiplied the VOC correlation emission factors from CDPHE 3/22/2005 memo (0.0037 lb NOx/lb VOC, and 0.0094 lb CO/lb VOC) by the VOC lb/yr (controlled) annual emissions limit based on the permit limit and VOC emission factor for this point. The NOx and CO lb/yr quantities from those two sources were summed, and divided by the gas throughput permit limit (MMscf/yr) to arrive at the lb/MMscf emission factors listed above. Emissions from this point are assumed to only occur during VRU downtime, which is requested by applicant to be limited to 169.4 hours per year. The applicant requested to track emissions from this point by gas flow meter rather than by VRU downtime hours. Point 012: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source N0x --- 0.00036 CDPHE and AP -42 COLORADO Air Pollution Control Division Page 14 of 22 CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source (see below) CO --- 0.000573 V0C 0.8623 0.0431 HYSYS and Tanks 4.0.9d based on a non -site -specific sample 71432 Benzene 0.0038 0.0002 108883 Toluene 0.0041 0.0002 100414 Ethylbenzene 0.0006 0.00003 1330207 Xylene 0.0010 0.0001 110543 n -Hexane 0.0274 0.0014 540841 2'2,4 Trimethylpentane 0.0036 0.0002 Notes: The controlled emission factors for this point are based on the enclosed combustor control efficiency of 95%. NOx and CO emission factors were calculated as follows: 1) Pilot gas: assumed 1.095 MMscf/yr; applied AP -42 Ch 1.4 Table 1.4-1 emission factors for NOx (100 lb/MMscf) and CO (84 lb/MMscf) to that pilot gas volume; 2) Waste gas (flash/working/breathing): multiplied the VOC correlation emission factors from CDPHE 3/22/2005 memo (0.0037 lb NOx/lb VOC, and 0.0094 lb CO/lb VOC) by the VOC lb/yr (controlled) annual emissions limit based on the permit's liquid throughput limit and VOC emission factor. The NOx and CO lb/yr quantities from those two sources were summed, and divided by the permit liquid throughput (bbl/yr) to arrive at the lb/bbl emission factors listed above. Point 013: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors ' lb/bbl, Source N0x --- 0.00010 CDPHE and AP -42 (see below) CO --- 0.00017 V0C 0.262 0.013 CDPHE default for Weld County 71432 Benzene 0.007 0.00035 110543 n -Hexane 0.022 0.00110 Note: The controlled emission factors for this point are based on the enclosed combustor control efficiency of 95%. NOx and CO emission factors were calculated as follows: 1) Pilot gas: assumed 1.095 MMscf/yr; applied AP -42 Ch 1.4 Table 1.4-1 emission factors for NOx (100 lb/MMscf) and CO (84 lb/MMscf) to that pilot gas volume to arrive at lb/yr NOx and CO generation; 2) Waste gas (flash/working/breathing): multiplied the VOC correlation emission factors from CDPHE 3/22/2005 memo (0.0037 lb NOx/lb VOC, and 0.0094 lb CO/lb VOC) by the VOC lb/yr (controlled) annual emissions limit based on the permit's liquid throughput limit and VOC emission factor. The NOx and CO lb/yr quantities from those two sources were summed, and divided by the permit liquid throughput (bbl/yr) to arrive at the lb/bbl emission factors listed above. Point 014: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Controlled Emission Factors lb/MMscf Source N0x 447.3 CDPHE 3/22/2005 Memo (waste gas) and AP -42 Table 1.4-1 (pilot gas) CO 1127.6 V0C 123,287 6,164 AspenHYSIS model output based on a non -site -specific gas analyisis, and 71432 Benzene 494.691 24.7346 108883 Toluene 534.908 26.7454 100414 Ethylbenzene 56.026 2.8013 COLORADO I Air Pollution Control Division V t e_., Ureiror,rivIt Page 15 of 22 CAS # Pollutant Uncontrolled '' Emission Factors lb/MMscf Controlled Emission Factors lb/MMscf Source Displacement Equation 1330207 Xylene 140.066 7.0033 110543 n -Hexane 3,617.568 180.8784 540841 2'2'4- Trimethylpentane 452.515 22.6257 Notes: The controlled emission factors for this point are based on the enclosed combustor control efficiency of 95%. NOx and CO emission factors were calculated as follows: 1) Pilot gas: assumed 0.1825 MMscf/yr; applied AP -42 Ch 1.4 Table 1.4-1 emission factors for N0x (100 lb/MMscf) and CO (84 lb/MMscf) to that pilot gas volume; 2) Waste gas (flash/working/breathing): multiplied the VOC correlation emission factors from CDPHE 3/22/2005 memo (0.0037 lb NOx/lb VOC, and 0.0094 lb CO/lb VOC) by the VOC lb/yr (controlled) annual emissions limit based on the permit limit and VOC emission factor for this point. The NOx and CO lb/yr quantities from those two sources were summed, and divided by the gas throughput permit limit (MMscf/yr) to arrive at the lb/MMscf emission factors listed above. Emissions from this point are assumed to only occur during VRU downtime, which is requested by applicant to be limited to 169.4 hours per year. The applicant requested to track emissions from this point by gas flow meter rather than by VRU downtime hours. 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) Points 004, 005, 006, and 007: 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 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/fr18ja08.pdf 8) Points 004, 005, 006, and 007: These engines are subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines (see January 18, 2008 Federal Register posting, effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines s 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 9) Point 012: This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 10) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, CO, HAPs (total, benzene, n -hexane) NANSR Synthetic Minor Source of: VOC, NOx COLORADO Air Pollution Control Division Page 16 of 22 Applicable Requirement' Status PSD Synthetic Minor Source of: CO MACT HH Area Source Requirements: Not Applicable 11) 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 COLORADO Air Pollution Coritrol Division u' .ua �uf er": C wrr:eser Page 17 of 22 CHMENT 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. COLORADO Air Pollution Control Division Page 18 of 22 op'.to „may p manently replace the existing compressor engine with er ee th -' anu rer, 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 https://www.colorado.gov/pacific/cdphe/alternate-operating-scenario-aos-reporting-forms. 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: https://www.colorado.gov/pacific/sites/default/files/AP Portable-Analyzer-Monitoring- Protocol.pdf 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. 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. COLORADO Air Pollution Control Division ,::,,, ; Page 19 of 22 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 wilt 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 S02 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 (5 60.331) and 40 CFR Part 72 (5 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. 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. COLORADO Air Pollution Control Division Page 20 of 22 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, § I.B (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 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. COLORADO Air Pollution Control Division Page 21 of 22 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 A0S is therefore essentially an advanced construction permit review. The A0S 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 A0S-approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. COLORADO Air Pollution Control Division i, r 3 Page 22 of 22 Colorado Air Permitting Project Version No. 1.00 Project Details Review Engineer: Package #: Received Date: Review Start Date: Section 01- Facility Information Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Location: Type of Facility: What industry segment? Is this facility located in a NAAQS non -attainment area? If yes, for what pollutant? ['Carbon Monoxide (CO) Andy Gruel 3S3352 9/12/2016, revised 1/30/17 10/4/2016 Green River DevCo LP 123 9E€0 Hudson CGF NW Section 22 T2N R64W Expioratimn-& Production Well Oil & Natural Gas Production & Section 02 - Emissions Units In Permit Application ❑ Particulate Matter (PM) 2 Ozone (NOx & VOC) AIRS Point # Emissions Source Type Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks 001 Natural Gas RICE Yes cancelled n/a n/a n/a cancelled Jan 30 2017 002 Natural Gas RICE Yes cancelled cancelled Jan 30 2017 003 Natural Gas RICE Yes cancelled cancelled Jan 30 2017 004 (Natural Gas RICE Yes 16WE1024 CP1 Permit Initial Issuance 005 . Naturaf Gas RICE Yes '' 16WE1024 CP1 CP1 Yes Permit Initial Issuance 006 -- - Natural Gas RICE ` - Yes 16WE1024 Yes Perntitlnftial Issuance 007 Naitira IGasRICE_ Yes 16WE1024 16WE1053.XP CP1 Yes llo Perm t Inmal Issuance 008 Diesel RICE - ' " INo XPI APEN Requited /. ,Permit Exempt XP per: Reg 3 Part B ILD.i.c.liii [emergency gen <250 havrl 009 Natural Gas RICE No cancelled n/o n/a CP1 cancelled Jan 30 2017 010 Natural Gas RICE No cancelled cancelled Jan 30 2017 011 Separatarttenting :. Yes - 16WE1024 Yes Permit Initial Issuance " LP VOC Burner" _ 012 Condensate Storage Tank Yes 16WE1024 CP1 Yes niti Permit Ial Issuance;, _. 013 Produced Waterstorage Tank- Yes . 16WE1024 CP1 Yes Permit I tai Issuance 014 : Separator Venting Yes 16WE1024 CP1 Yes Permit Initial Issuance "VRT VOC Burner" Section 03 - Description of Project Applicant requests to construct and operate a central gathering facility in the ozone non -attainment area of Weld County. Treatment does not occur at this facility, so I have classified this facility as "exploration and production'. January 30 2017 revision cancelled points 001,002, 003, 009, and 010; modified points 004, 005, 006, 007, 011, and 012;; and added new point 014. Section 04 - Public Comment Requirments Is Public Comment Required? Yes If yes, why?' RequesxingSynthetic Minor per Section 05 - Ambient Air Impact Analysis Requirements Was a quantitative modeling analysis required?' Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, explain what programs and which pollutants here: Prevention of Significant Deterioration (P50): CO Title V Operating Permits (OP) : NOx, CO, VOC HAPs (total, benzene, and n -hexane) Non -Attainment New Source Review (NANSR): NOx, VOC Is this stationary source a major source? If yes, explain what programs and which pollutants here: Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Facility Equipment ID Green River DevCo LP Hudson CGF NW Sec 22 T2N R64W TBD Permit No. AIRS Review Date Permit Engineer 16WE1024 123/9EE0/004 02/17/2017 Andy Gruel Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Waukesha, Model L7044GS1, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1680 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Natural Gas Consumption Requested (mmscf/yr) 113.71 Requested (mmscf/m) 9.66 Fuel Heat Value (btu/scf) 1020 BSCF (Btu/hp-hr) 7881 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled NOx Manufacturer's Spec Archrock Compression Services statement VOC Manufacturer's Spec Manufacturer's Spec lists 0.18 g/hp-hr, but I will accept the requested 0.5 g/hp-hr. CO Manufacturer's Spec Manufacturer's Spec lists 1.0 g/hp-hr, but I will accept the requested 1.3 g/hp-hr. Formaldehyde AP -42, Table 3.2-3 Requested by Applicant SOX AP -42; Table 3.2-3 (7/2000); Natural Gas No Control TSP AP -42; Table 3.2-3 (7/2000); Natural Gas No Control PM10 AP -42; Table 3.2-3 (7/2000); Natural Gas No Control PM2.5 AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Other Pollutants AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Point Summary of Criteria Emissions (t Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency 96.6% NOx 215.8 7.3 215.8 VOC 38.9 8.1 38.9 79.2% CO 181.7 21.1 181.7 88.4% SOx 0.0 0.0 0.0 0.0% TSP 1.1 1.1 1.1 0.0% PM10 1.1 1.1 1.1 0.0% PM2.5 1.1 1.1 1.1 0.0% Total HAPs* 0.0 0.0 1.9 48.0% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 2378 571 2378 76.0% Methanol 355 355 355 0.0% Acetaldehyde 324 324 324 0.0% Acrolein 305 305 305 0.0% Benzene 183 0.0% 1,3 -Butadiene * * 77 0.0% Toluene * * 65 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT 777Z New/Recon 4SRB over 500 HP located at a(n) Area Source Reg 7 XVII.E Standards (g/hp-hr) NOx: 1.0 CO: 2.0 VOC: 0.7 Reg 7 XVI.B (Ozone NAA requirements) applies? Yes MACT Z777 (area source) Is this engine subject to MACT 7777 area Yes source requirements? NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: JJJJ requirements are not currently included as permit conditions because JJJJ has not been adopted into Reg 6. Comments/Notes Initial APEN rec'd 9/12/16; revised APEN rec'd 1/30/17. Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Facility Equipment ID Green River DevCo LP Hudson CGF NW Sec 22 T2N R64W TBD Permit No. AIRS Review Date Permit Engineer 16WE1024 123/9EE0/005 02/17/2017 Andy Gruel Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Waukesha, Model L7044GS1, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1680 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Natural Gas Consumption Requested (mmscf/yr) 113.71 Requested (mmscf/m) 9.66 Fuel Heat Value (btu/scf) 1020 BSCF (Btu/hp-hr) 7881 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled NOx Manufacturer's Spec Archrock Compression Services statement VOC Manufacturers Spec Manufacturer's Spec lists 0.18 g/hp-hr, but I will accept the requested 0.5 g/hp-hr. CO Manufacturer's Spec Manufacturer's Spec lists 1.0 g/hp-hr, but I will accept the requested 1.3 g/hp-hr. Formaldehyde AP -42, Table 3.2-3 Requested by Applicant SOX AP -42; Table 3.2-3 (7/2000); Natural Gas No Control TSP AP -42; Table 3.2-3 (7/2000); Natural Gas No Control PM10 AP -42; Table 3.2-3 (7/2000); Natural Gas No Control PM2.5 AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Other Pollutants AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Point Summary of Criteria Emissions (tpy) Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 215.8 7.3 215.8 96.6% VOC 38.9 8.1 38.9 79.2% CO 181.7 21.1 181.7 88.4% SOx 0.0 0.0 0.0 0.0% TSP 1.1 1.1 1.1 0.0% PM10 1.1 1.1 1.1 0.0% PM2.5 1.1 1.1 1.1 0.0% Total HAPs* 0.0 0.0 1.9 48.0% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. rdous Air Pollutants (lb/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 2378 571 2378 76.0% Methanol 355 355 355 0.0% Acetaldehyde 324 324 324 0.0% Acrolein 305 305 305 0.0% Benzene * * 183 0.0% 1,3 -Butadiene * * 77 0.0% Toluene * 65 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT ZZZZ New/Recon 4SRB over 500 HP located at a(n) Area Source Reg 7 XVII.E Standards (g/hp-hr) NOx: 1.0 CO: 2.0 VOC: 0.7 Reg 7 XVI.B (Ozone NAA requirements) applies? Yes MACT Z777 (area source) Is this engine subject to MACT ZZZZ area source requirements? Yes NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: JJJJ requirements are not currently included as permit conditions because JJJJ has not been adopted into Reg 6. Comments/Notes Initial APEN rec'd 9/12/16; revised APEN rec'd 1/30/17. Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Facility Equipment ID Green River DevCo LP Hudson CGF NW Sec 22 T2N R64W TBD Permit No. AIRS Review Date Permit Engineer 16WE1024 123/9EE0/006 02/17/2017 Andy Gruel Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Waukesha, Model L7044GS1, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1680 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Natural Gas Consumption Requested (mmscf/yr) 113.71 Requested (mmscf/m) 9.66 Fuel Heat Value (btu/scf) 1020 BSCF (Btu/hp-hr) 7881 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled NOx Manufacturer's Spec Archrock Compression Services statement VOC Manufacturer's Spec Manufacturer's Spec lists 0.18 g/hp-hr, but I will accept the requested 0.5 g/hp-hr. CO Manufacturer's Spec Manufacturer's Spec lists 1.0 g/hp-hr, but I will accept the requested 1.3 g/hp-hr. Formaldehyde AP -42, Table 3.2-3 Requested by Applicant SOx AP -42; Table 3.2-3 (7/2000); Natural Gas No Control TSP AP -42; Table 3.2-3 (7/2000); Natural Gas No Control PM10 AP -42; Table 3.2-3 (7/2000); Natural Gas No Control PM2.5 AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Other Pollutants AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Point Summary of Criteria Emissions (t Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 215.8 7.30 215.8 96.6% VOC 38.9 8.10 38.9 79.2% CO 181.7 21.08 181.7 88.4% SOx 0.0 0.0 0.0 0.0% TSP 1.1 1.1 1.1 0.0% PM10 1.1 1.1 1.1 0.0% PM2.5 1.1 1.1 1.1 0.0% Total HAPs* 0.0 0.0 1.9 48.0% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 2378 571 2378 76.0% Methanol 355 355 355 0.0% Acetaldehyde 324 324 324 0.0% Acrolein 305 305 305 0.0% Benzene * * 183 0.0% 1,3 -Butadiene * * 77 0.0% Toluene * 65 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT ZZZZ New/Recon 4SRB over 500 HP located at a(n) Area Source Reg 7 XVII.E Standards (g/hp-hr) NOx: 1.0 CO: 2.0 VOC: 0.7 Reg 7 XVI.B (Ozone NAA requirements) applies? Yes MACT ZZZZ (area source) Is this engine subject to MACT ZZZZ area source requirements? Yes NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: JJJJ requirements are not currently included as permit conditions because JJJJ has not been adopted into Reg 6. Comments/Notes Initial APEN rec'd 9/12/16; revised APEN rec'd 1/30/17. Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Facility Equipment ID Green River DevCo LP Hudson CGF NW Sec 22 T2N R64W TBD Permit No. AIRS Review Date Permit Engineer 16WE1024 123/9EE0/007 02/17/2017 Andy Gruel Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Waukesha, Model L7044GS1, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1680 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Natural Gas Consumption Requested (mmscf/yr) 113.71 Requested (mmscf/m) 9.66 Fuel Heat Value (btu/scf) 1020 BSCF (Btu/hp-hr) 7881 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled NOx Manufacturer's Spec Archrock Compression Services statement VOCSpec Manufacturer's Manufacturer's Spec lists 0.18 g/hp-hr, but I will accept the requested 0.5 g/hp-hr. CO Manufacturer's Spec Manufacturer's Spec lists 1.0 g/hp-hr, but I will accept the requested 1.3 g/hp-hr. Formaldehyde AP -42, Table 3.2-3 Requested by Applicant SOx AP -42; Table 3.2-3 (7/2000); Natural Gas No Control TSP AP -42; Table 3.2-3 (7/2000); Natural Gas No Control PM10 AP -42; Table 3.2-3 (7/2000); Natural Gas No Control PM2.5 AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Other Pollutants AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Point Summary of Criteria Emissions (t Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 215.8 7.30 215.8 96.6% VOC 38.9 8.10 38.9 79.2% CO 181.7 21.08 181.7 88.4% SOx 0.0 0.0 0.0 0.0% TSP 1.1 1.1 1.1 0.0% PM10 1.1 1.1 1.1 0.0% PM2.5 1.1 1.1 1.1 - 0.0% Total HAPs" 0.0 0.0 1.9 48.0% "Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 2378 571 2378 76.0% Methanol 355 355 355 0.0% Acetaldehyde 324 324 324 0.0% Acrolein 305 305 305 0.0% Benzene * 183 0.0% 1,3 -Butadiene * * 77 0.0% Toluene * * 65 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT ZZZZ New/Recon 4SRB over 500 HP located at a(n) Area Source Reg 7 XVII.E Standards (g/hp-hr) NOx: 1.0 CO: 2.0 VOC: 0.7 Reg 7 XVI.B (Ozone NAA requirements) applies? Yes MACT ZZZZ (area source) Is this engine subject to MACT 7777 area Yes source requirements? NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: JJJJ requirements are not currently included as permit conditions because JJJJ has not been adopted into Reg 6. Comments/Notes Initial APEN rec'd 9/12/16; revised APEN rec'd 1/30/17. Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division 123-9EE0-011 16WE1024 CP1 Revised APEN rec'd 1/30/17 Equipment Description Venting and flaring of gas from LP separator during VRU downtime. Emissions are controlled by enclosed flare. Emission Calculation Method EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10 - Displacement Equation (10.4-3) Ex=Q*MW*Xx/C Ex = emissions of pollutant x Q = Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = SG of gas * MW of air Xx = mass fraction of x in gas C = molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm Throughput (Q) MW 8.47 MMscf/yr 44.03 Ib/Ib-mol 966.9 scf/hr 0.000 MMscf/d 0.72 MMscf/mo mole % MW Ibx/Ibmol mass fraction E lb/hr lb/yr tpy Helium 0 4.0026 0.000 0.000 Helium 0.0 0 0.00 CO2 1.33 44.01 0.585 0.013 CO2 1.5 13081 6.54 N2 0.03 28.013 0.008 0.000 N2 0.0 188 0.09 methane 10.64 16.041 1.707 0.039 methane 4.4 38143 19.07 ethane 15.39 30.063 4.627 0.105 ethane 11.8 103399 51.70 propane 32.34 44.092 14.2594 0.324 propane 36.4 318672 159.34 isobutane 5.54 58.118 3.2197 0.073 isobutane 8.2 71956 35.98 n -butane 19.82 58.118 11.5190 0.262 n -butane 29.4 257430 128.71 isopentane 3.25 72.114 2.3437 0.053 isopentane 6.0 52378 26.19 n -pentane 2.63 72.114 1.8966 0.043 n -pentane 4.8 42386 21.19 cyclopentane 0.91 70.13 0.6382 0.014 cyclopentane 1.6 14262 7.13 n -Hexane 1.09 86.18 0.9394 0.021 n -Hexane 2.4 20993 10.50 cyclohexane 0.34 84.16 0.2861 0.006 cyclohexane 0.7 6395 3.20 Other hexanes 0 86.18 0.0000 0.000 Other hexanes 0.0 0 0.00 heptanes 0.92 100.21 0.9219 0.021 heptanes 2.4 20604 10.30 methylcyclohexane 98.19 0.0000 0.000 methylcyclohexane 0.0 0 0.00 224-TMP 0.11 114.23 0.1257 0.003 224-TMP 0.3 2808 1.40 Benzene 0.17 78.12 0.1328 0.003 Benzene 0.3 2968 1.48 Toluene 0.15 92.15 0.1382 0.003 Toluene 0.4 3089 1.54 Ethylbenzene 0.02 106.17 0.0212 0.000 Ethylbenzene 0.1 475 0.24 Xylenes 0.03 106.17 0.0319 0.001 Xylenes 0.1 712 0.36 C8+ Heavies 0.51 118 0.6018 0.014 C8+ Heavies 1.5 13449 6.72 VOC mass fraction: 44.003 0.8421 Total VOC Emissions (Uncontrolled) 414.29 Notes Mole % based on a AspenHYSIS design model based on a non -site -specific gas analysis. Emissions only occur during VRU downtime, which is requested by applicant to be 169.4 hours per year. I assumed the average MW of C8+. annual limit assuming 95% control 20.71 Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division Flaring Information Equipment Description riare to comoust Lr separator gas aurinc vrcu aowntlme. Manufacturer TBD Model TBD Serial Number TBD Gas Heating Value 2463 Btu/scf Waste Gas Throughput 20861.610 MMBtu/yr Pilot Gas Volume Pilot Gas Volume Pilot fuel heating value Pilot Gas Throughput 500 0.1825 1020 186.15 scf/d from application MMscf/yr Btu/scf from application MMBtu/yr 123-9EE0-011 16WE1024 CP1 Revised APEN rec'd 1/30/17 Applicant requested to use AP -42 Ch 1.4 Table 1.4-1 emission factors for the pilot gas emissions. For the waste gas emissions, the source requested to use emission factors from the CDPHE 3/22/2005 "Condensate Flare Emission Factors" memo. WASTE GAS Combustion emission factor source: CDPHE Memo "Condensate Flare Emission Factors", 3/22/2005 lb CO/ lb VOC tpy CO 0.0037 lb NOX/Ib VOC tpy NOX 0.0094 1.54 PILOT Combustion emission factor source: 3.92 AP -42 Ch 1.4 Table 1.4-1 lb CO MMscf tpy CO 100 lb NOx / MMscf tpy NOX 84 0.009 TOTAL Combustion emissions: NOx: CO: 1.551 tpy 3.925 tpy 0.008 Emissions Summary My emissions calculations differed slightly from those on the APEN. The APEN amounts were higher, and so I will accept the amounts listed on the APEN, as shown below. My calculation Uncontrolled/PTE Controlled 1.6 tpy NOX 3.9 tpy CO 414.3 20.7 tpy VOC tpy VOC APEN Calculation (ACCEPTED) 1.55 tpy NOx 3.92 tpy CO 416.7 tpy VOC uncontrolled 20.84 tpy VOC controlled (from APEN) Uncontrolled Total (Ib/yr) Reportable? Controlled Total (Ib/yr) Benzene 2969 Yes 148 Toluene 3091 Yes 155 Ethylbenzene 475 Yes 24 Xylenes 712 Yes 36 n -hexane 21006 Yes 1050 224-TMP 2810 Yes 141 Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'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.' AQCC Regulation 2 _ Section I.A applies to all emission sources. "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." Produced Natural Gas Venting/Flaring Preliminary Analysis AQCC Regulation 3 Part A: An APEN is required for this source because uncontrolled VOC emissions exceed two tons per year in an attainment area. Part B: A permit is required for this source because uncontrolled VOC emissions from this facility exceed two tons per year in a nonattainment area for ozone. This source is subject to Section III. D.2 (Minor Source RACT) because it is located in a nonattainment area. RACT for this source has been determined to be the use of a flare to control emissions. Is public comment required? Public Comment Required AQCC Regulation 7 Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014? yes This separator is subject to Reg 7, Section XVII.G. and control requirements of Reg 7, XVII.B.2 Colorado Department of Public Health and Environment Air Pollution Control Division SCC Code 31000205 Emission Factors for Permit Uncontrolled NOX 366.2 lb/MMscf natura CO 926.7 Ib/MMscf natura VOC 98394 lb/MMscf natura Benzene 350.531 lb/MMscf natura Toluene 364.935 lb/MMscf natura Ethylbenzene 56.026 lb/MMscf natura Xylenes 84.040 lb/MMscf natura n -Hexane 2480.047 Ib/MMscf natura 224-TMP 331.759 lb/MMscf natura Controlled NOX 366.2 Ib/MMscf natural CO 926.7 Ib/MMscf natura VOC 4920 lb/MMscf natura Benzene 17.5266 b/MMSCt natura I oluene 18.2468 b/MMSCt natura Ethylbenzene 2.8013 b/MMsct natura Xylenes 4.2020 b/MMsct natura n -Hexane 124.0024 b/MMsct natura 224- I MP 16.5880 b/MMsct natura gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented 123-9EE0-014 16WE1024 CP1 APEN rec'd 1/30/17 123-9EE0-011 16WE1024 Condensate Storage Tank(s) Emissions Inventory Section 01- Adminstrative Information Facility AIRs ID: 123 9EE0 County Plant 0 Point Section 02 - Eauioment Description Details Detailed Emissions Unit Description: Two -(2) 750-bbtfixedroof atmospheric Storage vets storage of :Condensate, Emission Control Device Enclosed combustorwith mfnimam control efficiency of 95%'. Description: Requested Overall VOC & HAP Control Efficiency %: 95 Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Condensate Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Condensate Throughput = Barrels (bbl) per year Actual Condensate Throughput While Emissions Controls Operating = Barrels (bbl) per year 547,500.: Barrels (bbl) per year Secondary Emissions - Combustion Device(s) Pilot Gas Volume 3000 scud Pilot Gas Volume 1.095 MMscf/yr Pilot fuel heating value 1020 Btu/scf Pilot Gas Throughput 1116.9 MMBtu/yr from application (500 scf/d per burner, six burners) from application Applicant requested to use AP -42 Ch 1.4 Table 1.4-1 emission factors for the pilot gas emissions. For the waste gas emissions, the source requested to use emission factors from the CDPHE 3222005 "Condensate Flare Emission Factors" memo. WASTE GAS (Flash/W/B) Combustion emission factor source: CDPHE Memo "Condensate Flare Emission Factors", 3/22/2005 0.0037 0.04 lb NOX/lb VOC tpy NOX PILOT Combustion emission factor source: 0.0094(lb CO/ lb VOC 0.11Jtpy CO AP -42 Ch 1.4 Table 1.4-1 lb CO MMscf tpy CO 100 lb NOx / MMscf tpy NOX 84 0.055 TOTAL Combustion emissions: NOx: CO: 0.098 tpy 0.157 Spy Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? 0.046 Emission Factor (Ib/bbl) 0.00036 lb Noutbl 0.000573 ib COibbl Condensate Storage Tanks Control Device Pollutant PM10 PM2.5 NOx VOC CO Uncontrolled E.F. Controlled E.F. (Ibs/bbl (Ibs/bbl Condensate Condensate Throughput) Throughput) 0.8623 0.0431 Benzene Toluene 0,5038 0.0002 0. 0.0006 0.00003 00010 0.000 0.0274 0.0014 1 0.0002 Ethylbenzene Spleen n -Hexane 224 TMP 0036 0.0002 Section 05 - Emissions Inventory Uncontrolled E.F. Uncontrolled (Ibs/MMBtu E.F. (lbs/bbl waste heat Condensate combusted) Throughput) Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) NOx VOC CO 0.1 0.1 0.10 0.0 0.0 236.1 236.1 11.80 0.0 0.0 0.2 0.2 0.16 0.0 0.0 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Benzene Toluene Ethylbenzene Xylene n -Hexane- 224 TMP 1.0E+00 1.0E+00 5.2E-02 0.0E+00 0.0E+00 1.1E+00 1.1E+00 5.6E-02 0.0E+00 0.0E+00 1.6E-01 1.6E-01 8.2E-03 0.0E+00 0.0E+00 2.7E-01 2.7E-01 1.4E-02 0.0E+00 0.0E+00 7.5E+00 7.5E+00 3.8E-01 0.0E+00 0.0E+00 9.9E-01 9.9E-01 4.9E-02 0.0E+00 0.0E+00 Emissions Factor Source Citation Controlled PTE Uncontrolled PTE (Ib/yr) (lb/yr) 2081 104 2245 112 329 16 548 27 15002 750 1971 99 4 of 10 K:\PA\2016\ 16WE1024.CP1.xlsm Condensate Storage Tank(s) Emissions Inventory Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XII.C, D, E, F Storage tank is subject to Regulation 7, Section XII, as provided bel Regulation 7, Section XII.G, C Storage Tank is not subject to Regulation 7, Section XII.G Regulation 7, Section XVII.B, C.1, C.3 Storage tank is subject to Regulation 7, Section XVII, B, CI & C.3, a Regulation 7, Section XVII.C.2 Storage tank is subject to Regulation 7, Section XVII.C.2, as provide Regulation 6, Part A, NSPS Subpart Kb Storage Tank is not subject to NSPS Kb Regulation 6, Part A, NIPS Subpart 0000 Storage Tank is not subject to NSPS 0000 Regulation 8, Part E, MACE Subpart HH Storage Tank is not subject to MACT HH (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company use a site specific envisions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and intial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling 123-9EE0-012 16WE1024 CP1 Revised APEN rec'd 1/30/17 Section 08 - Technical Analysis Notes Applicant used HYSIS to model flash etnmums, .based on a model throughput of 15,000 bpd (625 barrels/hr), which is roughly 10x the requested permit throughput of 1500 bpd. The -mass flow (lb/hr) of VOC and HAPs from the model were divided by the 625 bph rate to derive the flash EFs.(lb/bbl) for VOC and HAP, as follows: VOC:127542; Bi:0.0033; Tot, 0.0036; Ebzt 0.0005;. Xy): 0:0009; n -Hex: 0:0240; 224TMP:0.0032. - Applicant used Tanks 4.0.9d to:model working&- breathing emissions from the tanks. The total lb/yrfrom working/breathing wa s modeled at 59117.15 Ib/yr, for a working/breathing contribution to.the VOC emission factor of0.1081lb/bbl. HAPs: 8x:0:0005; Tel: 0.0005; Ebz:9:0001;.X91:.0.0001; n -Hex: 0.0034; 224TMP:0.0005. -- The flash EFs were added to the working/breathing tIn to arrive at the overall EF5 listed above_ Applicant requestedseparateemission factors for the pilot light emissionsand the waste gas emissions.Pilot gas ernissio n factor was from AP -42 Ch Y.4 table 1.4-1 (large wall -flied boilers), which the applicant claims: more closely models emissions from pilot gas emissions than does the emission factor for an open -tipped flare.. The applicant requested that waste gas combustion emissions be based on the CDPHE 3/22/2005 memo"Condensate Hare Emission. Factors I accepted these, and made the following calculations toarrive at an overall Ib/tibi emission factor for pilot plus waste gas: NOxc.'-: Pont .100lb NOx/MMscf. Totalvolumefrom-pilot: - 0.5 Mscf/d per burner; 6 burners;,=3:OMscf/d =1:095 MMscf/yr; multiply by EF to get 109.5 lb NOx/yr.. Waste: 0.0037 lb NOn/Ib.VOC, multiply by controlled VOC emissions of 23606 lb/yr . 87.34 lb NOx/yr. Total: 196.84 lb NOx/yr. Dividethis by 547500 barrels to arrive at EF of-0.00036Ito NOx/bbl. CO: Pilot:: 84 lb CO/MMscf. Total volumefrom pilot: DS Mscf/d per burner;: 6 burners;. =3.0 Mscf/d = L095 MMscf/yr; multiply by EF to get 91.981b CO/yr from: Waste: 0.0094tb CO/lb VOC; multiply by controlled VOC emissions of 23606lb/yr=221.9-lb.NOx/yr. - --- Total: 313.88. lb CO/yr. Divide this by 547500 barrels to arrive at EF of 0.0005731b-CO/hOP. Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 012 Process # SCC Code 01 °.. Uncontrolled Emissions Pollutant Factor Control % Units NOx 0.0086 0 lb/1,000 gallons condensate throughput VOC 20.5310 95 lb/1,000 gallons condensate throughput CO 0.0136 0 lb/1,000 gallons condensate throughput Benzene 0.0905 95 lb/1,000 gallons condensate throughput Toluene 0.0976 95 lb/1,000 gallons condensate throughput Ethylbenzene 0.0143 95 lb/1,000 gallons condensate throughput Xylene 0.0238 95 lb/1,000 gallons condensate throughput n -Hexane 0.6524 95 lb/1,000 gallons condensate throughput 224 IMP 0.0857 95 lb/1,000 gallons condensate throughput 5 of 10 K:\PA\2016\16WE1024.CP1.xlsm Condensate Storage Tank(s) Emissions Inventory Issuance Date: December 30, 2015 Section 05 - Emissions Inventory Section 01- Adminstrative Information Facility AIRS ID: 123 SEED 013 County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Eight (B) 6000 -bbl fixed roof atmospheric storage vessels for storage of'. Enclosed combustor with minimum 95% control efficiency. 95 Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Produced Water Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Produced Water Throughput= Barrels (bbl) per year Actual Produced Water Throughput While Emissions Controls Operating = 190,000', Barrels (bbl) per year Barrels (bbl) per year Secondary Emissions - Combustion Device(s) Pilot Gas Volume 3000 scf/d from application (500 scf/d per burner, six burners) Pilot Gas Volume 1.095 MMscf/yr Pilot fuel heating value 1020 Btulscf from application Pilot Gas Throughput 1116.9 MMBtu/yr Applicant requested to use AP -42 Ch 1.4 Table 1.4-1 emission factors for the pilot gas emissions. For the waste gas emissions, the source requested to use emission factors from the CDPHE 3/22/2005 'Condensate Flare Emission Factors' memo. WASTE GAS (Flash) Combustion emission factor source: CDPHE Memo "Condensate Flare Emission Factors", 3/22/2005 0.0037 0.05 lb NOX/lb VOC 0.0094 tpy NOX 0.13 PILOT Combustion emission factor source: lb CO/ lb VOC tpy CO AP -42 Ch 1.4 Table 1.4-1 lb CO MMscf tpy CO 100 lb NOx / MMscf tpy NOX 84 0.055 TOTAL Combustion emissions: NOx: CO: 0.11 tpy 0.18 tpy Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Pollutant 0.046 Produced Water Storage Tanks Uncontrolled E.F. (Ibs/bbl Produced Water Throughput) Controlled E.F. (Ibs/bbl Produced Water Throughput) Emission Factor (lb/bbl) 0.00010 lb Nos/bbl 0.00017 lb CO/bbl Control Device Uncontrolled E.F. (Ibs/MMBtu waste heat combusted) Uncontrolled E.F. (Ibs/bbl Produced Water Throughput) IIIIICZW411740401AWII • 01:01\_____ 0.00010 =119.1.\\\\ IL.N.W1 O.flD7 + 0.00035 gw a 6XXXXX1N Xi I I \\ `III\'-' 0.00110 Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 NOx VOC CO 0.11 0.11 0.11 0.0 0.0 286.89 286.9 14.34 0.0 0.0 0.18 0.18 0.18 0.0 0.0 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 7.67 7.7E+00 3.8E-01 0.0E+00 0.0E+00 24.09 2.4E+01 1.2E+00 0.0E+00 0.0E+00 Emissions Factor Source Citation Controlled PTE Uncontrolled PTE (lb/yr) (lb/yr) 15330 766.5 48180 2409 6 of 10 K:\PA\2016\ 16WE1024.CPt.xlsm Condensate Storage Tank(s) Emissions Inventory Issuance Date: December 30, 2015 Section 06- Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XVII.B, C.1, C.3 Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3, a Regulation 7, Section XVII.C.2 Storage tank is subject to Regulation 7, Section XVII.C.2, as provide Regulation 6, Part A, NSPS Subpart OOOO Storage Tank is not subject to NSPS OOOO (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use a site specific envisions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn at the facility being permitted and analyzed using flash liberation analysis? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor. See PS Memo 14-03, Questions 5.9 and 5.12 for additional guidance on testing. 123-9EE0-013 16We1024 CP1 APEN rec'd 9/12/16 Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and intial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08- Technical Analysis Notes Applicant: used statedefauh EFs for: flash emissions. NOx and CO emissions for the flash gas ere based on the March 2005 COPHE memo which is based on condensate gas volume, which cnnservatvewhen comparedto the gas volumes expected from this produced:mafer Sank battery. The pilot gas emissions were based on AP•42'Table 1.4-1 which is acceptable approach. emissionsifrom a pilotufiame. Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # Process IF SCC Code 013 01 4-04-003-15 Fixed Roof Tank, Produced Water, working+breathing+Flashing losses Uncontrolled Emissions Pollutant Factor Control % Units NOx 0.0023 0 lb/1,000 gallons liquid throughput VOC 6.2381 95 lb/1,000 gallons liquid throughput CO 0.0039 0 lb/1,000 gallons liquid throughput Benzene 0.1667 95 Ib/1,000 gallons liquid throughput n -Hexane 0.5238 95 Ib/1,000 gallons liquid throughput 7 of 10 K: \ PA\2016\ 16 W E 1024. C P 1. xl s m Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division 123-9EE0-014 16WE1024 CP1 APEN rec'd 1/30/17 Equipment Description Venting and flaring of gas from VRT during VRU downtime. Emissions are controlled by enclosed flare. Emission Calculation Method EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10 - Displacement Equation (10.4-3) Ex=Q*MW*Xx/C Ex = emissions of pollutant x Q = Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = SG of gas * MW of air Xx = mass fraction of x in gas C = molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm Throughput (Q) MW 3.529 MMscf/yr 48.44 Ib/Ib-mol 402.9 scf/hr 0.000 MMscf/d 0.30 MMscf/mo mole % MW Ibx/lbmol mass fraction E lb/hr lb/yr tpy Helium 0 4.0026 0.000 0.000 Helium 0.0 0 0.00 CO2 0.46 44.01 0.202 0.004 CO2 0.2 1885 0.94 N2 0 28.013 0.000 0.000 N2 0.0 0 0.00 methane 1.9 16.041 0.305 0.006 methane 0.3 2838 1.42 ethane 8.8 30.063 2.646 0.055 ethane 2.8 24635 12.32 propane 32.28 44.092 14.2329 0.294 propane 15.1 132534 66.27 isobutane 6.9 58.118 4.0101 0.083 isobutane 4.3 37342 18.67 n -butane 25.91 58.118 15.0584 0.311 n -butane 16.0 140220 70.11 isopentane 4.61 72.114 3.3245 0.069 isopentane 3.5 30957 15.48 n -pentane 3.77 72.114 2.7187 0.056 n -pentane 2.9 25316 12.66 cyclopentane 0 70.13 0.0000 0.000 cyclopentane 0.0 0 0.00 n -Hexane 1.59 86.18 1.3703 0.028 n -Hexane 1.5 12760 6.38 cyclohexane 1.33 84.16 1.1193 0.023 cyclohexane 1.2 10423 5.21 Other hexanes 0.49 86.18 0.4223 0.009 Other hexanes 0.4 3932 1.97 heptanes 1.33 100.21 1.3328 0.028 heptanes 1.4 12411 6.21 methylcyclohexane 0 98.19 0.0000 0.000 methylcyclohexane 0.0 0 0.00 224-TMP 0.15 114.23 0.1713 0.004 224-TMP 0.2 1596 0.80 Benzene 0.24 78.12 0.1875 0.004 Benzene 0.2 1746 0.87 Toluene 0.22 92.15 0.2027 0.004 Toluene 0.2 1888 0.94 Ethylbenzene 0.02 106.17 0.0212 0.000 Ethylbenzene 0.0 198 0.10 Xylenes 0.05 106.17 0.0531 0.001 Xylenes 0.1 494 0.25 C8+ Heavies 0.9 118 1.0620 0.022 C8+ Heavies 1.1 9889 4.94 VOC mass fraction: 48.440 9349 Total VOG emissions (Uncontro annual limit assuming 95% control Notes Mole %, MW, and mass fractions based on a AspenHYSIS design model based on a non -site -specific gas analysis. Emissions only occur during VRU downtime, which is requested by applicant to be 169.4 hours per year. I assumed the average MW of C8+. 10.54 Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division Flaring Information Equipment Description Flare to combust VRT as during VRU downtime. Manufacturer TBD Model TBD Serial Number TBD Gas Heating Value 2463 Btu/scf Waste Gas Throughput 8692.338 MMBtu/yr Pilot Gas Volume Pilot Gas Volume Pilot fuel heating value Pilot Gas Throughput 500 0.1825 1020 186.15 scf/d MMscf/yr Btu/scf MMBtu/yr from application from application 123-9EE0-014 16WE1024 CP1 APEN rec'd 1/30/17 Applicant requested to use AP -42 Ch 1.4 Table 1.4-1 emission factors for the pilot gas emissions. For the waste gas emissions, the source requested to use emission factors from the CDPHE 3/22/2005 "Condensate Flare Emission Factors" memo. WASTE GAS Combustion emission factor source: CDPHE Memo "Condensate Flare Emission Factors", 3/22/2005 lb CO/ lb VOC tpy CO 0.0037 lb NOX/Ib VOC tpy NOX 0.0094 0.78 PILOT Combustion emission factor source: 1.98 AP -42 Ch 1.4 Table 1.4-1 lb CO MMscf tpy CO 100 lb NOx / MMscf tpy NOX 84 0.009 TOTAL Combustion emissions: NOx: CO: 0.789 tpy 1.990 tpy 0.008 Emissions Summary My emissions calculations differed slightly from those on the APEN. amounts listed on the APEN, as shown below. My calculation The APEN amounts were higher, and so I will accept the Uncontrolled/PTE 0.8 tpy NOX 2.0 tpy CO 210.9 tpy VOC Controlled 10.5 tpy VOC APEN Calculation (ACCEPTED) 0.789 tpy NOx 1.990 tpy CO 217.55 tpy VOC uncontrolled 10.58 tpy VOC controlled (from APEN) Uncontrolled Total (Ib/yr) Reportable? Controlled Total (lb/yr) Benzene 1746 Yes 87 Toluene 1888 Yes 94 Ethylbenzene 198 No 10 Xylenes 494 Yes 25 n -hexane 12767 Yes 638 224-TMP 1597 Yes 80 Regulatory Applicability AQCC Regulation 1 _ This source is subject to the opacity requirements for flares in Section II.A.5:'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.' AQCC Regulation 2 _ Section I.A applies to all emission sources. "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." Produced Natural Gas Venting/Flaring Preliminary Analysis CC Regulation 3 Colorado Department of Public Health and Environment Air Pollution Control Division Part A: An APEN is required for this source because uncontrolled VOC emissions exceed two tons per year in an attainment area. Part B: A permit is required for this source because uncontrolled VOC emissions from this facility exceed two tons per year in a nonattainment area for ozone. This source is subject to Section III. D.2 (Minor Source RACT) because it is located in a nonattainment area. RACT for this source has been determined to be the use of a flare to control emissions. Is public comment required? Public Comment Required AQCC Regulation 7 Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014? yes This separator is subject to Reg 7, Section XVII.G. and control requirements of Reg 7, XVII.B.2 SCC Code 31000205 Emission Factors for Permit Uncontrolled NOX 447.3 lb/MMscf natura CO 1127.6 Ib/MMscf natura VOC 123287 lb/MMscf natura Benzene 494.691 lb/MMscf natura Toluene 534.908 lb/MMscf natura Ethylbenzene 56.026 lb/MMscf natura Xylenes 140.066 lb/MMscf natura n -Hexane 3617.568 lb/MMscf natura 224-TMP 452.515 lb/MMscf natura Controlled NOX 447.3 lb/MMscf natural CO 1127.6 lb/MMscf natura VOC 6164 lb/MMscf natura benzene 24.7346 b/MMsct natura I oluene 26.7454 b/MMsct natura Ethylbenzene 2.8013 b/MMsct natura Xylenes 7.0033 b/MMsct natura n-l-lexane 180.8784 b/MMsct natura 224- I MP 22.6257 b/MMsct natura gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented 123-9EE0-014 16WE1024 CP1 APEN rec'd 1/30/17 123-9EE0-014 16WE1024 O w S W 0 U S E 2 E E U u T U a a a E 2 REMARKS 'New Facility - No Previous Total y 'revised APEN recd 1/30/17 'revised APEN recd 1/30/17 'revised APEN recd 1/30/17 'revised APEN recd 1/30/17 XP per Reg 3 Part B Ii.D.1.c.(ii) {emergency generator less than 250 hrs/vr1 C C " F,,. ro a ti m based on 169.4 hours of VRU downtime/yr revised APEN recd 1/30/17 APEN rec'd 9112/16 based on 169.4 hours of VRU downtime/vr from Form 102 (Sept 2016) from Form 102 (Sept 2016) (from Form 102 (Sept 2016) from Form 102 (Seot 2016) IVOC: Syn Minor (NANSR and OP) 'NOx: Syn Minor (NANSR and OP) CO: Syn Minor (PSO and OP) HAPS: Syn Minor B, n -hex, & Total HH: Syn Minor 7777: Syn Minor Excludes units exempt from permits/APENs Pubcom required based on new svn minor limits Facility is NOT eligible for GP02 because > 90 tpy Initial application rec'd 9/12/2016, revised APENs and cancellations recd 1/30/17. Application "complete" 2/28/17. M a O Q H S a a '•0 ,v 0 0 m 0 m O 0 O 0 6,a...-6 ,,,,00,0.L0 j 0 10 ,0 m 0 0 0 0 0 0 0 N r N n o (,7 O 0 o p N N .- N .- N O O: N 6 a N O C N < O V r r 0 0 mm m U LL ›.0 0.0 0 N 0 O O O 0 0 0U ] 00 00 m m aC m NO O m m N t7 m C O GCO e, N O O 00 at W CO O 00 otrn Q0 z 0 0 0 r r r r ., m 7 .- C O O .-- r I m m I I - Total VOC Facility Emissions (point and fugitive) (4 I ) Change in Total Permitted VOC emissions (point and fugitive) N O a O O o a O N O N N O O a 0 0 a a O a a 0 0 f a 0 o o 0 o c 0 0 o 0 a 0 0 0 0 0 6 0 0 0 0 0 F = O p '• ^- m O 0 O m m M 0 0 0 O U 00 O0 r ^O .- — O ON N N 0 N v,v, ��.-ei e r P2 c U LL j 00 O O o 0 0 0 U 0 0 0 0 a 1 s .- v, 7 a ,-00 m M < N 6 N N X O 77 O O o U z o0 0 o N N m N m N t°oo o rr m m O a a O O a N O O N a a S 0 0 o 0 0 a 0 m 2 a O O O O O a O a 0 0 00 0 c o o Description 'Previous FACILITY TOTAL Previous Permitted Facility,total c u T C� 2 V 0 o w 7 tl V v Waukesha 7044GSI 1680HP Waukesha 7044GSI 1680HP Waukesha 7044OSi 1680HP Waukesha 704400) 1680HP emergency generator "GENT" Cummins ()SKI 5-09 NR 2 Zm � G z I LP separator venting/flaring Condensate storage, 1500 -bbl Produced water storage, 6000 -bbl VRT venting/flaring IAPEN-Exempt / Insignificants: Fugtiives Heater Treater Heater Treater Heater Treater Permitted Facility Total (0) Chan a in Permitted Emissions PERMIT V � .., G 0 N O 3 O 10WE1024 0 3 b V O 3 m a x M 0 3 m "' ? L ' U L N C 0 0 W.. mm!! N N 0 0 FACILITY TOTAL 2 CI) Q K 0. .., V :.'L 0 0 C' 0 0 m 0 0 m 0 2 a c . 0 000 M< r .d. z N .d. z COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY - HAPs Company Name County AIRS ID Plant AIRS ID Facility Name Green River DevCo LP 123 SEES Hudson CGF POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane McOH 224 TMP H2S 1,3 Butadiene TOTAL (tpy) Previous FACILITY TOTAL 001 Cancelled Caterpillar G3408 255HP "COMP 1" 002 Cancelled Caterpillar G3408 255HP "COMP 2" 003 Cancelled Caterpillar G3408 255HP "COMP 3" 004 16WE1024 Waukesha 7044GS1 1680HP 2378 324 305 183 65 3 23 355 77 1.9 005 16WE1024 Waukesha 7044GS1 1680HP 2378 324 305 183 65 3 23 355 77 1.9 006 16WE1024 Waukesha 7044GSI 1680HP 2378 324 305 183 65 3 23 355 77 1.9 007 16WE1024 Waukesha 7044GS1 1680HP 2378 324 305 183 65 3 23 355 77 1.9 008 16WE1053.XP emergency generator "GEN1" Cummins QSX 2 1 0 1 0 0.0 009 Cancelled 'VRU I' Make/model TBD 010 Cancelled "VRU 2" Make/model TBD 011 16WE1024 LP separator venting/flaring 2969 3091 475 712 21006 2810 15.5 012 16WE1024 Condensate storage, 1500 -bbl 2081 2245 329 548 15002 1971 11.1 013 16WE1024 Produced water storage, 6000 -bbl 15330 48180 31.8 014 16WE1024 VRT venting/flaring 1746 1888 198 494 12767 1597 9.3 APEN-Exempt / Insignificants: Fugliives 0.0 Heater Treater 0.0 Heater Treater 0.0 Heater Treater 0.0 TOTALftpy) 4.8 0.6 0.6 11.4 3.7 0.5 0.9 48.5 0.7 3.2 0.0 0.2 75.1 'Total Reportable = all HAPs where uncontrolled emissions s de minimus values Red Text: uncontrolled emissions < de minimus POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane McOH 224TMP H2S 1,3 Butadiene TOTAL (tpy) Previous FACILITY TOTAL 001 Cancelled Caterpillar G3408 255HP "COMP 1" 002 Cancelled Caterpillar G3408 255HP "COMP 2" 003 Cancelled Caterpillar G3408 255HP "COMP 3" 004 16WE1024 Waukesha 7044GS1 1680HP 571 324 305 183 65 3 23 355 58 0.9 005 16WE1024 Waukesha 7044GS1 1680HP 571 324 305 183 65 3 23 355 58 0.9 006 16WE1024 Waukesha 7044OSI 1680HP 571 324 305 183 65 3 23 355 58 0.9 007 16WE1024 Waukesha 7044GSI 1680HP 571 324 305 183 65 3 23 355 58 0.9 008 16WE1053.XP emergency generator "GEN1" Cummins QSX 2 1 0 1 0 0.0 009 Cancelled "VRU 1' Make/model TOD 010 Cancelled "VRU 2" Make/model TBD 011 16WE1024 LP separator venting/flaring 148 155 24 36 1050 141 0.8 012 16WE1024 Condensate storage, 1500 -bbl 104 112 16 27 750 99 0.6 013 16WE1024 Produced water storage, 6000 -bbl 767 2409 1.6 014 16WE1024 VRT venting/flaring 87 94 10 25 638 80 0.5 APEN-Exempt / Insignificants: Fugliives 0.0 Heater Treater 0.0 Heater Treater 0.0 Heater Treater 0.0 TOTAL (tpy) 1.1 0.6 0.6 0.9 0.3 0.0 0.1 2.4 0.7 0.2 0.0 0.1 72 2 1239EE0.xlsx 3/6/2017 Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 /004 [Leave blank unless APCD has already assigned a permit = and AIRS ID] Section 1 - Administrative Information Company Name': Green River DevCo LP Site Name: Hudson CGF Site Location: NW S22 T2N R64W Mailing Address: (Include Zip Code) 1625 Broadway, Suite 2200 Portable Source Home Base: Denver, CO Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Shaun Higgins Phone Number: 720-587-2459 E -Mail Address2: shaun.higgins@nblenergy.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 1 I �a ik()e_P f)-10'Plso- 35331I COLORADO !tanmen el Plelrc i1�.1[Ir a Enu�renr..rr:f Permit Number: 16WE 1024 AIRS ID Number: 123 /9EE0/ 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If coverage under General Permit GPO2 is requested, an additional fee of $1,500.00 is required in lieu of hourly fees. -OR - E1 MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit E Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ▪ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info It Notes: Revision of initial submittal 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 GP02 fee is not required, but APEN filing fee is required. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? If yes, provide the Company Equipment Identification No. not yet General description of equipment and purpose: Gas compression For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: / /www.colorado.gov/cdphe/attainment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 25 TBD 0 Yes ❑ No hours/day 7 days/week 52 weeks/year Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Reciprocating Internal Combustion Engine APEN . Revision 11/2016 COLORADO 2 I - = u 7,'.ti Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 / 004 [Leave blank unless APCD has already assigned a permit a and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: 0 Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7044GS1 Serial Number6: TBD hours/year What is the maximum designed horsepower rating? 1680 hp What is the engine displacement? 9.6 1/cyl What is the maximum manufacturer's site -rating? 1680 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7881 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke 4 -Stroke Combustion: ❑ Lean Burn 0 Rich Burn Ignition Source: O Spark ❑ Compression Aspiration: ❑ Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No If yes, what type of AFRC is in use? O Oz Sensor (mV) ❑NOx Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOx design? ❑ Yes 0 No Engine Dates: What is the manufactured date of this engine? TBD What date was this engine ordered? TBD What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 Reciprocating Internal Combustion Engine APEN - Revision 11/2016 3 COLORADO Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 / 004 [Leave blank unless APCD has already assigned a permit and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.13, -104.539278 Operator P Stack ID No. Discharge Height Above Ground Level (Feet) Temp. ( F) Flow Rate (ACFM) Velocity (ft/sec) Indicate the direction of the Stack outlet: (check one) Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Circular ❑ Square/Rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load Actual Annual Fuel Use Requested Annual Permit Limit7 / (SCF/hour) (MMSCF/year) (MMSCF/ year) 5119 '2 / Zigo 44/.84 11 3.71 45/84 I/.3, / From what year is the actual annual amount? PTE Indicate the type of fuel used': ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) 0 Field Natural Gas Heating value: 1020 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 DewrrncrumPulAx COLORADO Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0/004 [Leave blank unless APCD has already assigned a permit and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? O Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 Sox STGT NOx NSCR g66� g‘-1 VOC NSCR /79.2 CO NSCR 88.4 Other: CHCO. NSCR 76.0 Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? PTE Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions' Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) • Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 0.01941 Ib/MMBtu AP -42 1.13 1.13 1.13 1.13 PM10 0.01941 Ib/MMBtu AP -42 1.13 1.13 1.13 1.13 PM z 5 0.01941 Ib/M M Btu AP -42 1.13 1.13 1.13 1.13 SOx 0.000588 1b/MMBIu AP -42 0.03 0.03 0.03 0.03 NOx 13.30 g/hp-hr Mfg. 215.76 7.30 215.76 7.30 VOC 2.40 g/hp-hr Mfg. 38.93 8.11 38.93 8.11 CO 11.20 g/hp-hr Mfg. 181.69 21O9 181.69 21.09 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: EYes No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions' Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0.0205 Ib/MM8tu AP -42 2378 571 Acetaldehyde 75070 0.0028 IbIMMBIu AP -42 324 324 Acrolein 107028 0.0026 IbIMMBtu AP -42 305 305 Benzene 71432 Other: Methanol 0.0031 lb/MMBtu AP -42 355 355 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. g Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 5 I AY COLORADO Drnal,, , A,etfa MwFn F ime�nm.x� Permit Number: 16WE 1024 AIRS ID Number: 123 /9EE0 /004 [Leave blank unless APCD has already assigned a permit and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Legally Authorized Person (not a vendor or consultant) Date Shaun Higgins Air Permitting Supervisor Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 (if applying for GP02 For more information or assistance call: submit with an additional $1500), to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN • Revision 11/2016 COLORADO 6 I CV7 ixa„��rz r..n�c HYI:F 6 Ennnnman, t „M30 "tli Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Qov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 /005 [Leave blank unless APCD has already assigned a permit A and AIRS ID] Section 1 - Administrative Information Company Name': Green River DevCo LP Site Name: Hudson CGF Site Location: NW S22 T2N R64W Mailing Address: (Include Zip Code) 1625 Broadway, Suite 2200 Portable Source Home Base: Site Location County: Weld NAICS or SIC Code: 1311 Denver, CO Permit Contact: Shaun Higgins Phone Number: 720-587-2459 E -Mail Address2: shaun.higgins@nblenergy.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-2O1 Reciprocating Internal Combustion Engine APEN - Revision 11 /2016 11 A® COLORADO Dw Pt� Permit Number: 16WE 1024 AIRS ID Number: 123 / 9EE0 / 005 [Leave blank unless APCD has already assigned a permit r* and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If coverage under General Permit GP02 is requested, an additional fee of $1,500.00 is required in lieu of hourly fees. - OR - Q MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit O Change permit limit ❑ Transfer of ownership" ❑ Other (describe below) - OR APEN submittal for update only (Blank APENs wilt not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: Revision of initial submittal 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 GP02 fee is not required, but APEN filing fee is required. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? If yes, provide the Company Equipment Identification No. General description of equipment and purpose: Gas compression not yet For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: //www.colorado.gov/cdphe/attainment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 25 TBD [] Yes ❑ No hours/day 7 days/week 52 weeks/year Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 COLORADO 2 I .V �.cammr mz.rce� HcaYlr fi Envrrorrm.ni Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 /005 [Leave blank unless APCD has already assigned a permit R and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump El Water Pump ❑ Emergency Back-up O Other: 0 Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7044GS1 Serial Number': TBD hours/year What is the maximum designed horsepower rating? 1680 hp What is the engine displacement? 9.6 l/cyl What is the maximum manufacturer's site -rating? 1680 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7881 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke E 4 -Stroke Combustion: ❑ Lean Burn E Rich Burn Ignition Source: ❑ Spark E Compression Aspiration: ❑ Natural E Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? E Yes E No If yes, what type of AFRC is in use? O2 Sensor (mV) ONOx Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑ Yes 0 No Engine Dates: What is the manufactured date of this engine? TBD What date was this engine ordered? TBD ❑ Other: What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the ofd engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 V COLORADO 3 1 ckmmP �. w�E;.„ammo, El Upward ❑ Horizontal Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 / 005 [Leave blank unless APCD has already assigned a permit g and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.13, -104.539278 Operator P Stack ID No. Discharge Height Above Ground Level (Feet) Temp. (�F) Flow Rate (ACFM) Velocity (ft/sec) Indicate the direction of the Stack outlet: (check one) ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): ❑ Square/Rectangle Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load (SCF/hour) Actual Annual Fuel Use , (MMSCF/year) Requested Annual Permit Limit' (MMSCF/year) 121 go 4484 113. 3-I 45O4 111...( From what year is the actual annual amount? PTE Indicate the type of fuel usede: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) Field Natural Gas Heating value: 1020 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-2O1 - Reciprocating, Internal Combustion Engine APEN - Revision 11 /2016 4 I i&V COLORADO hnvrmmi a1 hbil, Ho.i�hb Envlronm.n1 Permit Number: 16WE1024 AIRS ID Number: 123 / 9E E0 /005 [Leave blank unless APCD has already assigned a permit N and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? O Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 SOX A sTGT NOX NSCR 96 , 6 VOC NSCR ' 792 CO NSCR 88.4 Other: CHCC: NSCR 76.0 Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? PTE Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions9 Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 0.01941 Ib/MMBtu AP -42 1.13 1.13 1.13 1.13 PM i 0 0.01941 Ib/MMBtu AP -42 1.13 1.13 1.13 1.13 PM 2.5 0.01941 Ib/MMBtu AP -42 1.13 1.13 1.13 1.13 SOX 0.000588 Ib/MMBtu AP -42 0.03 0.03 0.03 0.03 NO 13.30 94 -hr Mfg. 215.76 7.30 215.76 7.30 VOC 2.40 g/hp-hr Mfg. 38.93 8.11 38.93 8.11 CO 1120 g/hp-hr Mfg. 161.69 21.09 181.69 21.09 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: EYes El No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service(CAS) Emission Factor Actual Annual Emissions9 Uncontrolled Basis Units Number Mfg. etc) (Pounds/year) Source (AP -42, Uncontrolled Emissions Controlled Emissions (Pounds/year) Formaldehyde 50000 0.0205 Ib/MMBtu AP -42 2378 571 Acetaldehyde 75070 0.0028 Ib/MMBtu AP -42 324 324 Acrolein 107028 0.0026 Ib/MMBtu AP -42 305 305 Benzene 71432 Other: Methanol 0.0031 Ib/MMBtu AP -42 355 355 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1112_016 COLORADO 5 I e'ofou:R.m�nr w�� H ' 'v Enviionm.n� Permit Number: 16WE 1024 AIRS ID Number: 123 /9EE0 / 005 [Leave blank unless APCD has already assigned a permit C and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Legally Authorized Person (not a vendor or consultant) Date Shaun Higgins Air Permitting Supervisor Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 (if applying for GP02 For more information or assistance call: submit with an additional $1500), to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692.3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 COLORADO 6 I AikYr Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/aped. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 16WE 1024 AIRS ID Number: 123 /9EE0 /006 [Leave blank unless APCD has already assigned a permit ;a and AIRS ID] Section 1 - Administrative Information Company Name': Green River DevCo LP Site Name: Hudson CGF Site Location: NW S22 T2N R64W Mailing Address: (Include Zip Code) 1625 Broadway, Suite 2200 Portable Source Home Base: Denver, CO Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Shaun Higgins Phone Number: 720-587-2459 E -Mail Address2: shaun.hig gins@nblenergy.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that wilt appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 3 M EJJ sew, Ai) 3533`13 COLORADO 1 LLVV::7T ®W p�wam�i wnoc N41111 a EnvNenrnrnr Permit Number: 16WE 1024 AIRS ID Number: 123 /9EE0/ 006 [Leave blank unless APCD has already assigned a permit At and AIRS ID] Section 2 - Requested Action El NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source El PORTABLE source El Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If coverage under General Permit GP02 is requested, an additional fee of $1,500.00 is required in lieu of hourly fees. -OR - ❑✓ MODIFICATION to existing permit (check each box below that applies) El Change fuel or equipment Cl Change company name El Add point to existing permit O Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit-exempt/grandfathered source El Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info & Notes: Revision of initial submittal 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 GP02 fee is not required, but APEN filing fee is required. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? If yes, provide the Company Equipment Identification No. not yet General description of equipment and purpose: Gas compression For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.gov/cdphe/attainment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 25 TBD EYes 0 N hours/day 7 days/week 52 weeks/year Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 COLORADO 2 i ,V tam s'aanunt tam b Fnriemun+ni Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 / 006 [Leave' blank. unless APCD has already assigned a permit and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: 0 Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7044GS1 Serial Number6: TBD hours/year What is the maximum designed horsepower rating? 1680 hp What is the engine displacement? 9.6 l/cyl What is the maximum manufacturer's site -rating? 1680 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7881 BTU/hp-hr Engine Features: Cycle Type: O 2 -Stroke 0 4 -Stroke Combustion: ❑ Lean Burn 0 Rich Burn Ignition Source: ❑ Spark ❑ Compression Aspiration: ❑ Natural E Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes O No If yes, what type of AFRC is in use? 0 0Z Sensor (mV) ENO Sensor (ppm) Is this engine equipped with a Low-NOx design? O Yes 0 No Engine Dates: What is the manufactured date of this engine? TBD What date was this engine ordered? TBD ❑ Other: What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 COLORADO 3 I `:=1".4N"..1!, 1! Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 / 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/longitude or UTM) 40.13, -104.539278 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. (.F) Flow Rate (ACFM) Velocity (ft/sec) Indicate the direction of the Stack outlet: (check one) E Upward ❑ Downward ❑ Horizontal ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) E Circular Interior stack diameter (inches): ❑ Square/Rectangle Interior stack diameter (inches): Interior stack depth (inches): ❑ Other (describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 1OO% Load (SCF/hour) Actual Annual Fuel Use (MMSCF/ year) Requested Annual Permit Limit' (MMSCF/ year) 592 fZ180 45 . 4 I/31 -I 45 4 //3-7l From what year is the actual annual amount? PTE Indicate the type of fuel used": ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) 0 Field Natural Gas Heating value: 1020 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the Listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 4 A. COLORADO wean.,.m.e.. ywsti< 6 Envrror.mrnr Permit Number: 16WE1024 AIRS ID Number: 123. / 9EE0 / 006 [Leave blank unless ARC0 has already assigned a permit # and AIRS ID) Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 2 Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PMio PM2.5 Sox sr&`T NOX NSCR /' 96 16-'6 VOC NSCR /79.2 CO NSCR 88.4 Other: CHCO: NSCR 76 0 Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? PTE Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions9 Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 0.01941 Ib/MMBtu AP -42 1.13 1.13 1.13 1.13 PM10 0.01941 Ib/MMBtu AP -42 1.13 1.13 1.13 1.13 PM 2.5 0.01941 Ib/MMBtu AP -42 1.13 1.13 1.13 1.13 5OX 0.000588 Ib/MMBtu AP -42 0.03 0.03 0.03 0.03 NOX 13.30 glhp-hr Mfg. 215.76 7.30 215.76 7.30 VOC 2.40 g/hp-hr Mfg. 38.93 8.11 38.93 8.11 CO 11.20 g/hp-hr Mfg. 181.69 21.09 181.69 21.09 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? Yes r] No If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions9 Uncontrolled Basis Units Source (AP -42, mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0.0205 Ib/MMBtu AP -42 2378 571 Acetaldehyde 75070 00028 Ib/MMBtu AP -42 324 324 Acrolein 107028 0.0026 Ib/MMBtu AP -42 305 305 Benzene 71432 Other: Methanol 0.0031 Ib/MMBtu AP -42 355 355 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 5 COLORADO DepaarrttentuP.lFc Hu11F b Gvnonnumt Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 /006 [Leave blank unless APCD has already assigned a permit g and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Legally Authorized Person (not a vendor or consultant) Date Shaun Higgins Air Permitting Supervisor Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance O Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 (if applying for GP02 For more information or assistance call: submit with an additional $1500), to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 COLORADO Form APCD-201 - Reciprocating Internet Combustion Engine APEN - Revision 11/.2016 6 Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 /007 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Green River DevCo LP Site Name: Hudson CGF Site Location: NW S22 T2N R64W Mailing Address: (include Zip Code) 1625 Broadway, Suite 2200 Portable Source Home Base: Denver, CO Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Shaun Higgins Phone Number: 720-587-2459 E -Mail Address2. shaun.higgins@nblenergy.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 1 I rtfen Mg� 4,2 3533tiy COLORADO Hul!M1a ELnenin.n, Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 / 007 [Leave blank unless APCD has already assigned a permit ^ and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If coverage under General Permit GP02 is requested, an additional fee of $1,500.00 is required in lieu of hourly fees. -OR - ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit El Change permit limit ❑ Transfer of ownership's ❑ Other (describe below) - OR APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ID APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info a Notes: Revision of initial submittal 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 GP02 fee is not required, but APEN filing fee is required. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? If yes, provide the Company Equipment Identification No. not yet General description of equipment and purpose: Gas compression For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.wv/cdphe/attainment) TBD 0 Yes ❑ No Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD 201 Reciprocating Internal Combustion Engine APENRevision 11/2016 2 I eA. COLORADO Department Pull, Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 / 007 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump El Water Pump ❑ Emergency Back-up ❑ Other: El Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7044GSI hours/year Serial Number': TBD What is the maximum designed horsepower rating? 1680 hp What is the engine displacement? 9,6 l/cyl What is the maximum manufacturer's site -rating? 1680 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7881 BTU/hp-hr Engine Features: Cycle Type: El 2 -Stroke El 4 -Stroke Combustion: ❑ Lean Burn El Rich Burn Ignition Source: ❑ Spark ❑ Compression Aspiration: ❑ Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? El Yes ❑ No If yes, what type of AFRC is in use? 0 O2 Sensor (mV) ❑NOx Sensor (ppm) El Other: Is this engine equipped with a Low-NOx design? ❑ Yes 0 No Engine Dates: What is the manufactured date of this engine? TBD What date was this engine ordered? TBD What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 ®� COLORADO / 6 3/6 /)r ),tr S-11,2)441 PTE F om what year is the actual annual amount? Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 / 007 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.13, -104.539278 Operator P Stack ID No. Discharge Height Above Ground Level (Feet) Temp. ('F) Flow Rate (ACFM) Velocity (ft/sec) Indicate the direction of the Stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ID Circular Interior stack diameter (inches): ❑ Square/Rectangle Interior stack diameter (inches): Interior stack depth (inches): ❑ Other (describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 1OO% Load (SCF/hour) Actual Annual Fuel Use (MMSCF/year) Requested Annual Permit Limit' (MMSCF/year) %C I Z9So 4584 //3.-74 4 j (?. ( l z/2g fi } ndicate the type of fuel used: /❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) 0 Field Natural Gas Heating value: 1020 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 AVCOLORADO Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 / 007 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? [] Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 SOX 1, STET NOX NSCR 'G , 6 VOC NSCR ,.96 79.2 CO NSCR 88.4 I Other: CHCO: NSCR 76.0 1 Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? PTE Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions9 Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 0.01941 lb/MMBtu AP -42 1.13 1.13 1.13 1.13 PM 10 0.01941 lb/MMBtu AP -42 1.13 1.13 1.13 1.13 PM 2.5 0.01941 lb/MM Btu AP -42 1.13 1-13 1.13 1.13 SOX 0.000588 IbIMMBtu AP -42 0.03 0.03 0.03 0.03 NO 13.30 g/hp-hr Mfg. 215.76 7.30 215.76 7.30 VOC 2.40 g/hp-hr Mfg. 38.93 8.11 38.93 8.11 CO 11.20 glhp-hr Mfg. 181.69 21.09 181.69 21.09 Does the emissions source have any uncontrolled actual emissions of non -criteria Yes pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? ❑ No If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions9 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0.0205 Ib/MMBIu AP -42 2378 571 Acetaldehyde 75070 0.0028 Ib/MMBIu AP -42 324 324 Acrolein 107028 0.0026 Ib/MMBIu AP -42 305 305 Benzene 71432 Other: Methanol 0.0031 Ib/MMBIu AP -42 355 355 7 Requested values will become permit limitations. Requested timit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 5 I Ai COLORADO _ eMime „o Permit Number: 16WE1024 AIRS ID Number: 123 /9EE0 /007 [Leave blank unless APCD has already assigned a permit T and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. c -ate_ ►,Z Signature of Legally Authorized Person (not a vendor or consultant) Date Shaun Higgins Aft Permitting Supervisor Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 (if applying for GP02 For more information or assistance call: submit with an additional $1500), to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 COLORADO AV6 I g 6 £nvuanm.n, Internal Combustion En Emission Source AIRS ID: Permit Number: z W CD Facility Equipment ID: Section 02 — Requested Action (check applicable request boxes) Section 01 — Administrative Information New Source: Company Name: Green River DevCo LP. Request for a standard Construction Permit Hudson CGF Source Nam C ca - U p ^n u O O U E T u � C O C .- U 0 taU 7 Ea u ti > > O O U o L G `z C U P- ar d g -o NW S22 T2N R64W Source Loca Portable Source (may only stay at one site for <2 years) 0 Stationary Source N LU C O > U y 1625 Broadway, Suite 2200 "O C0 2 U 0 Cl Modification of Permit L C cs F CJ C 000 0 N O N 0 Co 0 0 U N O U a) C a) 0 Shaun Higgins Person To Contact 303-228-4286 Fax Number: 720-587-2459 Phone Number: Section 03 -General Information 0 C3 a) C a) O a) O 0 a) a) O C O O ct E N: C) cc j y O - C/ with a check for O C) C C s w U_ O Cd) CC O C A U u ,r C L N Gc G = O o 14 e,cip 4: U A U aLJ U o c 0 U d APEN form, contact: Model: QSX15-G9 NR 2 T C r C) U CC LC o r O r > 'J p - 0 - 9 d C) 'O C �CC a C C- cip Td ,47 oCs o s P. zo U o p 7 C ; o 8- 04, 3 0 _ O y r " 'O C O U O m O a C r CO U 5 3 GO C LL C y U U 0 U U G C3 :J 0 0 J c,-3 0 C " _ y U n U z = T 0 d d CO y O z 8 CO ID m F- 0 m F— y J 4: CO C *Date of First Location into Colorado: O Cfl H C-0 O U7 CO' CC U C C C v C U C y C. Z. C C C C C C iF APEN- Diesel F cv O Cq a FORM APCD-213 Internal Combustion En w •r O rA Permit Number: O OD O 0 r .-7 0 J "G U -to O O'. 0) U 0 0. 0 0 O P W 0 0) r1. U C c O) U G 0 0) U W a) 0) O O 0 •ct -104.539278 M co v > V 0 J CU c Q N O z w 0 0) © 0) 0 .x U r 0 U Q Width (inches) = X Data Year (e.g. 2013) : hunt Information Section 06 — Fuel Data and Throu Diesel Fuel Heat Value (Btu/gal) Annual Throughput: gallons/year OR hours/year Requested (specify units) Data Year Actual (specify units) Fuel Use Rate @ 100% load (gallon/hour) N M Section 07 — Emissions Inventory Information 0 O U C c 0 0 0 CC 0 E I) 0 C) O 0 CC U Q O O U O) 2 0 CC F 0. CD 0 0 O s 0) 0 U Emission Factor Source (Mfg, AP -42, etc) Manf. Manf. Manf. AP -42 Manf. Manf. Manf. Requested Emissions (tons/year) 0.00 0.00 0.00 0.19 1.07 0.02 0.09 Actual Data Year Emissions2 (tons/year) O f^J o C 0 I .. L L l. -c L L Q_ L L L Q. L 2 MM W ,- L L Q_ L O) L L Q_ L O) L Q. L a) L O O 0 0 LO O O Co CC c. a- 0- 0 ° Y, O>0 (..) O 0 On L C7 CO Cn ``' • a) 0 O C O c '- ;2'. a.) c • N CIL • O E' O 0 U C O • OU � U Er O U � n N :n 7-1 '.C 0 0 C 0 00 2 0 N ..d 0 U U C C O rn i O O r - W7'+ 00 N ' U CC N Co y w J WT.r ti ago U 2. • >, C.7 0 N EC N C • p —. L^-. CJ 0. 0 L N O 2 • C.1 411 0 O r, .., T L., o r 4. co 0 ✓ C c• •uC > 2 .. OU O • ' ao co x 0 o C ❑ U cA C) U C CC 0. p O U C -o C) 0 0 U 09/08/2016 Name of Legally Authorized Person (Please print) 0 CC H 0 0. CC bD O (1.5 c, W Co O C APEN- Diesel Engine -I N W 0 N 0 aO CC CL. FORM APCD-213 es i.i C'7 z E O ct w W.; L) C z C z N C 0 O W W C) CC) Emission Source AIRS ID: [Leave blank unless APCD has already assigned a permit # & AIRS ID] 16WE1024 Permit Number: referenced within your organization.] [Provide Facility Equipment ID to identify how this equipme Section 02 — Requested Action (check applicable request boxes) Section 01— Administrative Information Request for NEW permit or newly reported emission source U a, O 0. C. h ❑ CC O a U CC C) CJ E b.1) ❑ ❑ CU z O F d U O O El Change company name Change fuel or equipment Transfer of ownership Change permit limit Request to limit I1APs with a Federally enforceable limit on PTE L 3 N N 00 1625 Broadway Suite 2200 C) c O v 0 O O cu -77 C) U CJ C 0 CC 0 or z a d C z C) 0 0 U c- 0 U C C 0 O ,73 O E C) O p C) L N CO c C c C) U C, C) 0 0 0 T O L O. 0 p .p a a O 00 U O v a Q.o O C) r. - 0 ❑ ❑ CC C 0 <z 303-228-4286 Fax Number: Section 03 — General Information For new or reconstructed sources, the projected startup date is: L CC >, U N C) U 3 CC 'o T r .C L O N U 0 00 O 0. 0 0. C) 0. 0 C 0 N 7 co 0 G C) C E C O C CC .C CC u u_ 3 0. 0 C E L CC C C) C 0 0 0 U C U 0. O Ca O C 0 U O O Q n ( 0 O 00 V1 n v N - ri) r ) r' N N N u '0oCC. o M rl rn U 0 0 CD 0 0 b . O O z Lu c a n Cucn o --FT. p OA L T) O 0 o a O C n o Q P 3 0 y o N 3 b . L C Q O o U ' y U U p U.. 0 O .C p -OC 7 7 4:2C) 0_ z cC L L).) L° ¢ &) < Application status:http://www.colorado.gov/cdphe/pennitstatus O oX O z A ca C C) Cu 0 C/C aL Q 'CU zE T C C .Y c c� O O bD .C 0 C CC C c • 3 y 3 3 O ment Information Section 04 — Processin C) 8 O 0 0 C CC U CC v 3 F • l- c 00 U 0 CC C) 0 O 7 0 Irk O Cu CC) O CQ1 C� C C 0D C CU O cC C C r Ov 7 • V) C • U c p v = F c 0 C7 c. M M scf/event Blowclowns: M 4-5 U C 4 o❑®❑❑❑ ❑ O CO C x3 q fd C) N 1 T VO Process Parameters: fj U Z‘;‘, N U X C) N CC 0 wV C y C 7 O EC E a � N O co O2 > Molecular Wt. Vented Gas Properties: C) U C U C C U Cu = C. O O 0 0 0 C. n O. es CC o 0 0 O a O U U U C) 0 Q O' V 1J O O X X .0 CJ .) - CD U ❑ ❑ AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Natural Gas Ventin 0 w w Q� O Emission Source AIRS ID: Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Section 05 — Stack Information (Combustion stacks must be listed here) o L b0 0 0 O C u -o 7 7 • E E 0A N N v U O a .� g lb! • Z 0. O O — Other (Describe): 0 Width (inches) = ❑ Horizontal ❑ Down ❑ Other: Length (inches) = Vertical ❑ Vertical with obstructing raincap ® Circular: Inner Diameter (inches) _ :tion of stack outlet (check one): O Exhaust Opening Shape & Size (check one): Section 07 — Control Device Information Section 08 — Emissions Inventory Information & Emission Control Information Estimation Method or Emission Factor Source AP- 42/HYSYS AP- 42/CDPHE AP- 42/CDPHE AP -42 AP- 42/}IYSYS AP 42/HYSYS cn > U) C., -- Q7 AP- 42/HYSYS cl) >. ci) C. ¢7 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. J Requested Permitted Emissions Controlled (Tons/Year) 20.84 0D ,-+ CC M co co O O O co O 0.02 Is) O J .--. 0 C L 1 O 0 •r 7 1.49 7 V) — et. N O 0 t7 O V) C •-i Actual Calendar Year Emissions 'l Controlled (Tons/Year) U -+ r O %.-i; U 3 Emission Factor Units lb/MMSCF lb/MMSCF lb/MMSCF LT. � a Ls. on a C. Cl) a LT. � a V. � a lb/MMSCF Uncontrolled Basis 98387.02 0 e7 0 N 0 C O � © t7 364.88 O In 0 O OO 00 2479.86 Control Efficiency (% Reduction) In C' In 0 .4 01 In C\ 95 II) 0 Overal Collection Efficiency O O O O O O O O O O O O Control Device Description Secondary Primary CD CD O U CD CD CD Pollutant VOC XON CO O V) Benzene Toulene I) = I.) N O) .T u U C O - n -Hexane AP Fonn-APCD-2II-Natural-Gas-Venting-APEN-LP.doc FORM APCD-211 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Natural Gas Ventin 4 Cot p'9 a.) Cri ed to Supply Da O ct FORM APCD-211 Ci W 0 LLJ U I- 0 Z Z co VO V W• es' F— Q ZE Q O U O M a) J a O � O a cc a w m a) Q a) ce a. cc ce ce U 16WE1024 Permit Number: Green River DevCo LP Company Name: a N O 0 NW S22 T2N R64W Plant Location: shaun.higgins@nblenergy.com E-mail Address: Controlled Actual Emissions (lbs/year) 140.50 Uncontrolled Actual Emissions Ibs/ ear) 2809.95 Emission Factor Source HYSYS Emission Factor (Include Units) 331.73 lb/MMSCF Control Equipment / Reduction (%) 95 Chemical Name c ca c c a) Q T -c a) E F- N N Chemical Abstract Service (CAS) Number 4 co 0 ear for which Actual Data Applies: co U N- O N_ CO N N a) ca 0 CO (TS a Q Q U) O a) N O To O) a) - J O a) 0 0 a) O) Air Permitting Supervisor Shaun Higgins Title of Person Legally Authorized to Supply Data Name of Person Legally Authorized to Supply. Data (Please print) O 7.7 Form Revision Date: A O W W O) Emission Source AIRS ID: [Leave blank unless APCD has already assigned a pennil # & AIRS ID] 16WE1024 Permit Number: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Facility Equipment ID: Section 02 — Requested Action (Check applicable request boxes) Section 01— Administrative Information z 0 a Change company name Change process or equipment N rs Transfer of ownership Change permit limit N 00 •• O o V] O 0"al U Q V o z c3 m N APEN Submittal for Permit Exempt/Grandfathered source L C) 0. 0.1 a O O C ra 0 N O C V G 0 0 O 0. a 0 L Q E .0• Lip p, .o a _y .o ❑ ❑ a O U i V C Revision of intial submittal Section 03 — General Information For new or reconstructed sources, the projected startup date is: rn O 0 N N Normal Hours of Source Operation: wnstream 0 C C_ aO+ U O c� C' oO. � C O � y - U C O G O Q N o c c O 0 .v L E U C Li) -0 .C t ul c- T L 2 C) O 0 � z z� ❑I U L O U 3 C t C _O O 4_0L �. U 2 L 0. O. T O _ C6 0) > 5 z . 0 6) C> 0 0 a QL'. O to G L..© •-- 0 �' • E N s C > .O .� vi d - a V) a O O c7 ` 0.yg o > W r,„,_, O L L C a v O\ O w [4C• U ry . E O 'j ,,y ` tn N 7. 0 • c O 69 - C3U.r E O C°C, .-a a .Ti a z U y. G Q n�. b0^0 u aui a CU - 7 .y a -= Q G = = c% 4.•'a _ t h 0. u -.E'..6 ❑ .. ) U .0 •� 7 Gr O .L. O L 4'. c m '9 W e ❑ y L C u .E L ocD o c° o E o �v L O •0 'a to 4 E 4. L L N O.0 c cs y y$ 0... U O E.L.-.w Z p) 00 ❑ .° v) v CAn LO 0 O 3 c _ a o c o u a L or .= E a s L L O cJ 0 E .N Cr) +- V. CZ U V O C > ..o.. 0y+ _ 0 (, O > C)a � P. 0 7 L'l t_ iUa 0 For guidance on how to complete this APEN form: 0 C0 00 v N M M M V s4DCD W C M M M O O o M .0 C) U >O APEN forms: htto://www.colorado. )crmitstatus O ://www.coloraclo Application status: to, r V) O c O a 0 c 71..., v O O y C ¢ ,n ❑ Y c - o o °? nl E c 0.. 0... N • O V ti0 U 4- Cl -a 0 0 0 0 C vi . '"et. U O a L Pu c b- m % = O .y 0 0 5 O O a 0 0 F-' •O. 0 —^. > • C I Q C)D .. 0 c C) i v0i 7 0 g¢ a � c 0. 61 a 6) o z7 ._ C c oD x cn w cV O U L o .m O_ u ♦ c u o C� E=J3a C7 i UE U T L Requested Permit Limit: a Q C- 0 0 L O u A Average API Gravity of Sales Oil: External Floating Ro El 0 CD c CD c O 0 0 J L Do V 0 E -- a a Z 0 + u a ho C. _� L am.• C w N Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) Newly Reported Well ❑ ■ ■ ■ Name of Well API Number IIII AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensat N (0, w W 0 0 Emission Source AIRS ID: H L. on .3 CC J aJ a) CC CC V 0 E O u O ai U O C) CJ CC 0 u a) a 0 V) r aJ O O CC C F-1 C) CJ C C/1 N 0 0 V a) J �o QCQ 7. s L. CC Cr.) C:L CJ U CC F gnu -104.539278 ao CID yUy U " o � Ci o w" y E'- sa J 0 J as ¢ b V 0 " 00 U 2 2 U CID sic E Direction of stack outlet (check one): Exhaust Opening Shape & Size (check one): CC C e Storage Tank(s) ed for contro ion Device C\ Manufacturer Guaranteed: T o 0 0 CC In 2 Enclosed Combustor CC 0 E 6 U E- VOC & HAP Control Efficiency: Th" 55 i N Waste gas heat content: CL Pilot burner rating: o a .0. m c 0 U a) u a) O O U ' V L 0 cn U or control o C a! 0 L 0 C. Make/Model: N Requested VOC & HAP Control Efficiency: 0 > L U U ❑ C no Fo U 0 0 U O C O O E&P Sites On Informatio CC oration Teem Section 08 — Gas/Li What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? Please describe the separation process between the well and the storage tanks: CC C. E CC O r:+ C CC U CC O Ct E W O CC C O CC a 0.1 VS CC y E a) C u LID b➢ u CC 4.c CC CC C 0 0 0 E u 9 u CC 2 L a C. G u CC O CC O CC 0 CC O E Emission Factor Data Source } CDPHE cn V) T [:.1 CI () HYSYS to V) -r- HYSYS HYSYS SASAH Please use the APCD Non -Criteria Re ortable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions LControlled (Tons/Year) (7) 3 \O co G `s' c O O O O M o —{` z' 0 0 0 0 0 0 0 Uncontrolled (TorisGY,ear)---- v 1 0.27 7.50 M O to C, 4 en 4 %O 0 Q1 0 N Actual Calendar Year Emission= Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor Units U U O J 0aoaaaaaa . O O .0 O .0 .0 2 O = .0 = a '0' a Uncontrolled Basis 0.0037 0 co O 0 O 0 O 0 O 0 O o 0.0274 O O a O o o a a co Pollutant xON VOC CO LToluene n -Hexane II CC N N a N vs a-) G U N U _.0 C U _j. 21 T / • L LI H N N L O L C Cj w E r L y U CC L L U C CU C r. a) CC 3 7 CO y • u 0 G C) CC C a Et o• u o C C C 0 •V C 0 .C U C u Ca C y a!) s 3 u .0 C � c E E U c V1 � cw O .- Eo L d C O C 0 a C r' C a c . et as u 0 CJ O r. C h O _ II n eJ ate+ V �> s V T Cb 0 O U C O O •c U u -E I. L V U G L C ar C. a) •C `a-0 L CJ C O V 0 V Air Permittin C) J F. c C 0 CC C a g S CC P. a E Wiz•.= CC L -i z [il CC O U C) O Q C O C) -a' ?i T E o- O az E. LU O a. Q _ Cl O U o O z CC -0 c o N a v �, o 2 >, c o y ty OD o .rte- O O ) ' N C. i -v + 1 5 o E 0 C c G >- 00 _ AP_Fonn-APCD-205-Condensate-Tanks-A P EN.doc 0 N nO for Construction Permit — Condensate Stora AIR POLLUTANT EMISSION NOTICE (APEN) & Applicatio O O • C .O c C rO r r 0 o T T C C O O U U C U 0 o O O O O O Y. O _o ,D X Y U U U U U 0 O R O C C v ;2 R Q y C b U. U U C U O CUJ C C F U T DO 0 AP Fonn-APCD-205-Condensate-Tanks-APEN.doc FORM APCD-205 CC O 11A cs— Emission Source AIRS ID: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] PW Tanks Facility Equipment ID: 0 O u C) CO U O 0 CID Section 01 — Administrative Information z z d 0 0-4 11 Request MODIFICATION to existing INDIVIDUAL permit (check boxes below) ®❑ ❑ Company Name: Colorado River DevCo GP LLC 0 Transfer of ownership ID El N a/ O)/ 0 0 0 0 to U Change permit li ❑ ❑ C) ° '. N 0 vi c Pr) 0 0 0 0 0 U APEN Submittal for Permit Exempt/Grandfathered source APEN Submittal for update only (Please note blank APEN's will not be accepted) ❑ ❑ 0 .. h 4♦ ' O •z ¢a! Section 03 — General Information a Tzzzzz N I❑ND= m ti ti ti ti -8a Ca a ` s ` m N b C) U O a C) 0 0 U 0 0 d CO 0 Normal Hours of Source Operation: 0 R . a) Ca 'S tri co . Ca a 2 a w 0 N w o N C) en C) _ a) a) U •0 0 y a Ca 4. w° 000 z 3 ' a d 4,531 m O El c. ac.�� A 0 0 ... O y� 5 a 03 .b AI b w q a ° o O 'm m CO> . o c° °.N '510 — h = 0 C• U •0 'C ❑ w gU +14 � Q0r0 0 0 U 0o0tai Oy O O o c°) O 0 W g cd e g U 4 023 id Yo 0 O Y C a) U .4 O' A a) U w 00 o. p U Y -0 E]Y U o d: ,b ,b ate`)) o 0 v 0 . 0 O b O b 0 o 0 0 0 o . .'4 4 a h a U v U . 0 . 0 o ff a .0 >, AAAA 1G7 0 d l w° a° 3 L y 0 U 0 CJ CZ 0 0 00 00 V0 t G °c .0., d o 00 Lel wC)L C. C. .--, --+ T' 40. C R - r4 M M CO0 72 C tg, C W c� 0 C - V O, as s T Z CO w O p., o U a) v;) ‘0 sr) 4T) c y 0 C aT b� £ N M M M L "' Q 0 Q N L C ./ -o O O m j U° y R L.L �..M.+� CI �7 a]� °) o Zp O y u 'n w .o as. A Yct 7 b9 •,_.+ PZ U I.., �y 7. x a a.� ' EC, z g o ¢z2 7' w 00 O aJ d d .s. .O. .C O 2 0 U h L .0 0 .•U-, b C .� CZ ; 00 = CA a p a A. •≥ .0 s a a a) Q 'y oA v°' -8 • gip. o .?o c°) .5 U L M O Nt _'7 CO A „., O A L ��yy C C a „, g a L U .� a ti 0 i7 oo R ,"" %- L N 0 Q et ni 5 w R V o o U y d Cl)o 0 0 U E Y w 0 A p i 0`7* . 0 .. ♦O 7 a a •° 0, d O C. a LoCOOgwE,- cc L) d'8 c� ,.. T a, - a = 0 U 0 a a, a, U¢� 0 w4—, u<PA w <� APEN forms: h Application sta Information Ca c F C) Section 04 — Stora 0 0 0 0 U C) U Qi ca .0 p O 0 o © Requested Permit Limit: ❑ External Floating Roof: Internal Floating Roof: Date Of First Production (Month/Year) Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) Newly Reported Well ID ODD Name of Well Installation Date of most recent storage vessel in storage tank (Month/Year) Total Volume of Storage Tank (bbl) © © © # of Liquid Manifold Storage Vessels in Storage Tank 00 II API Number Storage Tank I ID PW Tanks PW Tanks APEN 8.25.2016.doc M 0 7-, 0 00 col c FORM APCD-207 Produced Water Stora AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Emission Source AIRS ID: Permit Number: CO d d O GT a O CO E L O 0 R a O U 6) CI) y C .8 N E) OD 42 a az C0 N¢a, 0 N x •• V 0 E) ,re t� [n o o to w 'U ° O 0 U a A W Section 07 — Control Device Information E&P Sites Onl Information a ration Technolo 0 a Section 08 — Gas/Li 00 Cl, 0O0 N O en 0 rn rn NO en • ti w a O O C O O O U O O O R 0 C L O C O C C O 2 CO O V O (/] .0 R R 0 0 R 0 E w 0 E w Estimation Method or Emission Factor Source 1- State Default Factor I X s -4' d) Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. 1 Requested Permitted Emissions Controlled (Tons/Year) O 14.34 00 C Al Do fe$ • O- Cak 4 f, Uncontrolled (Tons/Year) ., O o ~ O ` }- 1 Cr" S 0 Actual Calendar Year Emission Controlled (Tons/Year) Uncontrolled (Tons/Year) O Emission Factor Units lb/lb VOC am lb/lb VOC 41 .../' Uncontrolled Basis r O O 0 0.262 O O 0 O Q o N 0 O Pollutant xON O CO Benzene Toluene a) w n -Hexane g y a .4 el, L 0 0 L .00 V E L . 0 v L. • CO L L • elO V O V C O V O u s. • c U cc: cs o� V C C O p R V = G = 0 CQ O • cu s s s 3 3 . C ✓ F E E a 0 C u w R E o C y G O CO O .O •C - L C1.0 s '7 R d C. v O L ✓ • 0 e " 0 .R E L .. w = .C F� GC V V s E... • X' © 44 0.. L 0 L — O c O O w d U CO CO 0 O 0 0 V L O d Air Permittin 0 CO 0 R s b O 00 O O 0) H PW Tanks MEN 8.25.2016.doc M O O N E) I FORM APCD-207 U G �a O2 00 a P. 0 a a R R w w O 0 R. E. U U o y 0 cr. cr0 U N U y O O PG X O O .a .O U U N N 1a U U El U 0 El PW Tanks APEN 8.25.2016.doc M O Pr FORM APCD-207 Emission Source AIRS ID: [Leave blank unless APCD has already assigned a permit # & AIRS ID] 16WE1024 Permit Number: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] nested Action (check applicable request boxes) Section 02 — Re Section 01 — Administrative Information Request for NEW permit or newly reported emission source Request MODIFICATION to existing permit (check each box below that applies) Change company name U 0 Transfer of ownership ❑ ❑ Change fuel or equipment Change permit limit CI IS] Request to limit HAPs with a Federally enforceable limit on PTE Request APEN update only (check the box below that applies) C) CL N 00 U O U c N O U v C C O U O a o c c— O ^_ p .r. U E. L o v � c o . � c 0 0 > • 3 L h � C C Z c� a O 0 >- E u c v)-0 0 a) ca t 0 ❑ ❑ Shaun Higgins Person To Contac 303-228-4286 Fax Number: shaun.higgins@nblenergy.com L CD Section 03 — General Information For new or reconstructed sources, the projected startup date is: For existing sources, operation began on: Backup combustion of VRT Separator Vapors during VRU downtime General description of equipment and purpose: C CV C O C W 'C e n CC O U O LO . L - •:O =,,C' o vl a m —' ....1=,\.\ C/'1 • I� LZ.7 U U ,,• dV - M cy1 WI G U ar ea `t . -N''0_ N .n O 0 0 O•' a C) U E _ - -M M M CJ y ^ _ • C -. OOO 0. en rn en m U O L CO 00 > E 99 a c2 . C -o 0�- ao ec) N W. C) y CCD ,fir C.L.1 G 0. j Co 69 L C. Q 7 C U m . 0 ° C cn Q o v,s z — O) 3 ° EGI a o C) -.-_, o a �a0• a= (I) a oC°Lr o U C C7 • CL Cl .� C' O U U • 1:3 6o c c 0� — "wp .O 0 C v 7 O •y CJ '> U CC 1- L N = O Q E n U o V s 'N O OL ^ p L Q U 0 C v 0. o V) y U m '� 'EA E o g a� _ .o .c .D ,O c c� .. L G U C) -2 o..c33. m • o — .2 uO > C0 0. W E. 63 UQ`v Qcn Q o C ❑ z ment Information Section 04 — Processin 5 a c r U 0 v O O G 2 ej S 0 # of events: 00 E C O �C .0 L co I', G U 0 bC , a 0 o U r F O C C 0 0 co U v) a. o _ - U ° G U C co oo c C P O — _ - a 3 .C > m C O O r U G U c 0 0- O' ❑ ® ❑ ❑ ❑ ❑ N N M U imum Vent R en m N N U C) X C —. CJ O N > CO U ,u O U C C U C ' C v 0 0 O O C .Q. C . C C) U 0. L L b 4 0 0 0 0 U U C) > > v v 0 0 0 0 C.) 1 Y U ❑ ❑ C) AP Fonn-APCD-2II-Nato l-Gas-Venting-APEN-VRT.doc `00 k FORM APCD-211 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Natural Gas Ventin w w O) O N a Emission Source Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Section 05 — Stack Information (Combustion stacks must be listed here) 0 v e GoogleEarth M u la. 3U O < Iz "� F U) Other (Describe): Width (inches) = ❑ Horizontal ❑ Down ❑ Other: Length (inches) _ ❑ Vertical with obstructing raincap Inner Diameter (inches) = Direction of stack outlet (check one): ® Vertical Exhaust Opening Shape & Size (check one): ® Cir Section 07 — Control Device Information Section 08 — Emissions Inventory Information & Emission Control Information Estimation Method or Emission Factor Source co ¢va7¢� V G U w W O U AP -42 AP- 42/HYSYS AP- 42/HYSYS A P- 42/HYSYS Cl) 1` ¢ >- < Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Controlled ("Ions/Year) co C .--i 0.79 i X) N O 0.0437 0.0472 a er O O O O 0.32 Uncontrolled (Tons/Year) 217.55 en N co © 0.9444 co a © 0 0.2473 co r so; Actual Calendar Year Emissions' Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor lb/MMSCF Ib/MMSCF en 3 en up 3 en 26 lb/MMSCF lb/MMSCF en Uncontrolled Basis N N O o .y — 448.74 R N en .. .- 0.03 CC' 7 Os 7 535.15 b C sO V) 140.14 3617.40 Control Efficiency (% Reduction) 95 IA O\ 1() O. 11) O. in a in 0 Overall Collection Efficiency O O ..4 O O .y O O — O O ..y O O v l O O I--i Control Device Description Secondary F CD CD CD CD V U Pollutant VOC xON 0 U 0 N Toulene N N CU 9 CO y X n -Hexane M O N CJ CO a FLI n and requires re -submittal. 'C a) C) C) QI O N N N O C) Cn a 0 E 0 z Signature of Person Legally Authorized to Supply Data AP_Fonn-APCD-2 FORM APCD-211 2 z W w U I- 0 Z Z O -, E O E W H 0 Z E QO U O J C J a O p m ao Q T w�, m°' Ct 0 a NW Iii 0 16WE1024 Permit Number: Green River DevCo LP Company Name: m O U a N NW S22 T2N R64W Plant Location: shaun.higgins@nblenergy.com E-mail Address: Controlled Actual Emissions Ibs/ ear c c a) Uncontrolled Actual Emissions Ibs/ ear 1596.56 Emission Factor Source HYSYS Emission Factor (Include Units) 452.36 lb/MMSCF Control Equipment / Reduction (%) LU 0) Chemical Name w m C a) Q >, E I- 4 N N Chemical Abstract Service (CAS) Number r co 6 .:3 - Lo w H 11 Calendar Year fo N- O N CO N 7 co 0 O Q C) O U) N •L O 7.7„ CC) O) C) J C O (,./2 0 O a) L Co r/ ) v / Air Permitting Supervisor Shaun Higgins Title of Person Legally Authorized to Supply Data Name of Person Legally Authorized to Supply Data (Please print) ril 14. 2014 Form Revision Da Hello