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Home My WebLink About20141563.tiff STATE OF COLORADO John W.Hickenlooper,Governor of cod Larry Wolk,MD,MSPH Executive Director and Chief Medical Officer Dedicated to protecting and improving the health and environment of the people of Colorado t � + 4300 Cherry Creek Dr.S. Laboratory Services Division Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.gov/cdphe and Environment Weld County-Clerk to the Board 1150 O St PO Box 758 Greeley, CO 80632 RECEIVED May 19, 2014 MAY 2 3 2014 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On May 22,2014,the Air Pollution Control Division will publish a public notice for Noble Energy, Inc— Wolfpack& Lone Wolf Econode, in the The Greeley-Tribune. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty(30) days from the date the public notice is published. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health& Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards,04,44, Giljd244) Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 'PU DLkCT 2 Uie„) (`G', IPL(MAA) +LL?&&PW('c -,CH, 3tA) 2014-1563 la- Z" ly 5 -nr1�I STATE OF COLORADO John W.Hickenlooper,Governor Larry Wolk, MD,MSPH Eot cotgp Executive Director and Chief Medical Officer Ne744O7o Dedicated to protecting and improving the health and environment of the people of Colorado ' c P 9 P Pr�"i�.4N, t ,.. • 4300 Cherry Creek Dr.S. Laboratory Services Division *187E, Denver,Colorado 80246.1530 8100 Lowry Blvd.Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.govlcdphe and Environment Website Title: Noble Energy, Inc—Wolfpack& Lone Wolf Econode—Weld County Released To: The Greeley Tribune On: May 19, 2014 Published: May 22, 2014 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Noble Energy, Inc Facility: Wolfpack& Lone Wolf Econode Oil and gas wellhead facility SWSW Section 2, T5N, R64W Weld County The proposed project or activity is as follows: Oil and gas wellhead facility including three reciprocating internal combustion engines, fugitive emissions, produced water tanks, truck loadout, wellhead flare and condensate tanks. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section IILC due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part 13, Section 1ll.C.l.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 14WE0638 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at www.colorado.gov/cdphe/AirPublicNotices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Stephanie Chaousy Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South,APCD-SS-B I Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us STATE OF COLORADO aF „O COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT �� AIR POLLUTION CONTROL DIVISION * * TELEPHONE: (303) 692-3150 -OK *1876* CONSTRUCTION PERMIT PERMIT NO: 14WE0638 Issuance 1 DATE ISSUED: ISSUED TO: Noble Energy, Inc. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Wolfpack & Lone Wolf Econode, located in SWSW Section 2, Township 5N, Range 64W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point One (1) GM, Model 5.7L, Serial Number 1M06067AH, natural gas-fired, naturally aspirated, 4SRB reciprocating VRUComp1 001 internal combustion engine, site rated at 88 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. One (1) Caterpillar, Model G3306NA, Serial Number G6X03975, natural gas-fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 145 VRUComp2 002 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. One (1) Caterpillar, Model G3306NA, Serial Number G6X04068, natural gas-fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 145 VRUComp3 003 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. Fugitives 004 Fugitive emission leaks. AIRS ID: 123/9C9F Page 1 of 24 NGEngine Version 2014-1 Col do p e o Public PollutionHealthand Control DivisionEnvironment Facility AIRS Description Equipment ID Point Six (6) above ground 500 bbl atmospheric produced water PW 005 storage tanks. Emissions from these tanks are controlled by an enclosed flare. TLO 006 Truck loadout of condensate. Flare 007 Separator controlled by a flare stack. Flare has a minimum combustion efficiency of 95%. The flare is not enclosed. Twelve (12) above ground 500 bbl atmospheric crude oil Condensate 008 storage tanks. Emissions from these tanks are controlled by tanks a vapor combustor with a minimum destruction efficiency of 95%. One (1) Caterpillar, Model 3516B, Serial Number JEF02471, natural gas-fired, naturally aspirated, 4SLB reciprocating Sales Comp 1 009 internal combustion engine, site rated at 1380 horsepower. This engine shall be equipped with an oxidation catalyst and air-fuel ratio control. This emission unit is used for natural gas compression. Points 001, 002, 003 and 009: These engines may be replaced with another engine in accordance with the temporary engine replacement provision or with another GM 5.7L, Caterpillar G3306NA or Caterpillar Model 3516B engines in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.cdphe.state.co.us/apldownloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) after issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, 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 AIRS ID: 123/9C9F Page 2 of 24 • Col' t do p e o Public Health and Environment Air Pollution Control Division of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, Ill.F.4.) 4. Points 001, 002, 003, 009: The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. Points 001, 002, 003, 009: The following information shall be provided to the Division within fifteen (15) days after issuance of permit. • construction date • order date • date of relocation into Colorado This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, III.E.) 6. The operator shall retain the permit final authorization letter issued by the Division after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Emission Type Equipment ID Point NO VOC CO z VRUComp1 001 0.8 0.6 1.7 Point VRUComp2 002 1.4 0.5 2.8 Point VRUComp3 003 1.4 0.5 2.8 Point Fugitives 004 --- 66.9 --- Fugitive PW 005 3.0 Point TLO 006 5.8 Point Flare 007 10.0 62.3 54.0 Point Condensate 008 15.4 Point tanks Sales Comp 1 009 13.3 5.6 13.3 Point See "Notes to Permit Holder"for information on emission factors and methods used to calculate limits. AIRS ID: 123/9C9F Page 3 of 24 Co door) e o Pu Airblic PollutionHealthand Control DivisionEnvironment Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 8. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility emission limitations as seen 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 Pollutant Emission Notice (APEN). Total emissions from the facility, including permitted emissions and insignificant activities, shall not exceed: • 100 tons per year of any criteria pollutant and/or 9. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) Facility AIRS Pollutants Equipment Point Control Device Controlled ID VRUComp1 001 NSCR and AFRC VOC, NOx and CO VRUComp2 002 NSCR and AFRC NOx and CO VRUComp3 003 NSCR and AFRC NOx and CO PW 005 Enclosed flare VOC TLO 006 Enclosed flare VOC Flare 007 Flare VOC Condensate 008 Vapor combustor VOC tanks Sales Comp 009 SCR Catalyst and AFRC VOC and CO 1 AIRS ID: 123/9C9F Page 4 of 24 nr+%t IIYI = Col . do itp rrme o" Public Health and Environment Air Pollution Control Division 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 rate shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Equipment Point Process Parameter Annual Limit ID VRUComp1 001 Consumption of natural gas as a fuel 5.64 MMscf/yr VRUComp2 002 Consumption of natural gas as a fuel 8.02 MMscf/yr VRUComp3 003 Consumption of natural gas as a fuel 8.02 MMscf/yr PW 005 Produced water throughput 450,000 BBL per year TLO 006 Condensate Loading 800,000 BBL per year condensate loaded Flare 007 Natural gas flaring 237 MMscf/yr Condensate 008 Condensate throughput 800,000 BBL per year tanks Sales Comp 009 Consumption of natural gas as a fuel 80.63 MMscf/yr 1 The owner or operator shall calculate monthly process rates based on the calendar month. 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. Records shall be kept in either an electronic file or hard copy provided that they can be promptly supplied to the Division upon request. All records shall be retained for a consecutive period of five years. STATE AND FEDERAL REGULATORY REQUIREMENTS 12. The permit number and AIRS ID point number(e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 13. Visible emissions shall not exceed twenty percent(20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) AIRS ID: 123/9C9F Page 5 of 24 Co do p e o Pu D Airblic PollutionHealthand Control DivisionEnvironment 14. No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.5.) 15. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 16. Points 001, 002 and 003: This equipment is subject to the control requirements for natural gas-fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas-fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Maximum' Engine Construction or Emission Standard in g/hp-hr HP Relocation Date NOx CO VOC <100HP Any N/A N/A N/A z100HP and January 1, 2008 2.0 4.0 1.0 <500HP January 1, 2011 1.0 2.0 0.7 z500HP July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 ' Maximum engine horsepower is the nameplate rating of the engine and does not account for deration. 17. Point 004: This source is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum I extent practicable. The operator shall comply with all applicable requirements of Section XII. 18. Point 004: Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). This requirement to apply RACT shall be satisfied by installing/implementing the following emission controls: a. Directed Inspection & Maintenance as described below shall satisfy the requirement to apply RACT. i. Auditory/visual/olfactory inspection (AVO) will be performed on a quarterly basis. ii. For each leak found in the AVO inspection, a gas detector shall be used to determine the size of the leak. The gas detector shall be AIRS ID: 123/9C9F Page 6 of 24 Cole ' do I• p: e or Public Health and Environment Air Pollution Control Division regularly calibrated. Component leaks greater than 10,000 ppm shall be managed in accordance with Item (vi) below, unless it is unfeasible to make the repair without shutting down the affected operation of the facility. For such component leaks that require a shutdown to be repaired, repair shall occur during the first shutdown of the affected operation after the leak is discovered. iii. For repair, valves adjacent to the equipment to be repaired will be closed if practicable, minimizing the volume released. iv. Repaired components shall be re-screened using portable analyzer to determine if the leak is repaired. Leak shall be considered repaired when 10,000 ppm is registered when tested. v. The following records shall be maintained for a period of two years: • The name of the site screened via AVO inspection and the name of the inspector. • Components evaluated with the gas detector. • Repair methods applied. • Dates of the AVO inspections, gas detector calibrations, attempted repairs, successful repairs, repair delays, and post- repair screenings. vi. Leaks shall be repaired as soon as practicable, but no later than 15 calendar days after detection, unless it is technically or operationally infeasible to make the repair within 15 calendar days. Records documenting the rationale shall be maintained if it is technically or operationally infeasible to make the repair within 15 calendar days. 19. Point 006: This source is located in an ozone non-attainment or attainment- maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 20. Point 006: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations onsite at the time of inspections to monitor compliance with Condition 20 (a) and (b) above. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. AIRS ID: 123/9C9F Page 7 of 24 Col do 1 e o Public Health and Environment Air Pollution Control Division 21. Point 006: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 22. Point 008: The flare covered by this permit is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). If a combustion device is used to control emissions of volatile organic compounds to comply with Section XII.D, it shall 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. The operator shall comply with all applicable requirements of Section XII. 23. Point 008: This source is subject to the recordkeeping, monitoring, reporting and emission control requirements of Regulation 7, Section XII. The operator shall comply with all applicable requirements of Section XII. 24. Point 008: The flare covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XVII. 25. Point 008: The condensate storage tanks covered by this permit are subject to Regulation 7, Section XVII emission control requirements. These requirements include, but are not limited to: Section XVII.C. - Emission reduction from condensate storage tanks at oil and gas exploration and production operations, natural gas compressor stations, natural gas drip stations and natural gas processing plants. XVII.C.1. Beginning May 1, 2008, owners or operators of all atmospheric condensate storage tanks with uncontrolled actual emissions of volatile organic compounds equal to or greater than 20 tons per year based on a rolling twelve-month total shall operate air pollution control equipment that has an average control efficiency of at least 95%for VOCs on such tanks. XVII.C.3. Monitoring: The owner or operator of any condensate storage tank that is required to control volatile organic compound emissions pursuant to this section XVII.C. shall visually inspect or monitor the Air Pollution Control Equipment to ensure that it is operating at least as often as condensate is loaded out from the tank, unless a more frequent inspection or monitoring schedule is followed. In addition, if a flare or other combustion device is used, the owner or operator shall visually inspect the device for visible emissions at least as often as condensate is loaded out from the tank. XVII.C.4. Recordkeeping: The owner or operator of each condensate storage tank shall maintain the following records for a period of five years: XVII.C.4.a. Monthly condensate production from the tank. XVII.C.4.b For any condensate storage tank required to be controlled pursuant to this section XVII.C., the date, time and duration of any AIRS ID: 123/9C9F Page 8 of 24 Col do •.=pvrt el o Public Health and Environment Air Pollution Control Division • period where the air pollution control equipment is not operating. The duration of a period of non-operation shall be from the time that the air pollution control equipment was last observed to be operating until the time the equipment recommences operation. XVII.C.4,c. For tanks where a flare or other combustion device is being used, the date and time of any instances where visible emissions are observed from the device. OPERATING & MAINTENANCE REQUIREMENTS 26. Points 001, 002, 003, 005, 006, 007, 008 and 009: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 27. Points 001, 002, 003 and 009: A source initial compliance test shall be conducted on emissions points 001, 002, 003 and 009 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emission limits in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. 28. Point 004: Within one hundred and eighty days (180) after issuance of permit, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. 29. Point 007: The owner or operator shall demonstrate compliance with Condition 14 using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section II.A.5). Periodic Testing Requirements 30. Points 001, 002, 003 and 009: 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. AIRS ID: 123/9C9F Page 9 of 24 Col do p e o PubD lic PollutionHealthand Control DivisionEnvironment Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. 31. Point 004: On an annual basis, the owner or operator shall complete an extended gas analysis of gas that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. 32. Point 007: On an annual basis, the operator shall complete a site specific extended gas analysis of the natural gas produced at this site that is routed to the flare in order to verify the VOC content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. ADDITIONAL REQUIREMENTS 33. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO,,) in ozone nonattainment areas emitting less than 100 tons of VOC or NO. per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Points 001, 002, 003 and 009: Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover AIRS ID: 123/9C9F Page 10 of 24 Col ido D p> tne OT Public Health and Environment Air Pollution Control Division letter explaining that the owner or operator is exercising an alternative-operating scenario and is installing a permanent replacement engine. 34. 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: 35. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 36. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 37. 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. 38. 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. 39. 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. 40. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the AIRS ID: 123/9C9F Page 11 of 24 Col do p e o Public Health ti and Control nment II Air Pollution Control Division Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 41. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Stephanie Chaousy, PE Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Noble Energy, Inc. Newly permitted wellhead site with four RICE, fugitive emissions, produced water tanks, truck loadout, wellhead flare and condensate tanks. Facility is synthetic minor. AIRS ID: 123/9C9F Page 12 of 24 .rte Cola ` do ; p me o Public Health and Environment Air Pollution Control Division Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: http:l/www.colorado.govlcs/Satellite?c=Document C&childpagename=CDPHE- Main%2FDocument C%2FCBONAddLinkView&cid=1 2 51 599389641&pagename=CBONWrapper 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Are the Controlled AIRS Pollutant CAS # BIN Emission emissions Emission Point Rate reportable? Rate (Ib/yr) (Ib/yr) Formaldehyde 50000 A 142 No 142 Methanol 67561 C 21 No 21 Acetaldehyde 75070 A 19 No 19 001 Acrolein 107028 A 18 No 18 Benzene 71432 A 11 No 11 1,3-Butadiene 106990 A 5 No 5 Toluene 108883 C 4 No 4 Formaldehyde 50000 A 202 No 202 Methanol 67561 C 30 No 30 002 Acetaldehyde 75070 A 28 No 28 and Acrolein 107028 A 26 No 26 003 each Benzene 71432 A 16 No 16 1,3-Butadiene 106990 A 7 No 7 Toluene 108883 C 6 No 6 Benzene 71432 A 849 Yes 849 004 Toluene 108883 C 2718 Yes 2718 Ethylbenzene 100414 C 187 No 187 AIRS ID: 123/9C9F Page 13 of 24 Ill Col do p e o Public Health and Environment Air Pollution Control Division Xylenes 1130207 C 2964 Yes 2964 n-Hexane 110543 C 5757 Yes 5757 Benzene 71432 A 3150 Yes 158 005 n-Hexane 110543 C 9900 Yes 495 Benzene 71432 A 2400 Yes 120 Toluene 108883 C 7200 Yes 360 Ethylbenzene 100414 C 800 Yes 40 006 Xylenes 1130207 C 8000 Yes 400 n-Hexane 110543 C 14400 Yes 720 2,2,4- 540841 C 1600 Yes 80 Trimethylpentane Benzene 71432 A 5694 Yes 285 Toluene 108883 C 3559 Yes 178 007 Ethylbenzene 100414 C 479 Yes 24 n-Hexane 110543 C 23488 Yes 1174 Benzene 71432 A 2160 Yes 108 008 n-Hexane 110543 C 19200 Yes 960 Formaldehyde 50000 A 9,594 Yes 2,665 Acetaldehyde 75070 A 830 Yes 830 Acrolein 107028 A 510 Yes 510 009 Methanol 67561 C 248 No 248 n-Hexane 110543 C 110 No 110 Benzene 71432 A 44 No 44 Toluene 108883 C 40 No 40 5) The emission levels contained in this permit are based on the following emission factors: Point 001: Emission Factors- Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu glbhp-hr NOx 1.4501 5.92 0.2450 1.00 CO 7.9366 32.40 0.4899 2.00 VOC 0.3503 1.43 0.1715 0.70 50000 Formaldehyde 0.0205 0.08 0.0205 0.08 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 107028 Acrolein 0.0026 0.01 0.0026 0.01 71432 Benzene 0.0016 0.01 0.0016 0.01 106990 1,3-Butadiene 0.0007 0.00 0.0007 0.00 108883 Toluene 0.0006 0.00 0.0006 0.00 AIRS ID: 123/9C9F Page 14 of 24 Col do p e o Public Health and Environment Air Pollution Control Division Emission factors are based on a Brake-Specific Fuel Consumption Factor of 9000 Btu/hp-hr, a site-rated horsepower value of 88, and a fuel heat value of 1231 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde AP-42 AP-42 Points 002 and 003: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.0907 10.90 0.2836 1.00 CO 3.7145 13.10 0.5671 2.00 VOC 0.0936 0.33 0.0936 0.33 50000 Formaldehyde 0.0205 0.07 0.0205 0.07 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 107028 Acrolein 0.0026 0.01 0.0026 0.01 71432 Benzene 0.0016 0.01 0.0016 0.01 106990 1,3-Butadiene 0.0007 0.00 0.0007 0.00 108883 Toluene 0.0006 0.00 0.0006 0.00 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 7775 Btu/hp-hr, a site-rated horsepower value of 145, and a fuel heat value of 1231 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde AP-42 AP-42 Point 004: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 4345 294 1067 633 Flanges 566 --- 168 28 Open-Ended Lines --- --- --- --- Pump Seals --- 2 --- Valves 1665 98 954 230 Other 574 --- 73 77 VOC Content(wt%) 18.6% 100% 100% 100% i Benzene Content(wt%) 0.042% 0.87% 0.87% 0.87% Toluene Content(wt%) 0.026% 3.14% 3.14% 3.14% Ethylbenzene (wt %) 0.004% 0.21% 0.21% 0.21% Xylenes Content(wt%) 0.001% 3.505% 3.505% 3.505% n-hexane Content(wt%) 0.175% 6.27% 6.27% 6.27% `Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents AIRS ID: 123/9C9F Page 15 of 24 Co do Dfpart e o Public Health and Environment CAir Pollution Control Division TOC Emission Factors (kg/hr-component): Component Gas Service Heavy Oil Light Oil ervi S Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas analysis. Point 005: Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source lb/BBL Produced lb/BBL Produced Water Throughput Water Throughput VOC 0.262 0.0131 PS Memo 09-02 110543 n-Hexane 0.022 0.0011 PS Memo 09-02 71432 Benzene 0.007 0.0004 PS Memo 09-02 Note: The controlled emissions factors for point 005 are based on the enclosed flare control efficiency of 95%. Point 006: Emission Factors - Emission Factors - Uncontrolled Controlled CAS Pollutant lb/1000 gal Source Wt% lb/1000 gal Source loaded loaded VOC 6.93 AP-42 --- 0.3465 AP-42 Benzene 0.0714 Compositional 0.9 0.0036 Compositional 71432 Wt% Wt Toluene 0.2143 Compositional 3.1 0.0107 Compositional 108883 Wt% Wt 100414 Ethylbenzene 0.0238 Compositional 0.2 0.0012 Compositional Wt /a Wt /o Xylenes 0.2381 Compositional 3.5 0.0119 Compositional 1330207 Wt /o Wt% n-hexane 0.4256 Compositional 6.3 0.0213 Compositional 110543 Wt% Wt 2,2,4- 0.0476 Compositional 0.6 0.0024 Compositional 54O841 Trimethylpentane Wt% Wt% The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 7.88 psia AIRS ID: 123/9C9F Page 16 of 24 Col do p.time-� o Public Health and Environment i Air Pollution Control Division M (vapor molecular weight) = 60 Ib/Ib-mol T (temperature of liquid loaded) = 510 °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. Controlled emission factors are based on a flare efficiency of 95%. Point 007: Weight Emission Emission CAS # Pollutant Fraction of Factors Factors Source Gas (%) Uncontrolled Controlled NOx 0.068 0.068 AP-42 lb/MMBtu lb/MMBtu CO 0.37 AP-42 0.37 lb/MMBtu lb/MMBtu VOC 18.6 10492.0152 524.6008 Engineering lb/MMscf lb/mmscf Calculation 71432 Benzene 0.042 23.9810 1.1991 Engineering lb/MMscf lb/mmscf Calculation 108883 Toluene 0.026 14.9886 0.7494 Engineering lb/MMscf lb/mmscf Calculation 100414 Ethylbenzene 0.004 2.0 lb/MMscf 0.1 lb/mmscf Engineering Calculation 110543 n-hexane 0.175 98.9240 4.9462 Engineering lb/MMscf lb/mmscf Calculation Note: The uncontrolled VOC and HAP emissions for this point were calculated using the January 20, 2014 analysis of a gas sample collected from the Lonewolf/Wolfpack Econode (meterl). The controlled VOC and HAP emissions factors for point 007 are based on the flare control efficiency of 95%. Point 008: Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source VOC 18.3333 lb/1000 0.9167 lb/1000 gal EPA Tanks and inSim Benzene 0.0643 lb/1000 gal 0.0032 lb/1000 gal EPA Tanks and 71432 WinSim n-hexane 0.5714 lb/1000 gal 0.0286 lb/1000 gal EPA Tanks and 110543 WinSim Note: The controlled emissions factors for point 008 are based on the vapor combustor control efficiency of 95%. These emission factors were developed using an average of four pressurized liquids analysis from the Lonewolf B02-65HC, Wolfpack B-20-65-1HN, Wolfpack B-2-65HN and Wolfpack B-02-66-1 HN wells. Point 009: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 0.2685 1.00 0.2685 1.00 CO 0.8377 3.12 0.2685 1.00 AIRS ID: 123/9C9F Page 17 of 24 •D Col do p e o Public PollutionHealthand Control DivisionEnvironment Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant Ib/MMBtu g/bhp-hr Ib/MMBtu g/bhp-hr VOC 0.3759 1.40 0.1128 0.42 50000 Formaldehyde 0.0967 0.36 0.0268 0.10 75070 Acetaldehyde 0.0084 0.03 0.0084 0.03 107028 Acrolein 0.0051 0.02 0.0051 0.02 67561 Methanol 0.0025 0.01 0.0025 0.01 110543 n-Hexane 0.0011 0.00 0.0011 0.00 71432 Benzene 0.0004 0.00 0.0004 0.00 108883 Toluene 0.0004 0.00 0.0004 0.00 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8211 Btu/hp-hr, a site-rated horsepower value of 1380, and a fuel heat value of 1231 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde Manufacturer Manufacturer 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 001, 002, 003 and 009: 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 < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.eoa.gov/ttn/atw/area/arearules.html 8) Point 009: This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting —effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.eoa.gov/ttn/atw/area/fr18ia08.pdf 9) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: NOx, CO, VOC, n-hexane, 2,2,4-TMP, total HAPS NANSR Synthetic Minor Source of: CO,VOC MACT ZZZZ Area Source Requirements: Applicable AIRS ID: 123/9C9F Page 18 of 24 gym _ Col do • p,.rtme or Public Health and Environment .j Air Pollution Control Division • 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN —Subpart XXXXXX 11) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: www.coloradomov/cdphefoilqawermits AIRS ID: 123/9C9F Page 19 of 24 Col do p e o Public PollutionHealthand Control DivisionEnvironment ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2.Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit(including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five(5)years and made available to the Division upon request. The owner or operator shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9C9F Page 20 of 24 Col` `do p rtme of Public Health and Environment Air Pollution Control Division 2.1.2 The owner or operator may permanently replace the existing compressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: http://www.colorado.qov/cs/Satellite/C DP H E-AP/CBO N/1251596520270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. AIRS ID: 123/9C9F Page 21 of 24 Col do p e o Pu Environment Airblic PollutionHealthand Control Division For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B§ II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and 8O2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ 6O2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§60.331) and 40 CFR Part 72 (§72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/9C9F Page 22 of 24 Coll, do • .4 " er of Public Health and Environment Air Pollution Control Division The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII.E—State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500≤Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § 1.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 AIRS ID: 123/9C9F Page 23 of 24 Col do p e o Public 1) 1M_ Air PollutionHealthand Control DivisionEnvironment requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9C9F Page 24 of 24 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Noble Energy, Inc. Permit Number: 14WE0638 Source Location: Wolfpack& Lone Wolf Econode SWSW Section 2,T5N, R64W,Weld County (non-attainment) Point 001: RICE Point 002: RICE Point 003: RICE Point 004: Fugitive emissions Point 005: (6) 500 BBL above ground atmospheric produced water Equipment Description: storage tank. Point 006: Condensate truck loadout Point 007: Plant flare with a minimum combustion efficiency of 95%. Point 008: (12) 500 BBL above ground atmospheric condensate storage tanks Point 009: RICE AIRS ID: 123-9C9F Date: May 2, 2014 Review Engineer: Stephanie Chaousy, PE Control Engineer Chris Laplante Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? Yes X No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered"no" to any of the above, when did you mail an See Section 14 for email Information Request letter to the source? conversations January 29, 2014; I received APEN On what date was this application complete? for Point 009 via email 5/12/14 Section 4—Source Description AIRS Point Equipment Description Page 1 One (1) GM, Model 5.7L, Serial Number 1M06067AH, natural gas-fired, naturally 001 aspirated, 4SRB reciprocating internal combustion engine, site rated at 88 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. One(1) Caterpillar, Model G3306NA, Serial Number G6X03975, natural gas-fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 145 002 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. One (1) Caterpillar, Model G3306NA, Serial Number G6X04068, natural gas-fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 145 003 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. 004 Fugitive emission leaks. 005 Six (6) above ground 500 bbl atmospheric produced water storage tanks. Emissions from these tanks are controlled by an enclosed flare. 006 Truck loadout of condensate. 007 Separator controlled by a flare stack. Flare has a minimum combustion efficiency of 95%. The flare is not enclosed. Twelve(12) above ground 500 bbl atmospheric crude oil storage tanks. Emissions from 008 these tanks are controlled by a vapor combustor with a minimum destruction efficiency of 95%. One (1) Caterpillar, Model 3516B, Serial Number JEF02471, natural gas-fired, naturally 009 aspirated, 4SLB reciprocating internal combustion engine, site rated at 1380 horsepower. This engine shall be equipped with an oxidation catalyst and air-fuel ratio control. This emission unit is used for natural gas compression. Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria X Yes No pollutant? If"yes", for what pollutant? PM10 CO X Ozone Is this location in an attainment maintenance area for Yes No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source PM1O CO Ozone RACT per Regulation 3, Part B,Section III.D.2) Is this source located in the 8-hour ozone non- attainment region?(Note: If"yes" the provisions of X Yes No Regulation 7, Sections XII and XVII.C may apply) Point 005: Is this source claiming exempt status for this source based on the fraction of oil in the stored X Yes No water(less than 1% by volume crude oil on an average annual basis)? Point 005: Are these produced water tanks located at a commercial facility that accepts oil production Yes X No wastewater for processing? Point 005: Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission Yes X No (COGCC) 805 Rule? Point 006: Is this source located at an oil and gas X Yes No exploration site? Page 2 Point 006: If yes, does this source load less than 10,000 gallons of crude oil per day on an annual average, splash fill less than 6750 bbl of condensate Yes X No (hydrocarbons that have an API gravity of 40 degrees or greater) per year or submerged fill less than 16,308 bbl of condensate per year? Point 006: Is this source located at a facility that is considered a major source of hazardous air pollutant Yes X No (HAP) emissions? Point 006: Will this equipment be operated in any X Yes No NAAQS nonattainment area? Point 006: Does this source load gasoline into Yes X No transport vehicles? Section 5—Emission Estimate Information AIRS Point Emission Factor Source 001 Manufacturer: NOx, VOC and CO AP-42 for HAPS 002 Manufacturer: NOx, VOC and CO AP-42 for HAPS 003 Manufacturer: NOx,VOC and CO AP-42 for HAPS 004 EPA-453/R-95-017, Table 2-4 005 CDPHE Emission Factors (PS Memo 09-02) AP-42: Chapter 5.2, Equation 1 L= 12.46*S*P*M/T 006 L= loading losses in lb per 1000 gallons loaded S = Saturation Factor P =true vapor pressure of liquid loaded [psia] NI = molecular weight of vapors [lb/lb-mole] T= temperature of bulk liquid loaded [deg. R] 007 Site-specific using VOC weight fraction (Refer to Section 14 for calculations) 008 Site-specific using EPA Tanks (working and breathing) and WinSim (flashing). (Refer to Section 14 for calculations) 009 Manufacturer NOx, VOC, CO and formaldehyde AP-42 for rest of HAPS Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/Throughput/Production 001 5.64 MMSCF/year 002 8.02 MMSCF/year 003 8.02 MMSCF/year Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 4345 294 1067 633 004 Flanges 566 --- 168 28 Open-Ended Lines --- --- --- Pump Seals --- --- 2 Valves 1665 98 954 230 Other 574 --- 73 77 005 540,000 BBL per year(450,000 x 1.2) Page 3 006 800,000 BBL per year condensate loaded 007 263 mmscf/yr 008 960,000 BBL per year(800,000 x 1.2) 009 80.6 MMSCF/yr Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventorvi AIRS Point Process Consumption/Throughput/Production Data Year 001 5.64 MMSCF/year 2014 002 8.02 MMSCF/year 2014 003 8.02 MMSCF/year 2014 Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy (or Light Liquid) Liquid) Connectors 4345 294 1067 633 004 Flanges 566 --- 168 28 - 2014 Open-Ended --- Lines Pump Seals --- --- 2 --- Valves 1665 98 954 230 Other 574 --- 73 77 005 450,000 BBL per year 2014 006 800,000 BBL per year condensate loaded 2014 007 263 mmscf/yr 2014 008 800,000 BBL per year 2014 009 80.6 MMSCF/yr Basis for Permitted Emissions(Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 5.64 MMSCF/year 002 8.02 MMSCF/year 003 8.02 MMSCF/year Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 4345 294 1067 633 004 Flanges 566 --- 168 28 Open-Ended Lines --- --- --- --- Pump Seals --- --- ' 2 --- Valves 1665 98 954 230 Other 574 --- 73 77 005 450,000 BBL per year 006 800,000 BBL per year condensate loaded 007 263 mmscf/yr 008 800,000 BBL per year 009 80.6 MMSCF/yr Does this facility use control devices? X Yes No AIRS Point Process Control Device Description % Reduction Granted Page 4 001 of NSCR and AFRC NOx:%; %; VOC: 51 /o; CO: 93.8% NOx: 002 01 NSCR and AFRC 90.8%; CO: 84.7%/o NOx: 90.8%; CO: 003 01 NSCR and AFRC 84.7% 005 al Enclosed flare 95 006 of Enclosed flare 95 007 01 Flare 95 008 01 Vapor combustor 95 VOC: 70%; CO: 68%; 009 01 SCR catalyst and AFRC formaldehyde: 72% Section 6—Emission Summary (tons per year) Point NO, VOC CO SOx PM10 Single HAP Total HAP 001 5.0 1.2 27.5 --- --- 0.07 0.1 (formaldehyde) 0.1 002 15.3 0.5 18.3 --- --- (formaldehyde) 0.1 0.1 003 15.3 0.5 18.3 --- --- (formaldehyde) 0.1 004 --- 66.9 --- --- --- 2.9 (n-hexane) 6.2 PTE: 005 --- 70.7 --- --- --- 5.9 (n-hexane) 7.8 006 --- 116.4 --- --- --- 7.2 (n-hexane) 17.2 007 10.0 1245.6 54.0 --- --- 13.0 (n- 18.5 hexane) 008 --- 369.6 --- ___ --- 11.5 12.8 (n-hexane) 4.8 009 13.3 18.7 41.6 --- --- (formaldehyde) 5.5 001 5.0 1.2 27.5 --- --- 0.07 0.1 (formaldehyde) 0.1 002 15.3 0.5 18.3 --- (formaldehyde) 0.1 0.1 003 15.3 0.5 18.3 --- -- (formaldehyde) 0.1 Uncontrolled point 004 --- 66.9 --- --- --- 2.9 (n-hexane) 6.2 source emission rate: 005 --- 59.0 --- --- --- 5.0 (n-hexane) 6.5 006 --- 116.4 --- --- --- 7.2 (n-hexane) 17.2 007 10.0 1245.6 54.0 --- --- 13.0 (n- 18.5 hexane) 008 --- 308 --- --- --- 9.6 (n-hexane) 10.7 4.8 009 13.3 18.7 41.6 --- "' (formaldehyde) 5.5 TOTAL(TPY) 58.9 1816.8 159.7 --- --- 37.7 (n- 64.9 hexane) 001 0.9 0.6 1.7 --- --- 0.07 0.1 (formaldehyde) Controlled point 002 1.4 0.5 2.8 --- --- 0.1 0.1 source emission rate: (formaldehyde) 0.1 003 1.4 0.5 2.8 --- "' (formaldehyde) 0.1 Page 5 004 --- 66.9^ --- --- --- 2.9 (n-hexane) 6.2 005 --- 3.0 0.3 (n-hexane) 0.3 006 --- 5.8 --- --- --- 0.4 (n-hexane) 0.9 007 10.0 62.3 54.0 --- --- 0.7 (n-hexane) 0.9 008 --- 15.4 --- --- --- 0.5 (n-hexane) 0.5 1.3 009 13.3 5.6 13.3 -- (formaldehyde) 2.0 INSIGNIFICANTS 3.1 .9 (TPY) --- --- --- TOTAL PERMITTED 27.0 93.7 74.6 --- --- 1.9 (n-hexane) 4.9 (TPY) ^ Fugitives are not included when calculating status of facility Section 7—Non-Criteria/Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS# BIN Emission Rate emissions (Iblyr) reportable? Rate(lb/yr) Point 001 Formaldehyde 50000 A 142 No 142 Acetaldehyde 75070 A 19 No 19 Acrolein 107028 A 18 No 18 Benzene 71432 A 11 No 11 Points 002 and 003 each Formaldehyde 50000 A 202 No 202 Acetaldehyde 75070 A 28 No 28 Acrolein 107028 A 26 No 26 Benzene 71432 A 16 No 16 Point 004 Benzene 71432 A 849 Yes 849 Toluene 108883 C 2718 Yes 2718 Ethylbenzene 100414 C 187 No 187 Xylenes 1130207 C 2964 Yes 2964 n-Hexane 110543 C 5757 Yes 5757 Point 005 Benzene 71432 A 3150 Yes 158 n-Hexane 110543 C 9900 Yes 495 Point 006 Benzene 71432 A 2400 Yes 120 Toluene 108883 C 7200 Yes 360 Ethylbenzene 100414 C 800 Yes • 40 Xylenes 1130207 C 8000 Yes 400 n-Hexane 110543 C 14400 Yes 720 Page 6 2,2,4-Trimethylpentane 540841 C 1600 Yes 80 Point 007 Benzene 71432 A 5694 Yes 285 Toluene 108883 C 3559 Yes 178 Ethylbenzene 100414 C 479 Yes 24 n-Hexane 110543 C 23488 Yes 1174 Point 008 Benzene 71432 A 2160 Yes 108 n-Hexane 110543 C 19200 Yes 960 Point 009 Formaldehyde 50000 A 9594 Yes 2665 Acetaldehyde 75070 A 830 Yes 830 Acrolein 107028 A 510 Yes 510 Benzene 71432 A 44 No 44 Note: Regulation 3, Part A, Section ll.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory X Yes No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 001 01 NOx, CO Regulation No. 3, Part B., Section III.G.3 Stack test 002 01 NOx, CO Regulation No. 3, Part B., Section III.G.3 Stack test 003 01 NOx, CO Regulation No. 3, Part B., Section III.G.3 Stack test 004 01 VOC, State only requirement Hard component HAPS count 007 at VOC, Regulation No. 1, Section II.A.5 EPA Method 9 HAPS 009 01 VOC, CO Regulation No. 3, Part B., Section III.G.3 Stack test Section 9 —Source Classification What is this facility classification? True Synthetic X Major Minor Minor Classification relates to what programs? X Title V PSD X NA NSR MACT Is this a modification to an existing permit? Yes X No If"yes"what kind of modification? Minor Synthetic Major Minor Section 10—Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes",for which pollutants?Why? VOC For Reg. 3, Part B, III.C.1.a(emissions increase > 25/50 tpy)? X Yes No Page 7 For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? X Yes No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 —Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards (NAAQS)? If"yes", for which pollutants?Why? NOx emissions are less than 40 TPY. AIRS Point Section 12— Regulatory Review Regulation 1 - Particulate.Smoke, Carbon Monoxide and Sulfur Dioxide Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A(July, 001-009 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5-Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2—Odor Section I.A- No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are 001-009 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 3-APENs.Const©.ucign Permits, Operating Permits, PSD Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: 001-009 each individual emission point in a non-attainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant(pollutants are not summed) for which the area is non-attainment. (Applicant is required to file an APEN since emissions exceed 1 ton per year VOC) Part B—Construction Permit Exemptions 001-009 Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold(Reg. 3, Part B, Section II.D.2.a) Part B, III.D.2- RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is/is not located in the 8-hour ozone nonattainment area, but not the 1-hour ozone area. 006 The date of interest for determining whether the source is new or modified is therefore November 20, 2007 (the date of the 8-hour ozone NA area designation). Since the tank battery from which loadout is occurring will be in service after the date above, this source is considered"new or modified." Operator is using 0.6 saturation factor(submerged fill), therefore, RACT requirements are satisfied. Regulation 6 New Source Performance Standards NSPS JJJJ: Determined by the date the engine was manufactured. All three engines 001-003 were manufactured prior to July 1, 2008(date for RB> 25 HP). Therefore,these engines are not subject to NSPS JJJJ and will be subject to Regulation 7. NSPS OOOO: Equipment Leaks of VOC from onshore natural gas processing plants. Affected facilities at onshore natural gas facilities (any processing site engaged in 004 the extraction of natural gas liquids from field gas,fractionation of mixed natural gas liquids (NGLs)or both). Source not subject since it is located at a wellhead site. 005-008 None Page 8 NSPS JJJJ: Determined by the date the engine was manufactured. This engine was 009 manufactured after July 1, 2007 (date for not RB> 1350 HP). Therefore, this engine is subject to NSPS JJJJ. Regulation 7—Volatile Organic Compounds 001-003 Since the engines are subject to MACT ZZZZ, but not NSPS JJJJ, it will be subject to the requirements under Regulation 7. Section XII.G: If facility is a natural gas processing plant located in non-attainment 004 area, therefore, not subject to Section XII.G. Facility is not a natural gas processing plant, therefore, not subject to this subpart. 005-007, None 009 XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS This facility is located in the 8-hr ozone control area; therefore, this facility is subject • 008 to Section XII of this regulation. XVII STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... Applicant is currently subject to this since actual uncontrolled emissions are greater than 20 tpy of VOC. Regulation 8—Hazardous Air Pollutants 001-003, MACT ZZZZ:The date of construction is the first time the engines are installed at any 009 location, therefore,the engines are new sources for MACT ZZZZ applicability. • MACT HH: If facility is MAJOR source for HAP (summation of HAPS of dehydrators 004, 008 and fugitives), then fugitive emissions are subject to MACT HH. Source is at an E&P site (not a gas plant), therefore, not subject to MACT HH. 006 MACT EEEE: Not subject because minor source of HAPs 005, 007 None Section 13—Aerometric Information Retrieval System Coding Information Emission Pollutant/ Fugitive Emission Factor Control Point Process Process Description Factor CAS# (Y/N) Source (%) 1.43 g/hp-hr VOC No Manufacturer 51 5.92 g/hp-hr NOx No Manufacturer 83.1 32.4 g/hp-hr CO No Manufacturer 93.8 0.0205 Formaldehyde No AP-42, Table 0 001 01 4SRB RICE lb/mmbtu 3.2-3 0.0028 Acetaldehyde No AP-42, Table 0 lb/mmbtu 3.2-3 0.0026 Acrolein No AP-42, Table 0 lb/mmbtu 3.2-3 0.0016 Benzene No AP-42, Table 0 lb/mmbtu 3.2-3 SCC 20200253: 4-cycle rich burn 0.33 g/hp-hr VOC No Manufacturer 0 10.9 g/hp-hr NOx No Manufacturer 90.8 13.1 g/hp-hr CO No Manufacturer 84.7 002 0.0205 Formaldehyde No AP-42, Table 0 and 01 4SRB RICE lb/mmbtu 3.2-3 003 0.0028 Acetaldehyde No AP-42, Table 0 each lb/mmbtu 3.2-3 0.0026 Acrolein No AP-42, Table 0 lb/mmbtu 3.2-3 0.0016 Benzene No AP-42, Table 0 lb/mmbtu 3.2-3 SCC 20200253: 4-cycle rich burn 01 Fugitive VOC Leak Emissions VOC Yes EPA-453/R-95- NA 004 017, Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves,flanges, connections, seals, drains) Page 9 6.2381 CDPHE PS lb/1000 gal VOC No Memo 09-02 95 throughput Produced Water Storage 0.1667 CDPHE PS 01 Tanks lb/1000 gal Benzene No Memo 09-02 95 005 throughput 0.5238 CDPHE PS lb/1000 gal n-Hexane No Memo 09-02 95 throughput SCC 40400315—Fixed Roof Tank, Produced Water,working+breathing+flashing losses 6.93 lb/1000 VOC No AP-42 95 gal 0.0714 Benzene No AP-42 95 lb/1000 gal 0.2143 Toluene No AP-42 95 lb/1000 gal 01 Truck Loadout 0.0238 Ethylbenzene No AP-42 95 006 lb/1000 gal 0.2381 Xylenes No AP-42 95 lb/1000 gal y 0.4256 n-hexane No AP-42 95 lb/1000 gal 0.0476 2 2 4-TMP No AP-42 95 lb/1000 gal SCC 40600132: Crude Oil: Submerged Loading (Normal Service) 10492.0152 Engineering • VOC No 95 lb/MMscf Calculation 0.068 AP-42, lb/MMBtu NOx No Table 13.5-1 NA 0.37 AP-42, lb/MMBtu CO No Table 13.5-1 NA 23.9810 Benzene No Engineering 95 01 Flares lb/MMscf Calculation 007 14.9886 Toluene No Engineering 95 lb/MMscf Calculation 2.0 lb/MMscf Ethlybenzene No Engineering 95 Calculation 0 lb/MMscf Xylenes No Engineering 95 Calculation 98.9240 n-hexane No Engineering 95 lb/MMscf Calculation SCC 31000205-Flares 18.3333 EPA Tanks and lb/1000 gal VOC No WinSim 95 01 Condensate Storage 0.0643 Benzene No EPA Tanks and 95 008 Tanks lb/1000 gal WinSim 0.5714 n-hexane No EPA Tanks and 95 lb/1000 gal WinSim SCC 40400311 —Fixed Roof Tank, Condensate,working+breathing+flashing losses 1.4 g/hp-hr VOC No Manufacturer 70 1.0 g/hp-hr NOx No Manufacturer 0 3.12 g/hp-hr CO No Manufacturer 68 009 01 4SLB RICE 0.36 g/hp-hr Formaldehyde No AP-42, Table 72 3.2-3 0.00836 Acetaldehyde No AP-42, Table 0 lb/mmbtu 3.2-3 0.00514 Acrolein No AP-42, Table 0 lb/mmbtu 3.2-3 0.00044 Benzene No AP-42, Table 0 lb/mmbtu 3.2-3 Page 10 SCC 20200254: 4-cycle lean burn Section 14—Miscellaneous Application Notes AIRS Point 001 4SRB RICE A permit will be issued because the uncontrolled NOx and CO emissions are greater than 1 TPY(APEN threshold) and total permitted NOx and CO emissions are greater than 5 TPY (permit threshold). Operator provided manufacturer emission factors for NOx, CO and VOC. AP-42 was used in generating HAP emissions. 002 AIRS Point and 4SRB RICE 003 A permit will be issued because the uncontrolled NOx and CO emissions are greater than 1 TPY(APEN threshold) and total permitted NOx and CO emissions are greater than 5 TPY (permit threshold). Operator provided manufacturer emission factors for NOx, CO and VOC. AP-42 was used in generating HAP emissions. AIRS Point 004 Fugitive emissions A permit will be issued because the uncontrolled VOC emissions are greater than 1 TPY (APEN threshold) and TOTAL FACILITY is greater than 2 TPY(permit threshold). An extended gas analysis was provided in the application dated 01/20/14. The gas analysis was perfomed less than a year of submittal. An updated extended gas analysis will not be required because an extended gas analysis was performed within a year of this submittal and included with this package I emailed the operator on 5/2/14: 1. I am working on the application submitted in January for the Wolfpack& Lone Wolf Econode facility. I am looking at the fugitives right now and was wondering if you could provide me the calculations on how the HAPS were calculated? I also noticed that the calculation sheet is showing 19.57%wt gas and 100% wt light oil while the APEN shows 27.1%wt gas and 99.9% wt light oil. I believe the calculation sheet is correct, for it matches the emissions shown on the APEN, so I redlined the APEN. Please do so for your records as well. 2. I found the sheet describing the HAPS (it was stuck to another sheet) and I got slightly different emissions. I typically will also multiply the wt% to the emissions as well. Since the APEN did not indicate stream wt% (Section 5)for heavy oil and water, I just used the same as what was provided for the light oil since it was 100%wt. Please see attached. Just some slight discrepancy. If you agree, I can just redline the APEN. He quickly replied on 5/2/14: /am so sorry that this APEN was such a mess!I agree, please redline the APEN. This application was fast tracked, and I did not get to review it as closely as I normally would. Thanks! 3. I am looking at the gas analysis included with the fugitives, and I am not seeing where 19.57% was calculated. The analysis says VOC wt fraction of 18.6% and the HAPS are a little skewed. He wrote back: It looks like they used a corrected VOC weight percent. I received a revised APEN and supporting calculations via email on 5/5/14. The revised APEN correlates with the gas analysis with 18.6% wt VOC. The emissions changed slightly, so I verified the PA to make sure all was correct. Page 11 AIRS Point 005 Produced Water Storage Tanks A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY (permit threshold). State-Developed Emission factors in lb/1000 gal are: Produced Water Tank Default County Emission Factors (lb/1000 gal) VOC Benzene n-Hexane Adams,Arapahoe, Boulder, Broomfield, Denver, 6.2381 0.1667 0.5238 Douglas, Jefferson,'Lorimer and Weld Garfield, Mesa, Rio Blanco and Moffat 4.2381 0.0952 0.2381 Remainder of Colorado 6.2381 0.1667 0.5238 I emailed the operator on 5/2/14: Just looking at the produced water tanks and it looks like the emissions on the APEN are for 450,000 bbl/yr throughput not 475,000 bbl/yr throughput. Which one is correct? I am assuming that the throughput should be 450,000 bbl/yr. I can redline the APEN accordingly. He wrote back quickly on 5/2/14: The throughput should be 450,000 bbl/yr. I redlined the APEN accordingly Page 12 AIRS Point 006 Truck Loadout Units Basis S 0.6 Submerged loading: dedicated normal service P 7.88 Psia Based on EPA TANKs run M 60 Lb/lb-mole Based on EPA TANKs run T 510 Deg R Based on EPA TANKs run L 6.93 Lb/10^3 gal This value is used to calculate annual emissions 0.291 Lb/bbl AP-42: Chapter 5.2 Equation 1 L = 12.46"S*P*M/T L = loading losses in lb per 1000 gallons loaded S = Saturation Factor P = true vapor pressure of liquid loaded [psia] M = molecular weight of vapors [lb/lb-mole] T= temperature of bulk liquid loaded [deg. R] L 6.931b/10^3 gal 2.91 E-01lb/bbl Annual requested Throughput 33600000ga1/yr Annual requested VOC emissions 2328711b/yr 116.44tpy I emailed the operator a question on 5/2/14: I am wondering where the wt% came from regarding the loadout calculations. The calculation sheet says that it came from DOC# EPA-453/R-94-002a however when I looked up this document, Table 3-2, it was not the same values as reflected in the calculations. Any guidance would be helpful. He quickly wrote back on 5/2/14: Usually the weight percent comes from the condensate analysis, which is included in the emission factor package. I received a revised APEN and supporting calculations via email on 5/5/14. All calculations seemed to be revised using the correct information from the application. Operator used the wt%from the separator extended liquids analysis sampled on 1/20/14. Emission factors for HAPS are: Benzene = (2400 Ib/yr)/(800000) = 0.003 lb/bbl*1000/42 = 0.0714 lb/1000 gal Toluene= (7200 Ib/yr)/(800000) = 0.009 lb/bbl*1000/42 = 0.2143 lb/1000 gal Ethylbenzene= (800 Ib/yr) /(800000) = 0.001 lb/bbl*1000/42 = 0.0238 lb/1000 gal Xylenes= (8000 Ib/yr) /(800000) = 0.01 lb/bbl*1000/42= 0.2381 lb/1000 gal n-hexane = (14400 lb/yr)/ (800000) = 0.018 lb/bbl*1000/42 = 0.4256 lb/1000 gal 2,2,4-TMP = (1600 Ib/yr)/(800000) = 0.002 lb/bbl*1000/42 = 0.0476 lb/1000 gal Page 13 AIRS Point 007 Flare The wrong APEN was submitted for this point source. I emailed the operator and received the correct APEN via email on 5/5/14. Operator provided an extended gas analysis and emissions were calculated using EPA Emission Inventory Improvement Program Publication, Volume II, Chapter 10-Displacement equation (10.4-3) where: Ex=Q *MW*Xx/C Ex=emissions of pollutant x Q = Volumetric flow rateNolume 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 Emissions generated from the flare are: Spreadsheet Spreadsheet Operator Operator Which is Component Uncontrolled Controlled Uncontrolled Controlled greater? Total(lb/yr) Total(lb/yr) Total(lb/yr) Total(lb/yr) NOx 11.0 TPY 11.0 TPY 11.0 TPY 11.0 TPY Same VOC 1381.3 TPY 69.1 TPY 1379.7 TPY 69.0 TPY Spreadsheet CO 59.89 TPy 59.89 TPY 59.8 TPY 59.8 TPY Spreadsheet Benzene 6234 312 6307 315 Operator Toluene 3837 192 3942 197 Operator Ethylbenzene 516 26 526 26 Operator Xylenes 147 7 0 0 Spreadsheet n-hexane 25955 1298 26017 1301 Operator 224-TMP 0 0 0 0 Same The calculations that I did versus the operator are slightly off. I believe this is due to rounding for they are very close to each other with no significant differences. Even though I calculated xylenes emissions, are are below the reporting threshold of 250 lb/yr. Therefore, I am going to use the operator's calculations when permitting this point source. An extended gas analysis was provided in the application dated 01/20/2014. The gas analysis was perfomed less than a year of submittal. An updated extended gas analysis will not be required because an extended gas analysis was performed within a year of this submittal and included with this package. Uncontrolled emission factors are: VOC = (1379.7*2000)/263 mmscf/yr= 10492.0152 lb/mmscf Benzene= (6307 lb/yr)/263 mmscf/yr= 23.9810 lb/mmscf Toluene= (3942 lb/yr)/263 mmscf/yr= 14.9886 lb/mmscf Ethylbenzene= (526 lb/yr)/263 mmscf/yr= 2.0 lb/mmscf Xylenes= (0 lb/yr)/263 mmscf/yr= 0 lb/mmscf n-hexane= (26017 lb/yr)/263 mmscf/yr= 98.9240 lb/mmscf Page 14 • AIRS Point 008 Condensate tanks A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY(permit threshold). Emissions were calculated using site-specific emission factors from EPA Tanks (working and breathing) and WinSim Design II model (flashing). Four gas analyses were used in the model for calculating the flash losses. Sampled on December 9, 2013 (within a year of application submittal). Uncontrolled emission factors with 600,000 bbl/yr: Component Uncontrolled Uncontrolled Emission Emission Total Total emission emissions- emissions- factor-EPA factor- Emission factor-(lb/1000 EPA Tanks WinSim Tanks WinSim factor— gal) (TPY) (TPY) (lb/bbl) (lb/bbl) (Ib/bbl) VOC 107.99 200.35 0.27 0.5 0.77 18.3333 Benzene 0.236 0.844 0.0006 0.0021 0.0027 0.0643 n-hexane 2.84 6.62 _ 0.007 0.017 0.024 0.5714 AIRS Point 009 4SLB RICE A permit will be issued because the uncontrolled VOC, NOx and CO emissions are greater than 1 TPY (APEN threshold) and total permitted NOx and CO emissions are greater than 5 TPY (permit threshold). Operator provided manufacturer emission factors for NOx, CO, VOC and formaldehyde. AP-42 was used in generating HAP emissions. Page 15 0 V 'O ,--. 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Q Qs 4 �i o 0 r a 7 J °O c c v e) u v C 4 p o g o o c ce N $ c o o R E ° U i x a $ c tc o v o E a Z 'u 0 p > CZ cL ¢ C C W O D U (A c 7 .0ILI U c u a c > ?- y u o x x o O d Ocinn - K :4m, ❑ a W F- `r u q w Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTERY Current Status(Check all that apply) Ay a)E O(',3g Reason for APEN Submittal(Check all that apply) AIRS ID#':O RA CA-cis/Co Si ❑ APEN update only° ® New or previously unreported battery ❑ Modification to existing source ❑ Previously grandfathered battery' ❑ Registration for coverage under general permit no. GPOI and ® Synthetic minor facility cancellation request for individual permits: ® Located in the 8-hr Ozone Control Areas ® Application for or Modification of an individual pennit ❑ Registered under general permit no.GP01 ❑ Administrative permit amendment' ❑ Permitted under individual permit: ❑ Other: For individual permit applications,check if you wants: ❑ A copy of the preliminary analysis conducted by the Division ®To review a draft of the permit prior to issuance Company Names: Noble Energy,Inc OGCC Operator#: 100322 Mailing Address10: 1625 Broadway Suite 2200 ney@nobleenergyinc City: Denver State: CO Zip: 80202 E-mail: 'co m Contact Name: Mike Putney Phone: (303)228-4385 Fax: (303)228-4286 Tank Battery Name': Wolfpack&Lone Wolf Econode Number of tanks: 12 Location12(QQ Sec.Twp. Range.): SWSW SEC2 T5N R64W County: Weld Total tank capacity[bbl]: 6000 Calendar year for which"Actual"data applies13: 2014 Year(s)tank(s)were placed in service'4: 2013 Control Description's: Vapor Combustor Control Efficiency16: 95% Condensate Throughput"[bbl/year] Requested1s: 800,000 Maximum for PTE calculation'9: 800,000 Actual": While Controls Operational21 Other equipment at facility": Comments: Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit ❑ Check if the Division is to calculate emissions. ®Check if site-specific emission factors provided to calculate emissions2s. Emission Factor Battery Requested Emissions1e Actual Emissions" Pollutant24 [Ib/bbl] PTE2i Uncontrolled26 Controlled" Uncontrolled26 Controlled' VOC[tons/year] 0.77 308 308 15.4 NOx[tons/year] CO[tons/year] Benzene[lbs/year] 0.0027 2,160 2,160 108.0 n-Hexane[lbs/year] 0.024 19,200 19,200 960.0 Wells serviced by this tank or tank battery's API#: 05-123-37321 Name: WOLFPACK B02-65HN ®Newly Reported Well API#: 05-123-37324 Name: WOLFPACK B02-64-1 HN ®Newly Reported Well API#: 05-123-37323 Name: WOLFPACK PC-B03-63-1HN ®Newly Reported Well API#: 05-123-37325 Name: WOLFPACK 502-63-1H ®Newly Reported Well API#: 05-123-37327 Name WOLFPACK B02-62-1 HN E Newly Reported Well API#: 05-123-37328 Name: WOLFPACK B02-66-IHN ®Newly Reported Well API#: 05-123-37326 Name: WOLFPACK B02-65-1HN ®Newly Reported Well API#: 05-123-37322 Name: LONE WOLF B-02-65-HC ®Newly Reported Well I The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of my knowledge and belief. If this is a registration for coverage under general permit GPI,I further certify that this source is and will be operated in full com.liance wi h each,condition of general permit GPI. - 4L I - 1/ mat if ZI / 2c/ V Signature of Legally Authorized Person(not a vendor or consultant) Date Mike Putney Environmental Engineer III Type or Print Name of Person Signing Above Official Title Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment For information call: filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-B1 (303)692-3150 $250 General Permit fee for each new GP 4300 Cherry 304828 Creek Drive South registration to: Denver,CO 80246-1530 FORM APCD-205 Page 1 of 2 WOLFPACK APEN COLD TANK BATTERY E W v 'V '•, C v O ';. = O U f• O _a �+ u a. _ ol^ v. .G ^r :7 z = p LZtI DD" i M r?r? = U o N C ` +. O O G C U N N rl y • v L O r 1. . 7 ...I w . ❑ `el C U . 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