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Home My WebLink About20143565.tiff CDPHE COLORADO CO V Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 11500 St PO Box 758 Greeley, CO 80632 November 7, 2014 Dear Sir or Madam: On November 12, 2014, the Air Pollution Control Division will begin a 30-day public notice period for Noble Energy, Inc. - Cougar B02-67-1HN, 68-1HN, 69-1HN Battery. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from - the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, i 7) ' - `.-7'�"- c) Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure /pF COO .,. p (11 ? 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 vrww.colorado.gov/cdphe ( F� x John W. Hickenlooper, Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer , _„ �` a,s \*Tw=ist«f 70.0(0 Keulea.6 2014-3565 II - I-1-ILI Ce,'-TlP011-kl.l`(l3 1 CDPHE Air Pollution Control Division CO ' Notice of a Proposed Project or Activity Warranting Public ' Comment Website Title: Noble Energy, Inc. - Cougar B02-67-1HN, 68-1HN, 69-1HN Battery - Weld County Notice Period Begins: November 12, 2014 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: Cougar B02-67-1HN, 68-1HN, 69-1HN Battery Oil and gas exploration and production facility NWNW Section 2, T5N, R64W Weld County The proposed project or activity is as follows: Oil and gas exploration and production facility including condensate tanks, produced water tanks, truck loadout, reciprocating internal combustion engines and associated fugitive emissions. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non-attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 14WE1300 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Stephanie Chaousy Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us ®'� XOLONADO 1I DRAFT STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT w'- OF't, AIR POLLUTION CONTROL DIVISION Ne TELEPHONE:(303)692-3150 «« +« .476« CONSTRUCTION PERMIT PERMIT NO: 14W E1300 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 Cougar B02-67-1 HN, 68-1 HN, 69-1 HN Battery, located in the NWNW Section 2, T5N, R64W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Tank Nine (9) above ground 500 bbl atmospheric condensate Battery 001 storage tanks. Emissions from these tanks are controlled by an enclosed flare. TLO 002 Truck loadout of condensate. Emissions from the loadout are not controlled. PW Three (3) above ground 300 bbl and four (4) 60 bbl 003 atmospheric produced water storage tanks. Emissions from these tanks are controlled by an enclosed flare. Equipment leaks (fugitive VOCs) from a natural gas exploration Fugitives 004 and production facility. One (1) Cummins, Model G5.9, Serial Number 2LB016831, natural gas-fired, naturally aspirated, 4SRB reciprocating COMP1 005 internal combustion engine, site rated at 84 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) Cummins, Model G5.9, Serial Number 2LB017011, natural gas-fired, naturally aspirated, 4SRB reciprocating COMP2 006 internal combustion engine, site rated at 84 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. Points 005 and 006: These engines may be replaced with another engine in accordance with the temporary engine replacement provision or with another Cummins G5.9 engine in AIRS ID: 123/9DOC Page 1 of 23 Fugitive SM/M Version 2012-2 I r accordance withDnR.stLFTrnateOperatklgscena,jo (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 sea,), 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. 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). 2. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, I I I.F.4.) 3. 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.) 4. 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 5. 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 NOx VOC CO Tank Battery 001 — 12.3 — Point TLO 002 — 29.1 — Point PW 003 - 1.0 -- Point Fugitives 004 -- 38.6 -- Fugitive COMP1 005 2.3 0.8 3.9 Point AIRS ID: 123/9DOC Page 2 of 23 olor-A Depa en li Health and Environment T Pollution Control Division COMP2 006 Point J See "Notes to Permit Holder"for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. 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. 6. Point 004: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas analysis, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. 7. 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 Tank Battery 001 Enclosed flare VOC and HAPS PW 003 Enclosed flare VOC and HAPS COMP1 005 NSCR and air/fuel ratio controller NOx and CO COMP2 006 NSCR and air/fuel ratio controller NOx and CO PROCESS LIMITATIONS AND RECORDS 8. 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 AIRS Process Parameter Annual Limit Point 001 Condensate throughput 225,000 BBL 002 Condensate Loading_ 225,000 BBL AIRS ID: 123/9DOC Page 3 of 23 ol 003DuRsAJ"• 1l5oo: BBL 005 Consumption of natural gas as a fuel 4.79 MMscf/yr 006 Consumption of natural gas as a fuel 4.79 MMscf/yr 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. STATE AND FEDERAL REGULATORY REQUIREMENTS 9. 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.) 10. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 11. Point 001: 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. 12. Point 001: 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. 13. Point 001: 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. 14. Point 001: The condensate storage tanks covered by this permit are subject to Regulation 7, Section XVII.C emission control requirements. These requirements include, but are not limited to: XVII.C.1.a. 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. AIRS ID: 123/9D0C Page 4 of 23 olor. A Depa en • •Ii ''Health and Environment it Pollution Control Division 15. Points 001 a• T - r : • - ed --rmit - eject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). These requirements include, but are not limited to: XVIl.B.1.b 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. XVII.B.2.d.(ii) All combustion devices installed before May 1, 2014, must be equipped with an operational auto-igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 16. Points 001 and 003: The storage tanks covered by this permit are subject to Regulation 7, Section XVII.C emission control requirements. These requirements include, but are not limited to: • Section XVII.C.1. Control and monitoring requirements for storage tanks XVII.C.1.b. Owners or operators of storage tanks with uncontrolled actual emissions of VOCs equal to or greater than six (6) tons per year based on a rolling twelve- month total must operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. XVII.C.1.b.(i)(b) Control requirements of Section XVII.C.1.b. must be achieved by May 1, 2015. XVII.C.1.d. Beginning May 1, 2014, or the applicable compliance date in Section XVII.C.1.b.(i), whichever comes later, owners or operators of storage tanks constructed before May 1, 2014 subject to Section XVII.C.1. must conduct audio, visual, olfactory ("AVO") and additional visual inspections of the storage tank and any associated equipment (e.g. separator, air pollution control equipment, or other pressure reducing equipment) at the same frequency as liquids are loaded out from the storage tank. These inspections are not required more frequently than every seven (7) days but must be conducted at least every thirty one (31) days. Monitoring is not required for storage tanks or associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section XVII.C.1.e. The additional visual inspections must include, at a minimum: XVII.C.1.d.(i) Visual inspection of any thief hatch, pressure relief valve, or other access point to ensure that they are closed and properly sealed; XVII.C.1.d.(ii) Visual inspection or monitoring of the air pollution control equipment to ensure that it is operating, including that the pilot light is lit on combustion devices used as air pollution control equipment; XVII.C.1.d.(iii) If a combustion device is used, visual inspection of the auto-igniter and valves for piping of gas to the pilot light to ensure they are functioning properly; AIRS ID: 123/9DOC Page 5 of 23 olor Depa en li Health and Environment it Pollution Control Division XVII.C is of olluti trol equipment to ensure that the valves for the piping from the storage tank to the air pollution control equipment are open; and XVII.C.1.d.(v) If a combustion device is used, inspection of the device for the presence or absence of smoke. If smoke is observed, either the equipment must be immediately shut-in to investigate the potential cause for smoke and perform repairs, as necessary, or EPA Method 22 must be conducted to determine whether visible emissions are present for a period of at least one (1) minute in fifteen (15) minutes. XVII.C.1.e. If storage tanks or associated equipment is unsafe, difficult, or inaccessible to monitor, the owner or operator is not required to monitor such equipment until it becomes feasible to do so. XVII.C.2. Capture and monitoring requirements for storage tanks that are fitted with air pollution control equipment as required by Sections XII.D. or XVII.C.1. XVII.C.2.a. Owners or operators of storage tanks must route all hydrocarbon emissions to air pollution control equipment, and must operate without venting hydrocarbon emissions from the thief hatch (or other access point to the tank) or pressure relief device during normal operation, unless venting is reasonably required for maintenance, gauging, or safety of personnel and equipment. Compliance must be achieved in accordance with the schedule in Section XVII.C.2.b.(ii). XVII.C.2.b. Owners or operators of storage tanks subject to the control requirements of Sections XII.D.2., XVII.C.1.a, or XVII.C.1.b. must develop, certify, and implement a documented Storage Tank Emission Management System ("STEM") plan to identify, evaluate, and employ appropriate control technologies, monitoring practices, operational practices, and/or other strategies designed to meet the requirements set forth in Section XVII.C.2.a. Owners or operators must update the STEM plan as necessary to achieve or maintain compliance. Owners or operators are not required to develop and implement STEM for storage tanks containing only stabilized liquids. The minimum elements of STEM are listed below. XVII.C.2.b.(i) STEM must include selected control technologies, monitoring practices, operational practices, and/or other strategies; procedures for evaluating ongoing storage tank emission capture performance; and monitoring in accordance with approved instrument monitoring methods following the applicable schedule in Section XVII.C.2.b.(ii) and Inspection Frequency in Table 1. XVII.C.2.b.(ii) Owners or operators must achieve the requirements of Sections XVII.C.2.a. and XVII.C.2.b. and begin implementing the required approved instrument monitoring method in accordance with the following schedule: XVII.C.2.b.(ii)(b) A storage tank constructed before May 1, 2014, must comply with the requirements of Sections XVII.C.2.a. and XVII.C.2.b. by May 1, 2015. Approved instrument monitoring method inspections must begin within ninety (90) days of the Phase-In Schedule in Table 1, or within AIRS ID: 123/9DOC Page 6 of 23 olor-i Depa en . • di Health and Environment it Pollution Control Division I) - - f• ! - ,•e unc• • • led actual VOC emissions greater than 50 tons per year. XVII.C.2.b.(ii)(d) Following the first approved instrument monitoring method inspection, owners or operators must continue conducting approved instrument monitoring method inspections in accordance with the Inspection Frequency in Table 1. Table 1 —Storage Tank Inspections Threshold: Storage Tank Approved Instrument Phase-In Schedule Uncontrolled Actual VOC Monitoring Method Emissions (tpy) Inspection Frequency > 6 and < 12 Annually January 1, 2016 > 12 and < 50 Quarterly July 1, 2015 I > 50 Monthly January 1, 2015 XVII.C.2.b.(iii) Owners or operators are not required to monitor storage tanks and associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section XVII.C.1.e. XVII.C.2.b.(iv) STEM must include a certification by the owner or operator that the selected STEM strategy(ies) are designed to minimize emissions from storage tanks and associated equipment at the facility(ies), including thief hatches and pressure relief devices. XVII.C.3. Recordkeeping XVII.C.3. The owner or operator of each storage tank subject to Sections XII.D. or XVII.C. must maintain records of STEM, if applicable, including the plan, any updates, and the certification, and make them available to the Division upon request. In addition, for a period of two (2) years, the owner or operator must maintain records of any required monitoring and make them available to the Division upon request, including: XVII.C.3.a. The AIRS ID for the storage tank. XVII.C.3.b. The date and duration of any period where the thief hatch, pressure relief device, or other access point are found to be venting hydrocarbon emissions, except for venting that is reasonably required for maintenance, gauging, or safety of personnel and equipment. XVII.C.3.c. The date and duration of any period where the air pollution control equipment is not operating. XVII.C.3.d. Where a combustion device is being used, the date and result of any EPA Method 22 test or investigation pursuant to Section XVII.C.1.d.(v). XVII.C.3.e. The timing of and efforts made to eliminate venting, restore operation of air pollution control equipment, and mitigate visible emissions. AIRS ID: 123/9DOC Page 7 of 23 olor Depa en Ii and Environment it Pollution Health Control Division XVII.C.3.f.A f ip ' d orag that is designated as unsafe, difficult, or inaccessible to monitor, as described in Section XVII.C.1.e., an explanation stating why the equipment is so designated, and the plan for monitoring such equipment. 17. Point 002: 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) 18. Point 002: 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 18 (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. 19. Point 002: 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. 20. 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 extent practicable. The operator shall comply with all applicable requirements of Section XII: 21. 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 may be used to determine the size of the leak. The gas detector shall be 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 AIRS ID: 123/9DOC Page 8 of 23 olor-� Depa en . - •li Health' and Environment II it Pollution Control Division ty. . - • le. ''- han Y •+0 ppm shall not require repair. 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. Hi. 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 AVO to determine if the leak is repaired. 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. OPERATING & MAINTENANCE REQUIREMENTS 22. 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 23. Points 001 and 003: The owner or operator shall demonstrate compliance with opacity standards, using EPA Method 22 to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one (1) minute in any fifteen (15) minute period during normal operation. (Reference: Regulation No. 7 Section XVII.AII) 24. Point 004: Within one hundred and eighty days (180) after issuance of this 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. 25. Points 005 and 006: A source initial compliance test shall be conducted on emissions points 005 and 006 to measure the emission rate(s) for the pollutants listed below in AIRS ID: 123/9DOC Page 9 of 23 Depa en li Health and Environment it Pollution Control Division order to deDolor • ion li 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. Periodic Testing Requirements 26. Point 004: On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. 27. Points 005 and 006: These engines are subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 28. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5)tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five . percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of arty facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or AIRS ID: 123/9DOC Page 10 of 23 olorl Depa en . ' •Ii Health and Environment it Pollution Control Division d. When: —rm* .- t.:, . - st • - - r'-d; or e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative-operating scenario and is installing a permanent replacement engine. 29. Federal regulatory program requirements (i.e. PSD, 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 30. 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. 31. 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. 32. 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. 33. 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. 34. 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 AIRS ID: 123/9DOC Page 11 of 23 Depa en li Health and Environment it Pollution Control Division failure to meDolor r on he p 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. 35. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 36. 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 condensate tanks, produced water tanks, truck loadout, two reciprocating internal combustion engines and associated fugitives at a synthetic minor facility. AIRS ID: 123/9D0C Page 12 of 23 Ill olor.� Depa en . • •li Health and Environment I •it Pollution Control Division Notes to Permit Holder - me o "' .e a -. 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 emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: https://www coloredo.gov/pacific/cdnhe/agcc-reqs 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 Controlled Emission Are the Emission AIRS Rate emissions Rate Point Pollutant CAS# BIN (Ib/yr) reportable? (Ib/yr) Benzene 71432 A 1598 Yes 80 Toluene 108883 C 1283 Yes 64 Ethylbenzene 100414 C 77 No 4 001 Xylenes 1330207 C 401 Yes 20 n-Hexane 110543 C 14850 Yes 743 2,2,4-TMP 540841 C 405 Yes 20 Benzene 71432 A 473 Yes 473 Toluene 108883 C 1590 Yes 1590 Ethylbenzene 100414 C 267 Yes 267 002 Xylenes 1330207 C 1757 Yes 1757 n-Hexane 110543 C 3902 Yes 3902 2,2,4-TMP 540841 C 283 Yes 283 Benzene 71432 A 1050 Yes 53 003 n-Hexane 110543 C 3300 Yes 165 Benzene 71432 A 481 Yes 481 004 Toluene 108883 C 1429 Yes 1429 Ethylbenzene 100414 C 237 No 237 AIRS ID: 12319D0C Page 13 of 23 loDepli Health and Environment it Pollution Control Division Xylenes R: AFt 7 Yes 1537 n-Hexane 110543 C 3668 Yes 3668 Formaldehyde 50000 A 119 No 119 Methanol 67561 C 18 No 18 005 Acetaldehyde 75070 A 16 No 16 and Acrolein 107028 A 15 No 15 006 each Benzene 71432 A 9 No 9 1,3-Butadiene 106990 A 4 No 4 Toluene 108883 C 3 No 3 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/1000 gal lb/1000 gal Source Condensate Condensate Throughput Throughput Engineering VOC 51.9048 2.5952 calculation (WimSim + EPA Tanks) Engineering 71432 Benzene 0.1690 0.0085 calculation (WimSim+ EPA Tanks) Engineering 108883 Toluene 0.1357 0.0068 calculation (WimSim + EPA Tanks) Engineering 100414 Ethylbenzene 0.0081 0.0004 calculation (WimSim + EPA Tanks) Engineering 1330207 Xylene 0.0424 0.0021 calculation (WimSim + EPA Tanks) Engineering 110543 n-Hexane 1.5714 0.0786 calculation (WimSim + EPA Tanks) Engineering 540841 2,2,4-TMP 0.0429 0.0021 calculation (WimSim + EPA Tanks) Note: The controlled emissions factors for point 001 are based on the flare control efficiency of 95%. AIRS ID: 123/9DOC Page 14 of 23 ti olor- Depa en li Health and Environment II 'Iit Pollution Control Division Point 002: Emission Factors -Uncontrolled CAS Pollutant lb/1000 gal Source loaded VOC 6.15 AP-42 71432 Benzene 0.0500 Engineering Calculation 108883 Toluene 0.1683 Engineering Calculation 100414 Ethylbenzene 0.0283 Engineering Calculation 1330207 Xylene 0.1859 Engineering Calculation 110543 n-Hexane 0.4129 Engineering Calculation 540841 2,2,4-TMP 0.0299 Engineering Calculation The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L= 12.46*S*P*Mrf S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) 6.9 psia M (vapor molecular weight)= 62 Ib/Ib-mol T (temperature of liquid loaded)= 520 °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 003: Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source lb/BBL Produced lb/BBL Produced Water Throughput Water Throughput VOC 0.262 0.0131 Source 110543 n-Hexane 0.022 0.0011 Source 71432 Benzene 0.007 0.0004 Source Note: The controlled emissions factors for point 003 are based on the flare control efficiency of 95%. Point 004: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2373 294 595 290 Flanges 363 -- 111 16 Open-ended Lines 21 Pump Seals --- --- 2 Valves 9847 98 • 590 116 Other* 322 --- 52 38 VOC Content(wt. 0.176 1 1 1 fraction) Benzene Content(wt. 0.00047 0.008133 0.008133 0.008133 fraction) Toluene Content(wt. 0.00034 0.027348 0.027348 0.027348 fraction) AIRS ID: 123/9D0C Page 15 of 23 olor Depa en li Health and Environment it Pollution Control Division Ethylbenzene(wt. . 04591 0.004591 fraction) Xylenes Content(wt 0.00010 0.030231 0.030231 0.030231 fraction) n-hexane Content(wt. 0.00189 0.067134 0.067134 0.067134 fraction) *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors(kg/hr-component): Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas analysis. Points 005 and 006: Emission Factors- Emission Factors— Uncontrolled Controlled CAS Pollutant Ib/MMBtu g/bhp-hr Ib/MMBtu g/bhp-hr NOx 3.1785 11.41 0.7800 2.80 CO 4.0783 14.64 1.3371 4.80 VOC 0.2786 1.00 0.2786 1.00 50000 Formaldehyde 0.0205 0.07 0.0205 0.07 l 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 7914 Btu/hp-hr, a . site-rated horsepower value of 84, and a fuel heat value of 1215 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 AIRS ID: 123/9D0C Page 16 of 23 olor- Depa en` • - .li Health and Environment it Pollution Control Division 6) Points 005 and 006: These engines are subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting — effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.aov/ttn/atw/area/fr18ia08.odf 7) Points 005 and 006: 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) 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. 9) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, n-hexane NANSR Synthetic Minor Source of: VOC MACT HH Area Source Requirements: Not Applicable NSPS OOOO Not Applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfrgpoaccess.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 AIRS ID: 123/9D0C Page 17 of 23 Depa en li Health and Environment it Pollution Control Division MALT 6389Dolor S N part 11) A self certification form and guidance on how to self-certify compliance as required by this permit may be obtained online at: http://www.colorado.gov/pacific/cdphe/air-permit-selfcertification. AIRS ID: 123/9D0C Page 18 of 23 olor-A Depa en • - di Health and Environment •it Pollution Control Division ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Pad A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Pad B, Construction Permits, and Regulation No. 3, Part ID, 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: 123/9DOC Page 19 of 23 Depa en li Health and Environment it Pollution Control Division 2.1.2 The owner or oDolor a epl fisting ressor 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.alphe.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: htto://www.colorado.aov/cs/Satellite/CDPH E-AP/CBON/1251596520270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual(tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760),whichever applies. AIRS ID: 123/9D0C Page 20 of 23 Depa en li Health and Environment it Pollution Control Division For comparison with aDolor f a er ' (lb/ ), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B§II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/9D0C Page 21 of 23 Dolo Depa en Ii Health and Environment it 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 0.7 500<Hp July 1, 2007 2.0 4.0 1.0 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 bum 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, § LB (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 7777 A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart 7777.An analysis of the applicable monitoring, recordkeeping, and reporting AIRS ID: 123/9DOC Page 22 of 23 olor Depa en li Health and Environment it Pollution Control Division requirements for the e incl 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. i 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: 123/9D0C Page 23 of 23 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Noble Energy, Inc Permit Number: 14WE1300 Source Location: Cougar B02-67-1HN, 68-1HN, 69-1HN Battery NWNW Section 2,T5N, R64W,Weld County(non-attainment) Point 001: Condensate tanks Point 002: Truck loadout Point 003: produced water tanks Equipment Description: Point 004: fugitive emissions Point 005: RICE Point 006: RICE AIRS ID: 123-9D0C Date: November 3, 2014 Review Engineer: Stephanie Chaousy Control Engineer. Chris Laplante Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Pernit Exempt Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no"to any of the above, when did you mail an Information Request letter to the source? • On what date was this application complete? July 25, 2014 Section 4—Source Description AIRS Point Equipment Description 001 Nine(9)above ground 300 bbl atmospheric condensate storage tanks. Emissions from these tanks are controlled by a flare. 002 Truck Condensate Loadout Three (3) above ground 300 bbl and four(4)above ground 60 bbl atmospheric 003 produced water storage tanks. Emissions from these tanks are controlled by a flare. 004 Fugitive VOC leak emissions Page 1 One(1) Cummins, Model G5.9,Serial Number 2LB016831, natural gas-fired, naturally aspirated,4SRB reciprocating internal combustion engine,site rated at 84 005 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) Cummins, Model G5.9,Serial Number 21_6017011, natural gas-fired, naturally aspirated,4SRB reciprocating internal combustion engine, site rated at 84 006 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. 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? PKo CO X Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes",for what pollutant? (Note: These pollutants are subject to minor source PKo 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 002: Is this source located at an oil and gas X Yes No exploration site? Point 002: 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 002: Is this source located at a facility that is considered a major source of hazardous air pollutant Yes X No (HAP) emissions? Point 002: Will this equipment be operated in any X Yes No NAAQS nonattainmeM area? Point 002: Does this source load gasoline into transport vehicles? Yes X No Point 003: Are"flash"emissions anticipated from X Yes No these tanks? Point 003: Is this tank located at an E&P site? X Yes No Point 003: Is this tank located at a non-E&P, midstream or downstream site? Yes X No Point 003: Is tills 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 003: Are these produced water tanks located at a commercial facility that accepts oil production Yes X No wastewater for processing? Point 003: Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission Yes X No (COGCC)805 Rule? Section 5—Emission Estimate Information AIRS Point Emission Factor Source 001 Source provided site-specific emission factors using gas sample,VinSim and EPA Tanks. See Section 14 for calculations. Page 2 AP-42: Chapter 5.2, Equation 1 L= 12.46*S*P•Ma 002 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] 003 CDPHE Memo 09-02 004 EPA-453/R-95-017,Table 2-4 NOx, CO: Manufacturer specs 005 VOC: conservative All HAPS: AP-42 NOx, CO: Manufacturer specs 006 VOC: conservative All HAPS: AP-42 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 001 225,000 BBL per year 002 225,000 BBL per year 003 150,000 BBL per year Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 2373 294 595 290 004 Flanges 363 — 111 16 Open-Ended Lines 21 -- Pump Seals --- --- 2 Valves 9847 98 590 116 Other 322 --- 52 38 005 4.79 MMscf/yr 006 4.79 MMscf/yr Basis for Permitted Emissions(Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 225,000 BBL per year 002 225,000 BBL per year 003 150,000 BBL per year Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 2373 294 595 290 004 Flanges 363 --- 111 16 Open-Ended Lines 21 --- Pump Seals --- --- 2 Valves 9847 98 590 116 Other 322 --- 52 38 005 4.79 MMscf/yr 006 4.79 MMscf/yr Does this facility use control devices? X Yes No Page 3 AIRS Point, Process Control Device Description % Reduction Granted 001 01 Flare 95 003 01 Flare 95 NOx: 75.5% 005 01 NSCR and AFCR CO: 67.2% 006 01 NSCR and AFCR NOx: 75.5% CO: 67.2% Section 6—Emission Summary (tons per year) Point NO, VOC CO Single HAP Total HAP 001 — 245.0 — 7.4(Hexane) 9.3 002 — 29.1 — 2.0 (Hexane) 4.1 003 --- 19.7 -- 1.7 (hexane) 2.2 PTE: 004 — 38.6 — 1.8 (Hexane) 3.7 005 9.3 0.8 11.9 (fonnald0ehyde) 0.08 0. 006 9.3 0.8 11.9 (fonnald0ehyde) 0.08 001 - 245.0 — 7.4 (Hexane) 9.3 I 002 — 29.1 — 2.0 (Hexane) 4.1 003 --- 19.7 — 1.7 (hexane) 2.2 Uncontrolled point source emission rate: 004 --- 38.6 — 1.8 (Hexane) 3.7 0. 005 9.3 0.8 11.9 (fonnald�ehyde) 0.08 0.006 9.3 0.8 11.9 (fonnald�ehyde) 0.08 001 --- 12.3 -- 0.4 (Hexane) 0.5 002 - 29.1 - 2.0 (Hexane) 4.1 003 — 1.0 — 0.1 (hexane) 0.1 Controlled point source emission rate: 004 -- 38.6 --- 1.8 (Hexane) 3.7 0.06 005 2.3 0.8 3.9 (formaldehyde)0. 0.08 006 2.3 0.8 3.9 (formald0ehyde) 0.08 Section 7—Non-Criteria/ Hazardous Air Pollutants Uncontrolled nre rtre Controlled Emission Pollutant CAS# BIN Emission Rate amiaalom 0biYr) reportable? Rate(lbhr) Point 001 Benzene 71432 A 1598 Yes 80 Toluene 108883 C 1283 Yes 64 Ethylbenzene 100414 C 77 No 4 Xylenes 1330207 C 401 Yes 20 n-Hexane 110543 C 14850 Yes 743 2,2,4-IMP 540841 C 405 Yes 20 Page 4 Point 002 Benzene 71432 A 473 Yes 473 Toluene 108883 C 1590 Yes 1590 Ethylbenzene 100414 C 267 Yes 267 Xylenes 1330207 C 1757 Yes 1757 n-Hexane 110543 C 3902 Yes 3902 2,2,4-TMP 540841 C 283 Yes 283 Point 003 Benzene 71432 A 1050 Yes 53 n-Hexane 110543 C 3300 Yes 165 Point 004 Benzene 71432 A 481 Yes 481 Toluene 108883 C 1429 Yes 1429 Ethylbenzene 100414 C 237 No 237 Xylenes 1330207 C 1537 Yes 1537 n-Hexane 110543 C 3668 Yes 3668 Points 005 and 006 each Formaldehyde 50000 A 119 No 119 Acetaldehyde 75070 A 16 No 16 Acrolein 107028 A 15 No 15 Benzene 71432 A 9 No 9 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 Yes X No standard? If"yes", complete the information listed below Section 9—Source Classification Is this a new previously un-permitted source? X Yes No What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V PSD X NA NSR X 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 Page 5 If"yes",for which pollutants?Why? For Reg. 3, Part B, III.C.1.a(emissions increase>25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.ii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d(synthetic minor emission limits)? X Yes No Section 11 —Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards(NAAQS)? If"yes", for which pollutants?Why? AIRS Point Section 12—Regulatory Review Reaulation 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 001-006 is in excess of 20%opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR, Part 60,Appendix A(July, 1992)) in all subsections of Section II.A and B of this regulation. Reaulat pn 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 001-006 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7)or more volumes of odor free air. Regulation 3'-APENs. Construction Permits. Operating Permits. PSI) Part A-APEN Requirements Criteria Pollutants: For criteria pollutants,Air Pollutant Emission Notices are required for: 001-006 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 001-006 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 ll.D.2a) 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. 002 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 since after the date above, this source is considered"new or modified." Operator is using submerged fill (0.6 saturation factor),therefore, RACT requirements are satisfied. 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. 004 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 fugitives will be in service since after the date above, this source is considered"new or modified." Operator has agreed on the Division's standard conditions. Reaulation 6-New Source Performance Standards Page 6 NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. 001 Is this source greater than 19,800 gallons(471 bbl)? No Is this source subject to NSPS Kb? No WHY? The storage tanks do not meet the criteria of this subpart, therefore, not subject. 002 No applicable subpart. This facili is not a bulk gasoline terminal. NSPS OOOO: Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution. For fugitive emissions at natural gas processing plants subject to NSPS OOOO. This subpart establishes emission standards and compliance schedules for the control of volatile organic compounds(VOC)and 004 sulfur dioxide (SO2)emissions from affected facilities that commence construction, modification or reconstruction after August 23, 2011. Is this source at a"natural gas processing plant?" No Is this source subject to NSPS OOOO? No WHY? Facility does not meet the definition of"natural gas processing plant"therefore not meeting the criteria of this subpart. NSPS JJJJ: the date of construction is the date it was ordered or reconstructed/modified. 005, 006 These engines were manufactured after the 7/1/2008 effective date and are therefore subject to JJJJ. Regulation 7—Volatile Organic Compounds XII.VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is subject to the emission control requirements for condensate tanks 001, 003 since it is located in a non-attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is currently subject to this since actual uncontrolled emissions are greater than 20 tpy of VOC.) No sections apply. Per Regulation 7, Section VI.C, a terminal is defined as a petroleum liquid storage and distribution facility that has a daily average throughput of more than 002 76,000 liters of gasoline (20,000 gallons), which is loaded directly into transport vehicles. This facility is neither a terminal, nor a bulk plant per definitions in Reg 7, Section VI.C. Section XII.G: If facility is a natural gas processing plant located in non-attainment 004 area, then subject to Section XII.G. This facility is not a natural gas processing plant, therefore, not subject. 005, 006 These engines are not subject to Regulation 7 because they are subject to the more stringent requirements of NSPS JJJJ. Regulation 8—Hazardous Air Pollutants MACT EEEE: Organic Liquids Distribution 001 This source is not subject to MACT EEEE because it is not located at a major source of HAP. 001, 004 MACT HH This source is not subject to MACT HH because it is not located at a major source of HAP. 002, 003 None 005, 006 MACT ZZZZ: the date of construction is the first time the engine is installed at any location, therefore the engines are new sources for ZZZZ applicability. Section 13—Aerometric Information Retrieval System Coding Information Process Emission Pollutant/ Fugitive Control Point Process Description Factor CAS# (Y/N) Emission Factor Source (%) 51.9048 VOC No Engineering calculation 95 lb/1000 gal (WimSim+ EPA Tanks) 0.1690 Benzene/ Engineering calculation lb/1000 gal 71432 No (WimSim+ EPA Tanks) 95 0.1357 Toluene/ No Engineering calculation 95 E&P Condensate lb/1000 gal 108883 (WimSim+ EPA Tanks) 001 01 Storage Tanks 0.0081 Ethylbenzene No Engineering calculation 95 lb/1000 gal / 100414 (WimSim+ EPA Tanks) 0.0424 Xylenes/ Engineering calculation lb/1000 gal 1330207 No (WimSim + EPA Tanks) 95 1.5714 n-Hexane/ Engineering calculation lb/1000 gal 110543 No (WimSim+ EPA Tanks) 95 Page 7 0.0429 2,2,4-TMP Engineering calculation I lb/1000 gal /540841 No (WimSim+ EPA Tanks) 95 SCC 40400311 —Fixed Roof Tank, Condensate,working+breathing+Hashing losses 6.15 VOC No AP-42 0 lb/1000 gal 0.0500 Benzene I No Engineering calculation 0 lb/1000 gal 71432 0.1683 Toluene/ No Engineering calculation 0 lb/1000 gal 108883 01 Truck loadout 0.0283 2,2,4 TMP No Engineering calculation 0 lb/1000 gal /540841 002 0.1859 Xylenes/ No Engineering calculation 0 lb/1000 gal 1330207 0.4129 n-Hexane/ No Engineering calculation 0 lb/1000 gal 110543 0.0299 2,2,4-TMP/ No Engineering calculation 0 lb/1000 gal 540841 SCC 40600132: Crude Oil: Submerged Loading (Normal Service) 6.2381 VOC No CDPHE PS Memo 09-02 95 lb/1000 gal 01 Produced Water 0.1667 Benzene No CDPHE PS Memo 09-02 95 003 Storage Tanks lb/1000 gal 0.5238 n-Hexane No CDPHE PS Memo 09-02 95 lb/1000 gal SCC 40400315—Fixed Roof Tank, Produced Water,working+breathing+flashing losses 004 01 Fugitive VOC Leak VOC Yes EPA-453/R-95-017, NA Emissions Table 2-4 SCC 31000220: All Equip. Leak Fugitives(Valves,flanges, connections, seals,drains) 11.41 g/hp- 4SRB hr NOx No Manufacturer 75.5 005 Reciprocating 1.0 g/hp- Operator estimation and 01 Internal hr VOC No (conservative) 0 006 Combustion 14.64 each Engine g/hp-hr CO No Manufacturer 67.2 SCC 40400315—Fixed Roof Tank, Produced Water,working+breathing+flashing losses Section 14—Miscellaneous Application Notes AIRS Point 001 Condensate Storage 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). A gas analysis was used in the model for calculating the flash losses. Sampled on June 6, 2014 (within a year of application submittal). Uncontrolled emission factors with 225,000 bbl/yr. Component Uncontrolled Uncontrolled Emission Emission Total Total Uncontrol emissions- emissions- factor-EPA factor- Emission emission led Total EPA Tanks WinSim Tanks WinSim factor— factor- emission (TPY) (TPY) (lb/bbl) (lb/bbl) (lb/bbl) (lb/1000 (lb/yr) gal) VOC 41.04 204.02 0.36 1.81 2.18 51.9048 - Benzene 0.082 0.0064 0.0007 0.0064 0.0071 0.1690 1597.5 Toluene 0.078 0.565 0.0007 0.0050 0.0057 0.1357 1282.5 Ethylbenzene 0.0043 0.034 0.00004 0.0003 0.00034 0.0081 76.5 Xylenes 0.0225 0.176 0.0002 0.00157 0.00178 0.0424 400.5 n-hexane 1.12 6.26 0.010 0.056 0.066 1.5714 14850 2,2,4-TMP 0.029 _ 0.179 0.0003 0.0016 _ 0.0018 0.0429 405 Page 8 AIRS Point 002 Truck Condensate Loadout Units Basis S 0.6 Submerged loading: dedicated normal service P 6.9 Psia Based on EPA TANKs run M 62 Lb/lb-mole Based on EPA TANKs run T 520 Deg R Based on EPA TANKs run L 6.15 Lb/10^3 gal This value is used to calculate annual emissions 0.258 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 6.151b/10^3 gal 2.58E-01 lb/bbl Annual requested Throughput 9450000ga1/yr Annual requested VOC emissions 581221b/yr 29.06tpy HAP emissions were calculated using HAP weight%from the Cougar B02-67-1HN low pressure separator extended condensate analysis sampled June 6, 2014. Component Component wt% Uncontrolled (Ib/yr) Emission factor Emission factor (lb/bbl) (lb/1000 gal) Benzene 0.813 473 0.0021 0.0500 Toluene 2.735 1590 0.0071 0.1683 Ethylbenzene 0.459 267 0.0012 0.0283 Xylenes 3.023 1757 0.0078 0.1859 n-hexane 6.713 3902 0.0173 0.4129 2,2,4-TMP 0.487 283 0.0013 0.0299 AIRS Point 003 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, Larimer and Weld Garfield, Mesa, Rio Blanco and Moffat 4.2381 0.09¢2 0.2381 Remainder of Colorado 6.2381 0.1667 0.5238 AIRS Point 004 Fugitive VOC Leak Emissions A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY(permit threshold). Page 9 AIRS Point 005 RICE A permit will be issued because the uncontrolled CO emissions are greater than 5 TPY(permit threshold). AIRS Point 006 RICE A permit will be issued because the uncontrolled CO emissions are greater than 5 TPY(permit threshold). Page 10 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) Reason for APEN Submittal(Check all that apply) _JUL 2520 4 AIRS ID#1:1? ? —11-1.30C_—W l O APEN update only° O New or previously unreported battery O Modification to existing source5 ❑ Previously grandfathered battery ❑ Registration for coverage under general permit no.GPO l' 51:1. El Synthetic minor facility cancellation request for individual permits: ® Located in the 8-hr Ozone Control Area3 0 Application for or Modification of an individual permit ❑ Registered under general permit no.GP0I O Administrative permit amendment ElPermitted under individual permit: mug/21-'O O Other: For individual permit applications,check if you wants: O A copy of the preliminary analysis conducted by the Division ®To review a draft of the permit prior to issuance Company Name9: Noble Energy,Inc OGCC Operator if: 100322 Mailing Address'9: 1625 Broadway Suite 2200 mputney@nobleenergyinc City: Denver State: CO Zip: 80202 E-mail: corn Contact Name: Mike Putney Phone: (303)2284385 Fax: (303)228-4286 Tank Battery Name'I: Cougar 802-67-1HN,68-IHN,69-IHN Battery Number of tanks: 9 Location'?(QQ Sec.Twp.Range.): NWNW SEC2 T5N R64W County: Weld Total tank capacity[bbl]: 2,700 Calendar year for which"Actual"data applies13: 2014 Year(s)tank(s)were placed in service1°: 2014 Control Description 5: FLARE(Vapor Combustors) Control Efficiency's: 95% Condensate Throughput°[bbliyear] Requested's: 225,000 Maximum for PTE calculation 9: 225,000 Actual20: While Controls Operational' Other equipment at facility22: Comments: Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting art individual permit ❑Check if the Division is to calculate emissions. ®Check if site-specific emission factors provided to calculate emissions23. Emission Factor Battery Requested EmissionsIs Actual Emissions20 Pollutant° [lb/bbl] PTE25 Uncontrolled26 Controlled2' Uncontrolled26 Controlled2' VOC[tons/year] 2.18 245.0 245.0 12.25 NOx[tons/year] CO[tons/year] Benzene[lbs/year] 0.0071 1597.5 1597.5 79.9 n-Hexane[lbs/year] 0.066 14850 14850 7423 Wells serviced by this tank or tank battery2s AN#: 05-123-36406 Name: Cougar B02-67-1HN ®Newly Reported Well API#: 05-123-36407 Name: Cougar B02-68-IFIN 0 Newly Reported Well API#: 05-123-36405 Name: Cougar B02-69-IHN 0 Newly Reported Well API#: Name: O Newly Reported Well API#: Name O Newly Reported Well API#: Name: O Newly Reported Well API#: Name: O Newly Reported Well API#: Name: O Newly Reported Well 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 GP I,I further certify that this source is and will be operated in full comp�liyan� ceth each copditigp of general permit GPI. '_/ �i'1 CC it 7711-,-',7 07/24/2014 Signature of Legally Authorized Pers 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-B 1 (303)692-3150 $250 General Permit fee for each new GP 4300 Cherry Creek Drive South 315160 registration to: Denver,CO 80246-1530 FORM APCD-205 Page 1 of 2 COUGAR B02 MEN COND TANK BATTERY e o .ft0 ,�1 " O O 0 0 0 ° E CD L "' 0 .�` .� .� 0 a g mat) t_ = c tQ6 T �_ �_ .C ^G .C E ,. O ,---. 01 M M F C ! O O O O O = p, N N N O 0 O o 0 0 O O O i .. 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