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Home My WebLink About20152715.tiff A c0PHE COLORADO co -Is Department of Public Health Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 O St PO Box 758 RECEIVED Greeley, CO 80632 AUG 0 7 2015 August 3, 2015 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On August 5, 2015, the Air Pollution Control Division will begin a 30-day public notice period for Noble Energy, Inc - Cutthroat, Brook, Rainbow LC28 Econode. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure -pub(,u., P,v1 CO 8 /lb 2015-2715 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe u, John W. Hickenlooper, Governor Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer h. , ,� *F` CDPHE ` Air Pollution Control Division CONotice of a Proposed Project or Activity Warranting Public Comment Website Title: Noble Energy, Inc - Cutthroat, Brook, Rainbow LC28 Econode - Weld County Notice Period Begins: August 5, 2015 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Noble Energy, Inc Facility: Cutthroat, Brook, Rainbow LC28 Econode Oil and gas exploration and production facility SESW Section 28, T9N, R59W Weld County The proposed project or activity is as follows: Oil and gas exploration and production facility including reciprocating internal combustion engines, flares, truck loadout, produced water tanks and condensate tanks. 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 15WE0495 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 1 I AI „n.,. STATE OF COLORADO of coz0 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT y� o AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 *, ,876 CONSTRUCTION PERMIT PERMIT NO: 1 5YY E0495 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 Cutthroat, Brook, Rainbow LC28 Econode, located in SESW Section 28, T9N, R59W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point One (1) Cummins, Model GTA855E, Serial Number 99800048, natural gas-fired, turbo-charged, 4SRB reciprocating internal combustion engine, site rated at 256 GEN1A 007 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 primary and/or peaking power. One (1) Cummins, Model GTA855E, Serial Number 99800189, natural gas-fired, turbo-charged, 4SRB reciprocating internal combustion engine, site rated at 256 GEN3 008 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 primary and/or peaking power. Flare 009 Open flare to control LP separator vapors when the VRU shuts down. Truck Loadout 010 Truck loadout of condensate. Emissions are controlled. One (12) above ground 500 bbl atmospheric produced water Produced 011 storage tanks. Emissions from these tanks are controlled by Water an enclosed flare with a minimum destruction efficiency of 95%. AIRS ID: 123/9DAC Page 1 of 24 NGEngine Version 2014-1 Co do e p e o 'Public Health and Environment Air Pollution Control Division Facility AIRS Description Equipment ID Point Thirty-two (32) above ground 750 bbl atmospheric Condensate condensate storage tanks. Emissions from these tanks are Tank Battery 012 controlled by an enclosed flare with a minimum destruction efficiency of 95%. VRT VOC Six (6) enclosed flares used as backup to control VRT Burners 013 vapors when the VRT shuts down. Points 007 and 008: These engines may be replaced with another engine in accordance with the temporary engine replacement provision or with another Cummins GTA855E engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO 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 of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at https://www.colorado.dov/pacific/cdphe/other-air- permitting-notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation 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) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. Points 009 and 013: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. AIRS ID: 123/9DAC Page 2 of 24 do p e o Public Health and Environment Air Pollution Control Division • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, III.E.) 6. Points 009 and 013: Within one hundred eighty (180) days after issuance of this permit, the operator shall install a flow meter to monitor and record volumetric flow rate of natural gas flared from the low pressure separators and vapor recovery towers. The operator shall use the gas flow rate listed in the application for actual flow rate, assuming 5% downtime, until the flow meter is installed, not to exceed one hundred and eighty (180) days after issuance of this permit. 7. 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 8. 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 x GEN1A 007 2.5 1.7 4.9 Point GEN3 008 2.5 1.7 4.9 Point Flare 009 0.3 3.6 0.7 Point Truck Loadout 010 --- 10.2 --- Point Produced 011 --- 4.9 --- Point Water Condensate 012 3.0 38.3 7.3 Point Tank Battery VRT VOC 013 0.1 1.1 0.3 Point Burners See "Notes to Permit Holder"for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. AIRS ID: 123/9DAC Page 3 of 24 IDCo ido e?p- e o Public Health and Environment Air Pollution Control Division ll 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. 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 Control Device Pollutants Equipment ID Point Controlled GEN1A 007 Non-selective catalytic reduction system and NOx and CO air/fuel ratio controller GEN3 008 Non-selective catalytic reduction system and NOx and CO air/fuel ratio controller Flare 009 Flare VOC and HAPS Truck 010 Enclosed flare VOC and HAPS Loadout Produced 011 Enclosed flare VOC and HAPS Water • Condensate 012 Four(4) enclosed flares VOC and HAPS Tank Battery VRT VOC 013 Six(6) enclosed flares VOC and HAPS Burners 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 Process Parameter Annual Limit Equipment ID Point GEN1A 007 Consumption of natural gas as a fuel 14.62 MMscf/yr GEN3 008 Consumption of natural gas as a fuel 14.62 MMscf/yr Flare 009 Natural gas flaring 2.67 MMSCF/yr Truck 010 Condensate Loading 1,400,000 BBUyr Loadout AIRS ID: 123/9DAC Page 4 of 24 Col do p e o Public Health and Environment Air Pollution Control Division Produced 011 Produced water throughput 750,000 BBUyr Water Condensate 012 Condensate throughput 1,400,000 BBUyr Tank Battery VRT VOC 013 Consumption of natural gas as a fuel 0.69 MMscf/yr Burners 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 three years. 12. Points 009 and 013: Upon installation of a flow meter, the owner or operator shall monitor and record the volumetric flowrate of natural gas vented form all low pressure separators and VRTs during VRU downtime using a flow meter. The flow meter shall measure flowrate and record total volumetric flow vented to the flares from all low- pressure separators and VRTs during VRU downtime. The owner or operator shall use monthly throughput records to demonstrate compliance with the limits specified and to calculate emissions as described in this permit. 13. Point 010: Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E). STATE AND FEDERAL REGULATORY REQUIREMENTS 14. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 15. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section I I.A.1. &4.) 16. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 17. Point 010: 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): AIRS ID: 123/9DAC Page 5 of 24 Co ido P;: p, e o Public Health and Environment Air Pollution Control Division 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 17 (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. 18. Point 010: 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. 19. Point 012: 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. 20. Point 012: The flare(s) covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). These requirements include, but are not limited to: XVII.B.2.b If a 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 combustion device, or by other means approved by the Division, determine whether it is operating properly. XVII.B.2.d Auto-igniters: All combustion devices used to control emissions of hydrocarbons must be equipped with and operate an auto-igniter as follows: XVII.B.2.d.(i) All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto-igniter upon installation of the combustion device. 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. 21. Points 011 and 012: 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: AIRS ID: 123/9DAC Page 6 of 24 Col do p e o Public Health and Environment Air Pollution Control Division 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)(a) Control requirements of Section XVII.C.1.b. must be achieved within ninety (90) days of the date that the storage tank commences operation. 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 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; XVII.C.1.d.(iv) Visual inspection of the air pollution control 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 AIRS ID: 123/9DAC Page 7 of 24 IICo > do r p e o Public Health and Environment ��; Air Pollution Control Division 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)(a) A storage tank constructed on or after May 1, 2014, must comply with the requirements of Section XVII.C.2.a. by the date the storage tank commences operation. The storage tank must comply with Section XVII.C.2.b. and implement the approved instrument monitoring method inspections within ninety (90) days of the date that the storage tank commences operation. 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 > 50 Monthly January 1, 2015 AIRS ID: 123/9DAC Page 8 of 24 Col do p e,;, o Public Health and Environment Air Pollution Control Division 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. XVII.C.3.f. A list of equipment associated with the storage tank 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. 22. Point 013: The separator covered by this permit is subject to Regulation 7, Section XVII.G. (State Only). On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the date of first production by air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. OPERATING & MAINTENANCE REQUIREMENTS 23. 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.) AIRS ID: 123/9DAC Page 9 of 24 Co do D e o Public Health and Environment a,. Air Pollution Control Division 24. Point 010: The owner or operator of a loadout to control emissions shall: a. Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. d. Operate all recovery and disposal equipment at a back pressure less than the pressure relief valve setting of transport vehicles. e. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. f. Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. g. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 25. Points 007 and 008: A source initial compliance test shall be conducted on emissions points 007 and 008 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emission limits in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. Volatile Organic Compounds using EPA approved methods. 26. Point 009: The owner or operator shall demonstrate compliance with opacity standards using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section II.A.5). 27. Point 012: 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 AIRS ID: 123/9DAC Page 10 of 24 Co do p e o Public Health and Environment Air Pollution Control Division greater than or equal to one (1) minute in any fifteen (15) minute period during normal operation. (Reference: Regulation No. 7 Section XVII.All) Periodic Testing Requirements 28. Points 007 and 008: These engines are subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. 29. Point 009: 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. 30. Point 012: 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.All) ADDITIONAL REQUIREMENTS 31. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or 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 007 and 008: 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 AIRS ID: 123/9DAC Page 11 of 24 Co do � p e o Public Health and Environment } Air Pollution Control Division 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. 32. This source is subject to the provisions of Regulation No. 3, Part C, Operating Permits (Title V of the 1990 Federal Clean Air Act Amendments). The provisions of this construction permit must be incorporated into the Operating Permit. The application for the modification to the Operating Permit is due within one year of the issuance of this permit. 33. 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 34. 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 P q and the submittal of a revised APEN and the required fee. 35. 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. 36. 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. 37. 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. 38. 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 AIRS ID: 123/9DAC Page 12 of 24 Col -do p e . o Public Health and Environment Air Pollution Control Division 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. 39. 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. 40. 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 synthetic minor facility consisting RICE, flares, truck loadout, produced water tanks and condensate tanks. AIRS ID: 123/9DAC Page 13 of 24 Co Ado • p e 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: https://www.colorado.gov/pacific/cdphe/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 Are the Controlled AIRS Pollutant CAS# BIN Emission emissions Emission Point Rate reportable? Rate (Ib/yr) (Ib/yr) Formaldehyde 50000 A 401 Yes 401 Methanol 67561 C 60 No 60 Acetaldehyde 75070 A 55 No 55 007 Acrolein 107028 A 51 No 51 Benzene 71432 A 31 No 31 1,3-Butadiene 106990 A 13 No 13 Toluene 108883 C 11 No 11 Formaldehyde 50000 A 401 Yes 401 Methanol 67561 C 60 No 60 Acetaldehyde 75070 A 55 No 55 008 Acrolein 107028 A 51 No 51 Benzene 71432 A 31 No 31 1,3-Butadiene 106990 A 13 No 13 Toluene 108883 C 11 No 11 Benzene 71432 A 340 Yes 17 009 Toluene 108883 C 603 Yes 30 Ethylbenzene 100414 C 23 No 1 AIRS ID: 123/9DAC Page 14 of 24 Col. do p e o Public Health and Environment Air Pollution Control Division Xylenes 1130207 C 212 No 11 n-Hexane 110543 C 2016 Yes 101 2,2,4-TMP 540841 C 222 No 11 Benzene 71432 A 676 Yes 34 Toluene 108883 C 992 Yes 50 Ethylbenzene 100414 C 30 No 2 010 Xylenes 1130207 C 276 Yes 14 n-Hexane 110543 C 3886 Yes 194 2,2,4-TMP 540841 C 367 Yes 18 Benzene 71432 A 5250 Yes 263 011 n-Hexane 110543 C 16500 Yes 825 Benzene 71432 A 2550 Yes 128 Toluene 108883 C 3741 Yes 187 Ethylbenzene 100414 C 115 No 6 012 Xylenes 1130207 C 1041 Yes 52 n-Hexane 110543 C 14657 Yes 733 2,2,4-TMP 540841 C 700 Yes 35 Benzene 71432 A 68 No 3 Toluene 108883 C 100 No 5 Ethylbenzene 100414 C 3 No 0 013 Xylenes 1130207 C 28 No 1 n-Hexane 110543 C 390 Yes 20 2,2,4-TMP 540841 C 37 No 2 5) The emission levels contained in this permit are based on the following emission factors: Points 007 and 008: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.0613 12.10 0.2530 1.00 CO 0.7337 2.90 0.5060 2.00 VOC 0.1771 0.70 0.1771 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: 123/9DAC Page 15 of 24 al'_ Co do D� e o Pu Environment Airblic PollutionHealth Controland Division Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8714 Btu/hp-hr, a site-rated horsepower value of 256, and a fuel heat value of 1337 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC NSPS JJJJ NSPS JJJJ 50000 Formaldehyde AP-42 AP-42 Point 009: Weight Emission Emission CAS# Pollutant Fraction of Factors Factors Source Gas(%) Uncontrolled Controlled VOC 35.86 53.6717 2.6836 AP-42 lb/Mscf lb/Mscf NOx 0.2249 lb/Mscf 0.0112 AP-42 lb/Mscf CO 0.5246 lb/Mscf 0.0262 Engineering lb/Mscf Calculation 71432 Benzene 0.135 0.12741b/Mscf 0.0064 Engineering lb/Mscf Calculation 108883 Toluene 0.0239 0.2261 lb/Mscf 0.0113 Engineering lb/Mscf Calculation 100414 Ethylbenzene 0 0.0084 lb/Mscf 0.004 lb/Mscf Engineering Calculation 1330207 Xylenes 0.081 0.0794 lb/Mscf 0.0040 Engineering lb/Mscf Calculation 110543 n-hexane 0.798 0.0831 lb/Mscf 0.0042 Engineering lb/Mscf Calculation Note: The uncontrolled VOC and HAP emissions for this point were calculated using the average of 5 gas samples. All were sampled on December 19, 2014. Sample names are Cutthroat LC28-73HB, Cutthroat LC28-78HNB, Rainbow LC28-73-1H NA, Rainbow LC28-74-1H NA and Brook LC28-74-1AH NC. The controlled VOC and HAP emissions factors for point 009 are based on the flare control efficiency of 95%. Point 010: Emission Factors - Emission Factors—Controlled Uncontrolled CAS Pollutant lb/BBL loaded Source Lb/BBL loaded Source VOC 0.2897 AP-42 0.0145 AP-42 71432 Benzene 0.0005 Engineering 0.00003 Engineering calculation calculation 108883 Toluene 0.0007 Engineering 0.00004 Engineering calculation calculation 1130207 Xylenes 0.0002 Engineering 0.00001 Engineering calculation calculation 110543 n-Hexane 0.0028 Engineering 0.00014 Engineering calculation calculation 540841 2,2,4-TMP 0.0003 Engineering 0.00002 Engineering calculation calculation AIRS ID: 123/9DAC Page 16 of 24 Col do ,p;4R o Public Health and Environment �K Air Pollution Control Division 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*M/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 7.881 psia M (vapor molecular weight) = 60 lb/lb-mol T (temperature of liquid loaded) = 512.45 °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 011: 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 011 are based on the enclosed flare control efficiency of 95%. Point 012: Emission Factors Emission Factors Uncontrolled Controlled CAS# Pollutant lb/1000 gal lb/1000 gal Source Condensate Condensate Throughput Throughput VOC 26.0167 1.3008 Engineering Calculation NOx 0.1054 0.0053 Engineering Calculation CO 0.2483 0.0124 Engineering Calculation 71432 Benzene 0.0432 0.0022 Engineering Calculation 108883 Toluene 0.0636 0.0032 Engineering Calculation 100414 Ethylbenzene 0.0020 0.0001 Engineering Calculation 1330207 Xylene 0.0177 0.0009 Engineering Calculation 110543 n-Hexane 0.2491 0.0125 Engineering Calculation 540841 2,2,4-TMP 0.0127 0.0006 Engineering Calculation Note: The controlled emissions factors for point 012 are based on the enclosed flare control efficiency of 95%. AIRS ID: 123/9DAC Page 17 of 24 : ID + Co do e p . e o Public Health and Environment Air Pollution Control Division Point 013: Emission Factors Emission Factors Uncontrolled Controlled CAS# Pollutant Ib/Mscf Ib/Mscf Source Condensate Condensate Throughput Throughput Engineering VOC 53.6717 2.6836 Calculation Engineering NOx 0.2907 0.0145 Calculation Engineering CO 0.8720 0.0436 Calculation 71432 Benzene 0.1274 0.0064 Calculation Engineering Calculation 108883 Toluene 0.2261 0.0113 Engineering Calculation 100414 Ethylbenzene 0.0084 0.0004 Engineering Calculation 1330207 Xylene 0.0794 0.0040 CaIEngineeringuli Calculation 110543 n-Hexane 0.0831 0.0042 Engineering Calculation Note: The controlled emissions factors for point 013 are based on the enclosed flare control efficiency of 95%. 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 007 and 008: These engines are subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting — effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf 8) Points 007 and 008: 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/fr18ja08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html 9) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: NOx, CO, VOC, n-hexane, total HAPS PSD Synthetic Minor Source of: VOC AIRS ID: 123/9DAC Page 18 of 24 Col- do -p rte" o Public Health and Environment Air Pollution Control Division MACT ZZZZ Area Source Requirements: Applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX 11) 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-self-certification AIRS ID: 123/9DAC Page 19 of 24 IICo do a p � e o Public Health and Environment ' Air Pollution Control Division ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2.Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit(including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5)years and made available to the Division upon request. The owner or operator shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9DAC Page 20 of 24 Col. -do p e o 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: https://www.coloredo.gov/pacific/sites/default/files/AP Portable-Analyzer-Monitoring-Protocol.pdf Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. AIRS ID: 123/9DAC Page 21 of 24 Co A do pp e o Public Health and Environment Air Pollution Control Division For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology(RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/9DAC Page 22 of 24 Col do Jp !i! !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, § 1.8 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting AIRS ID: 123/9DAC Page 23 of 24 Co ,ado •� p e o Public Health and Environment Air Pollution Control Division requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9DAC Page 24 of 24 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Noble Energy, Inc. Permit Number: 15WE0495 Cutthroat, Brook, Rainbow LC28 Econode Source Location: SESW Section 28,T9N, R59W,Weld County (attainment) Point 007: 4SRB RICE Point 008: 4SRB RICE Point 009: Open flare Equipment Description: Point 010: truck loadout Point 011: (12) 500 BBL above ground atmospheric produced water storage tanks. Point 012: (32) 750 BBL above ground atmospheric condensate tanks Point 013: (6) enclosed flares to control VRT vapors when equipment shuts down AIRS ID: 123-9DAC Date: June 25, 2015 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? 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? Yes X 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 Information Request letter to the source? February 26, 2015. I received On what date was this application complete? modified APENS for several points via email on 7/1/2015. Section 4—Source Description AIRS Point Equipment Description One(1) Cummins, Model GTA855E, Serial Number 99800048, natural gas-fired, turbo-charged, 4SRB reciprocating internal combustion engine, site rated at 256 007 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 primary and/or peaking power. Page 1 One(1) Cummins, Model GTA855E, Serial Number 99800189, natural gas-fired, turbo-charged, 4SRB reciprocating internal combustion engine,site rated at 256 008 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 primary and/or peaking power.- 009 Open flare to control LP separator vapors when the VRU shuts down. 010 Truck loadout of condensate. One(12) above ground 500 bbl atmospheric produced water storage tanks. 011 Emissions from these tanks are controlled by an enclosed flare with a minimum destruction efficiency of 95%. Thirty-two (32) above ground 750 bbl atmospheric condensate storage tanks. 012 Emissions from these tanks are controlled by an enclosed flare with a minimum destruction efficiency of 95%. 013 Six(6) enclosed flares used as backup to control VRT vapors when the VRT shuts down. Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria x Yes No pollutant? If"yes", for what pollutant? PM10 CO X Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B, Section III.D.2) 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 010: Is this source located at an oil and gas X Yes No exploration site? Point 010: 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 010: Is this source located at a facility that is considered a major source of hazardous air pollutant Yes X No (HAP) emissions? Point 010: Will this equipment be operated in any Yes X No NAAQS nonattainment area? Point 010: Does this source load gasoline into Yes X No transport vehicles? Point 011: 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 011: Are these produced water tanks located at a commercial facility that accepts oil production Yes X No wastewater for processing? Point 011: 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 Page 2 NOx, CO: Manufacturer 007 VOC: NSPS JJJJ limits HAPS: AP-42 NOx, CO: Manufacturer 008 VOC: NSPS JJJJ limits HAPS: AP-42 009 Site-specific using VOC weight fraction (Refer to Section 14 for calculations) AP-42: Chapter 5.2, Equation 1 L = 12.46*S*P*M/T 010 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] 011 CDPHE Emission Factors (PS Memo 09-02) 012 Site-specific using HYSYS/AP-42. See calculations in Section 14. 013 Site-specific using VOC weight fraction (Refer to Section 14 for calculations) Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/Throughput/Production 007 14.62 MMSCF/yr 008 14.62 MMSCF/yr 009 2.67 MMSCF/yr 010 1,400,000 BBL per year condensate loaded 011 900,000 BBL per year(750,000 x 1.2) 012 1,680,000 BBL per year(1,400,000 x 1.2) 013 0.69 MMscf/yr Basis for Permitted Emissions(Permit Limits] AIRS Point Process Consumption/Throughput/Production 007 14.62 MMSCF/yr 008 14.62 MMSCF/yr 009 2.67 MMSCF/yr 010 1,400,000 BBL per year condensate loaded 011 750,000 BBL per year 012 1,400,000 BBL per year 013 0.69 MMscf/yr Does this facility use control devices? X Yes No AIRS Point Process Control Device Description % Reduction Granted 007 01 NSCR and AFCR NOx: 91.7%; CO: 31% 008 01 NSCR and AFCR NOx: 91.7%; CO: 31% 009 01 Open flare 95 Page 3 010 01 Enclosed flare 95 011 01 Enclosed flare 95 012 01 Enclosed flares (4) 95 013 01 Enclosed flares (6) 95 Section 6—Emission Summary (tons per year) Total Point NO,, VOC CO SOx PM10 Single HAP otP HAP G5j 2 8.3 60.4 19.7 126.0 --- --- (formaldehyde) 9.5 ( 0.2 007 29.9 1.7 7.2 --- --- (formaldehyde) 0.3 0.2 008 29.9 1.7 7.2 --- --- (formaldehyde) 0.3 PTE: 009 0.3 71.6 0.7 --- --- 1.0 (n-hexane) 1.6 010 --- 202.8 --- --- --- 1.9 (n-hexane) 3.1 011 --- 117.9 --- --- --- 9.9 (n-hexane) 13.1 012 3.0 764.9 7.3 --- --- 7.3 (n-hexane) 11.4 013 0.1 21.2 0.3 --- --- 0.2 (n-hexane) 0.3 8.3 G(5;2 60.4 19.7 126.0 --- --- (formaldehyde)0.2 9.5 007 29.9 1.7 7.2 --- --- (formaldehyde) 0.3 Uncontrolled point 008 29.9 1.7 7.2 --- --- 0.2 0.3 source emission rate: (formaldehyde) 009 0.3 71.6 0.7 --- --- 1.0 (n-hexane) 1.6 010 --- 202.8 --- --- --- 1.9 (n-hexane) 3.1 011 --- 98.3 --- --- --- 8.3 (n-hexane) 10.9 012 3.0 764.9 7.3 --- --- 7.3 (n-hexane) 11.4 013 0.1 21.2 0.3 --- --- 0.2 (n-hexane) 0.3 TOTAL(TPY) 123.6 1181.9 148.7 --- --- 18.7 (n- 37.4 hexane) G5;2 2.3 15.4 12.6 30.3 --- --- (formaldehyde) 3.6 ( 0.2 007 2.5 1.7 4.9 --- --- (formaldehyde) 0.3 008 2.5 1.7 4.9 --- --- 0'2 0.3 (formaldehyde) Controlled point 009 0.3 3.6 0.7 --- --- 0.1 (n-hexane) 0.1 source emission rate: 010 --- 10.2 --- --- --- 0.2 (n-hexane) 0.2 011 . --- 4.9 --- --- --- 0.4 (n-hexane) 0.5 012 3.0 38.3 7.3 --- --- 0.4 (n-hexane) 0.6 013 0.1 1.1 0.3 --- --- 0.01 (n- 0.01 hexane) INSIGNIFICANTS 4.6 1.7 3.9 --- (TPY) --- --- --- TOTAL PERMITTED 23.8 73.1 48.4 --- --- 1.1 (n-hexane) 5.6 (TPY) Page 4 Section 7- Non-Criteria/ Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS # BIN Emission Rate emissions (Ib/yr) reportable? Rate(Ib/yr) Point 007 Formaldehyde 50000 A 401 Yes 401 Acetaldehyde 75070 A 55 No 55 Acrolein 107028 A 51 No 51 Benzene 71432 A 31 No 31 Toluene 108883 C 11 No 11 Methanol 67561 C 60 No 60 Point 008 Formaldehyde 50000 A 401 Yes 401 Acetaldehyde 75070 A 55 No 55 Acrolein 107028 A 51 No 51 Benzene 71432 A 31 No 31 Toluene 108883 C 11 No 11 Methanol 67561 C 60 No 60 Point 009 Benzene 71432 A 340 Yes 17 Toluene 108883 C 603 Yes 30 Ethylbenzene 100414 C 23 No 1 Xylenes 1130207 C 212 No 11 n-Hexane 110543 C 2016 Yes 101 2,2,4-Trimethylpentane 540841 C 222 No 11 Point 010 Benzene 71432 A 676 Yes 34 Toluene 108883 C 992 Yes 50 Ethylbenzene 100414 C 30 No 2 Xylenes 1130207 C 276 Yes 14 n-Hexane 110543 C 3886 Yes 194 2,2,4-Trimethylpentane 540841 C 367 Yes 18 Point 011 Benzene 71432 A 5250 Yes 263 n-Hexane 110543 C 16500 Yes 825 Point 012 Benzene 71432 A 2550 Yes 128 Toluene 108883 C 3741 Yes 187 Ethyl benzene 100414 C 115 No 6 Page 5 Xylenes 1130207 C 1041 Yes 52 n-Hexane 110543 C 14657 Yes 733 2,2,4-Trimethylpentane 540841 C 700 Yes 35 Point 013 Benzene 71432 A 68 No 3 Toluene 108883 C 100 No 5 Ethylbenzene 100414 C 3 No 0 Xylenes 1130207 C 28 No 1 n-Hexane 110543 C 390 Yes 20 2,2,4-Trimethylpentane 540841 C 37 No 2 Note: Regulation 3, Part A, Section II.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 007 01 VOC Regulation No. 3, Part B., Section III.G.3 Stack test 008 01 VOC, Regulation No.3, Part B., Section III.G.3 Stack test HAPS 009 01 VOC, Regulation No. 1, Section II.A.5 EPA Method 9 HAPS 012 01 VOC, Regulation No. 7 Section XVII.All EPA Method 22 HAPS Section 9—Source Classification What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V X PSD NA NSR X MACT Is this a modification to an existing permit? Yes X No If"yes"what kind of modification? Minor Synthetic 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 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)? Page 6 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 007-013 A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 -Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2 Odor 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 007-013 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 3 APENs, Construction Permits, Operating Permits, PSD Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: 007-013 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 007-013 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.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. 010 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 submerged fill (0.6 saturation factor), therefore, RACT requirements are satisfied. Regulation 6-New Source Performance Standards NSPS JJJJ: the date of construction is the date it was ordered or reconstructed/modified. 007, 008 Points 007 and 008 were manufactured after the 7/1/2008 effective date and are therefore subject to NSPS JJJJ. 009, 010, None 013 NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. 012 Is this source greater than 19,800 gallons(471 bbl)? Yes Is this source subject to NSPS Kb? No WHY? The tanks are all located prior to custody transfer and therefore are not subject. NSPS OOOO: Tanks with the potential to emission equal to or greater than 6 TPY. Are uncontrolled VOC emissions greater than 6 TPY?Yes 011, 012 Are controlled emissions greater than 6 TPY?Yes Is the operator requesting a permitted limit less than 6 TPY? No Source is subject to NSPS OOOO requirements. Page 7 NSPS OOOO: Tanks with the potential to emission equal to or greater than 6 TPY. Are uncontrolled VOC emissions greater than 6 TPY?Yes 012 Are controlled emissions greater than 6 TPY?Yes Is the operator requesting a permitted limit less than 6 TPY?Yes Source is not subject to NSPS OOOO requirements. Regulation 7-Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is not subject to the emission control requirements for condensate 011, 012 tanks since it is located in an attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is not currently subject to this since actual uncontrolled emissions are greater than 6 tpy of VOC.) Regulation 8 Hazardous Air Pollutants 009, 011, None 013 007, 008 MACT ZZZZ: The date of construction is the first time the engine is installed at any location, therefore the engines are new sources for MACT 777Z applicability. 010, 012 MACT EEEE: Not subject because minor source of HAPs 012 MACT HH This source is not subject to MACT HH because it is not located at a major source of HAP. Section 13—Aerometric Information Retrieval System Coding Information Point Process Process Description Emission Pollutant/ Fugitive Emission Factor Control Factor CAS# (Y/N) Source (%) 0.7 g/hp-hr VOC No NSPS JJJJ -- 12.1 g/hp-hr NOx No Manufacturer 91.7 01 4SRB RICE 007 2.9 g/hp-hr CO No Manufacturer 31.0 0.0205 Formaldehyde/ No AP-42 lb/mmbtu 50000 SCC 20200253—4-cycle rich burn 0.7 g/hp-hr V0C No NSPS JJJJ 12.1 g/hp-hr N0x No Manufacturer 91.7 01 4SRB RICE 008 2.9 g/hp-hr CO No Manufacturer 31.0 0.0205 Formaldehyde No AP-42 -- Ib/mmbtu /50000 SCC 20200253—4-cycle rich burn 53.6717 V0C No Engineering 95 lb/Mscf Calculation 0.2249 Engineering lb/Mscf N0x No Calculation NA 0.5246 CO No Engineering NA lb/Mscf Calculation 0.1274 Benzene No Engineering 95 009 01 Flare lb/Mscf Calculation 0.2261 Toluene No Engineering 95 lb/Mscf Calculation 0.0084 Ethlybenzene No Engineering 95 lb/Mscf Calculation 0.0794 Engineering lb/Mscf Xylenes No Calculation 95 0.0831 n-hexane No Engineering 95 lb/Mscf Calculation Page 8 SCC 31000205-Flares 6.8980 VOC No AP-42 95 lb/1000 gal 0.0115 Benzene/ No AP 42 95 lb/1000 gal 71432 0.0169 Toluene/ No AP 42 95 lb/1000 gal 108883 01 Truck Condensate 0.0005 Ethylbenzene/ No AP 42 95 010 Loadout lb/1000 gal 100414 0.0047 Xylenes/ No AP 42 95 lb/1000 gal 1130207 0.0661 n-hexane/ No AP 42 95 lb/1000 gal 110543 0.0062 2,2,4-TMP/ No AP 42 95 lb/1000 gal 540841 SCC 40600132: Crude Oil: Submerged Loading (Normal Service) 6.2381 CDPHE PS lb/1000 gal VOC No Memo 09-02 95 throughput Produced Water 0.1667 Benzene/ CDPHE PS ' orage 01 St Tanks lb/1000 gal 71432 No Memo 09-02 95 011throughput 0.5238 n-hexane/ CDPHE PS lb/1000 gal 110543 No Memo 09-02 95 throughput SCC 40400315— Fixed Roof Tank, Produced Water,working+breathing+flashing losses 26.0167 Engineering lb/1000 gal VOC No Calculation 95 0.1054 Engineering lb/1000 gal NOx No Calculation NA 0.2483 Engineering lb/1000 gal CO No Calculation NA 0.0432 Benzene/ Engineering lb/1000 gal 71432 No Calculation 95 Condensate Storage 0.0636 Toluene/ Engineering 01 N°Tanks lb/1000 gal 108883 Calculation 012 95 0.0020 Ethylbenzene/ No Engineering 95 lb/1000 gal 100414 Calculation 0.0177 Xylenes/ No Engineering 95 lb/1000 gal 1130207 Calculation 0.2491 n-hexane/ Engineering lb/1000 gal 110543 No Calculation 95 0.0127 2,2,4-TMP/ No Engineering 95 lb/1000 gal 540841 Calculation SCC 40400301 — Fixed Roof Tank, Oil field storage of crude, breathing losses 53.6717 VOC No Engineering 95 I lb/Mscf Calculation 0.2907 Engineering lb/Mscf NOx No Calculation NA 0.8720 Engineering lb/Mscf CO No Calculation NA 0.1274 Benzene No Engineering 95 01 Flare lb/Mscf Calculation 013 0.2261 Toluene No Engineering 95 lb/Mscf Calculation 0.0084 Ethlybenzene No Engineering 95 lb/Mscf Calculation 0.0794 X lenes No Engineering y 95 lb/Mscf Calculation 0.0831 n-hexane No Engineering 95 lb/Mscf Calculation SCC 31000205-Flares Page 9 Section 14—Miscellaneous Application Notes AIRS Point 007 RICE Emissions were calculated using manufacturer(NOx and CO), NSPS JJJJ limits (VOC)and AP-42 (HAPs). Engine is controlled by a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. AIRS Point 008 RICE Emissions were calculated using manufacturer(NOx and CO), NSPS JJJJ limits(VOC) and AP-42 (HAPs). Engine is controlled by a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. AIRS Point 009 Flare Emission factor for VOC: VOC= 71.58*2000/2.66739 mmscf/yr= 53670.4419 lb/mmscf(Operator calculated 53.6717 lb/mcf) Emission factors for HAPS are: Benzene= (340 Ib/yr)/2.66739 mmscf/yr= 127.4654 lb/mmscf(Operator calculated 0.1274 lb/mcf) Toluene= (603 Ib/yr)/2.66739 mmscf/yr= 226.0637 lb/mmscf(Operator calculated 0.2261 lb/mcf) Ethylbenzene= (23 Ib/yr)/2.66739 mmscf/yr= 8.6227 lb/mmscf(Operator calculated 0.0084 lb/mcf) Xylenes= (212 Ib/yr)/2.66739 mmscf/yr= 79.4784 lb/mmscf(Operator calculated 0.0794 lb/mcf) n-hexane= (2016 Ib/yr)/2.66739 mmscf/yr= 755.7950 lb/mmscf(Operator calculated 0.7559 lb/mcf) 2,2,4-TMP= (222 Ib/yr)/2.66739 mmscf/yr= 83.2274 lb/mmscf(Operator calculated 0.0831 lb/mcf) Operator used CDPHE approved emission factors to calculated NOX and CO (based on VOC). I calculated a lb/mmscf emission factor to keep all emission factors consistent: NOX= 0.27 TPY*2000/2.66739 lb/mmscf=202.4451 lb/mmscf CO= 0.68 TPY*2000/2.66739 lb/mmscf= 509.8617 lb/mmscf Operator used HYSYS model to generate mass fraction composition for the"vapors to VRU/Combo." 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 rate/volume of gas processed MW= Molecular weight of gas= SG of gas*MW of air Xx = mass fraction of x in gas C = molar volume of ideal gas(379 scf/Ib-mol)at 60F and 1 atm See K:\PA\2015\15WE0495-009.CP1.xlsm for calculations Emissions generated from the flare are: Uncontrolled Total (Ib/yr) Controlled Total (Ib/yr) NOx 0.3 TPY 0.3 TPY VOC 71.6 TPY 3.6 TPY CO 0.7 TPY 0.7 TPY Benzene 340 17 Toluene 603 30 Ethylbenzene 23 1 Xylenes 212 11 n-hexane 2016 101 224-TMP 222 11 I am going to calculate a lb/1000 gal emission factor for NOx and CO: NOx= 0.3 TPY*2000/2.66739 mmscf/yr=224.939 lb/mmscf CO= 0.7 TPY*2000/2.66739 mmscf/yr= 524.8576 lb/mmscf Page 10 AIRS Point 010 Truck condensate Loadout Units Basis S 0.6 Submerged loading: dedicated normal service P 7.881 Psia Based on EPA TANKs run 60 60 Lb/lb-mole Based on EPA TANKs run T 512.45 Deg R Based on EPA TANKs run L 6.90 Lb/10^3 gal 2.897E-01 Lb/bbl This value is used to calculate annual emissions 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 6.90lb/10^3 gal 2.897E-01 lb/bbl Annual requested Throughput 58,800,000gal/yr Annual requested VOC emissions 405,6281b/yr Uncontrolled emissions 202.8TPY Controlled by an enclosed flare 10.14TPY Operator calculated HAP emissions based on tank flash emission speciation from the HYSYS model. The operator took the lbs/hr for each HAP from the flash Information from HYSYS, and divided it by the total lbs/hr VOC emissions. The lb/hr was taken from the HYSYS output labeled Material Stream: Flash. Total VOC emissions in lb/hr(subtracting out CO2, N, methane and ethane) is 89.6854 lb/yr. Component Mass Ratio (mass Uncontrolled Controlled Emission Emission flow flow/total emissions emissions factor factor (lb/hr) VOC) (Ib/yr) (Ib/yr) lb/bbl lb/1000 gal VOC --- --- 202.8 TPY 10.14 TPY 0.2897 6.8980 Benzene 0.1495 0.001667 676.14 33.81 0.00048 0.0115 Toluene 0.2193 0.002445 991.83 49.59 0.0007 0.0169 Ethylbenzene 0.0067 0.000075 30.30 1.52 0.00002 0.0005 Xylenes 0.0610 0.00068 275.88 13.79 0.000197 0.0047 n-hexane 0.8593 0.00958 3886.35 194.32 0.0028 0.0661 2,2,4-TMP 0.0812 0.00091 367.24 18.36 0.00026 0.0062 AIRS Point 011 Produced Water Storage Tanks A permit will be issued because the uncontrolled VOC emissions are greater than 5 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 0.0952 0.2381 Remainder of Colorado 6.2381 _0.1667 0.5238 _ Page 11 AIRS Point 012 Condensate Storage Tanks Operator used HYSYS(flash)and EPA tanks(working and breathing)to calculate emissions from the tanks. I did not see the EPA tanks model in the application so I emailed the operator on 6/25/15 requesting a copy. I received revised calculations on 7/1/2015. Operator provided some guidance regarding the new calculations: "At this facility I learned that the open flare controls the LP separator during VRU downtime, and there is a bank of 6 combustors that control emissions from the VRT during upset conditions. I revised the HYSYS run to include the emissions from the LP separator and VRT, which increased the emission factor for the condensate tanks. I have attached a revised APEN for the condensate tanks with the new emission factor[redlining purposes only], and with a revised throughput of 1,400,000 bbl/yr. I also included the combustion emissions on the tanks APEN, and attached the oil tanks burners combustion detail sheet. I have also attached the revised HYSYS run. Please be advised, that TANKS4.0.9d no longer runs on our computers. We perform the AP-42 calculations from TANKS4.0.9d using macro- embedded calculations within our HYSYS spreadsheet. The emissions and inputs are listed on the HYSYS excel spreadsheet." I checked and I was able to run Tanks4.0.9d on my computer, so with the information that was provided on their calculation spreadsheet(I had to estimate a few things), I ran a quick model. Tanks 4.0.9d calculated uncontrolled VOC emissions of 20,912.76 lb/yr or 10.46 TPY VOC. Looking at the operator's spreadsheet,they calculated uncontrolled VOC emissions of 2.6547 lb/hr or 11.63 TPY. There is about a 10%difference, but the operator's calculations are higher. I ran this just to see if what I calculated was something close to what they calculated or way off. I am comfortable using their calculations. HYSYS Flash calculations: Mass flow(lb/hr)*24hr/day*(liq vol flow @ standard condition) Mass flow(lb/hr)=Total overall phase—CO2-N-Methane-Ethane 125.2811-4.9764-0.6443-3.7403-26.2347=89.6854 lb/hr VOC/flash= 89.6854 lb 24 hr Day =0.5612 lb/bbl hr day 3835.62 bbl (matches operator's calculations). This equation is also used when calculating the emission factor for HAPs from the HYSYS flash gas output. Emissions and emission factors based on a throughput of 1,400,000 bbl/yr(when calculating W+B emissions, it was based on a 1 tank throughput of 43750 bbl/yr): Component Flash W+B Flash W+B Total Total Uncontrolled Controlled (lb/hr) (lb/hr) E.F. E.F. E.F. E.F. emissions/ emissions/ (lb/bbl) (lb/bbl) (lb/bbl) (lb/1000 Operator Operator gal) calculation calculation (lb/yr) (Ib/yr) VOC 89.6854 2.6547 0.5612 0.5315 1.0927 26.0167 764.9 TPY 38.2 TPY Benzene 0.1495 0.0044 0.000934 0.000881 0.001815 0.0432 2541 /2550 127/ 128 Toluene 0.2193 0.0065 0.001372 0.001301 0.002673 0.0636 3742/3741 187/ 187 Ethylbenzene 0.0067 0.0002 0.000042 0.00004 0.000082 0.0020 115/ 115 6/6 Xylenes 0.0610 0.0018 0.000382 0.000360 0.000742 0.0177 1039/ 1041 52/52 n-hexane 0.8593 0.0254 0.005377 0.005086 0.010463 0.2491 14648/14657 732/733 2,2,4-TMP 0.0812 0.0024 0.000508 0.000481 0.000532 0.0127 745/700 37/35 There's a little discrepancy between what I calculated and what the operator calculated. I believe that is due to rounding in the calculations. I am comfortable using what the operator calculated in the permit. Emission factors adjusted slightly with the operator calculations: Benzene=2250/1400000=0.001821 lb/bbl*1000/42=0.0434 lb/1000 gal Toluene=3741/1400000=0.002672 lb/bbl*1000/42=0.0636 lb/1000 gal Ethylbenzene= 115/1400000=0.000082 lb/bbl*1000/42=0.0020 lb/1000 gal Xylenes= 1041/1400000=0.000743 lb/bbl*1000/42=0.0177 lb/1000 gal n-hexane= 14657/1400000=0.010469 lb/bbl*1000/42 =0.2493 lb/1000 gal 2,2,4-TMP=700/1400000=0.0005 lb/bbl*1000/42=0.0119 lb/1000 gal NOx and CO emissions were also calculated from the enclosed flares(4) controlling this emission point. Emissions were calculated using state approved Ib/Ib-VOC ratio: NOx=(764.9 TPY)*0.0037=2.83 TPY(Operator calculated 3.1 TPY) CO =(764.9 TPY) *0.0094=7.19 TPY(Operator calculated 7.3 TPY) I am going to calculate a lb/1000 gal emission factor for NOx and CO: NOx=3.1 TPY*2000/1400000=0.004429 lb/bbl* 1000/42=0.1054 lb/1000 gal CO=7.3 TPY*2000/1400000=0.01043 lb/bbl* 1000/42=0.2483 lb/1000 gal Page 12 AIRS Point 013 Flares Emission factor for VOC: VOC= 21.2*2000/0.68808 mmscf/yr= 61330.0779 lb/mmscf(Operator calculated 61.60665 lb/mcf) Emission factors for HAPS are: Benzene= (68 Ib/yr)/0.68808 mmscf/yr= 98.8257 lb/mmscf(Operator calculated 0.09853 lb/mcf) Toluene= (100 Ib/yr)/0.68808 mmscf/yr= 145.3319 lb/mmscf(Operator calculated 0.14472 Ib/mcf) Ethylbenzene= (3 Ib/yr)/0.68808 mmscf/yr= 4.36 lb/mmscf(Operator calculated 0.00443 Ib/mcf) Xylenes= (28 Ib/yr) /0.68808 mmscf/yr=40.6929 lb/mmscf(Operator calculated 0.04034 lb/mcf) n-hexane= (390 lb/yr)/0.68808 mmscf/yr= 566.7946 lb/mmscf(Operator calculated 0.56672 lb/mcf) 2,2,4-TMP= (37 Ib/yr)/0.68808 mmscf/yr= 53.7728 lb/mmscf Operator used CDPHE approved emission factors to calculated NOX and CO (based on VOC). I calculated a lb/mmscf emission factor to keep all emission factors consistent: NOX= 0.13 TPY*2000/0.68808 lb/mmscf= 377.8630 lb/mmscf CO = 0.25 TPY*2000/0.68808 lb/mmscf= 726.6597 lb/mmscf Operator used HYSYS model to generate mass fraction composition for the"vapors to VRTVRU/Combo." 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 rate/volume of gas processed MW= Molecular weight of gas= SG of gas* MW of air Xx = mass fraction of x in gas C= molar volume of ideal gas(379 scf/lb-mol) at 60F and 1 atm See K:\PA\2015\15WE0495-013.CP1.xlsm for calculations Emissions generated from the flare are: Uncontrolled Total (lb/yr) Controlled Total (Ib/yr) NOx 0.1 TPY 0.1 TPY VOC 21.2 TPY 1.1 TPY CO 0.3 TPY 0.3 TPY Benzene 68 3 Toluene 100 5 Ethylbenzene 3 0 Xylenes 28 1 n-hexane 390 20 224-TMP 37 2 I am going to calculate a lb/1000 gal emission factor for NOx and CO: NOx = 0.1 TPY*2000/0.68808 mmscf/yr=290.6639 lb/mmscf CO= 0.3 TPY*2000/0.68808 mmscf/yr= 871.9916 lb/mmscf Page 13 1r^ o X W c co u O C. j c :n L o CO n 11, �' i -GJ .� G Z ' C., M M rte. '= C. :Jrq • T L < _a. L - c. .,_ C' _ [C]"+ 7 �.. 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Source Name: Cutthroat,Brook,Rainbow LC28 Econode Emissions Source AIRS ID2: N/A/ / j, - Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05-123-38852 CUTTHROAT LC28-75-1AHNB 05-123-38851 CUTTHROAT LC28-77HNB 05-123-38846 CUTTHROAT LC28-78HNB 05-123-38855 CUTTHROAT LC28-79HNB 05-123-38615 RAINBOW LC28-73-1HNA 05-123-38849 RAINBOW LC28-74-1HNA 05-123-38847 RAINBOW LC28-74HNA 05-123-38854 RAINBOW LC28-76-1BIINA 05-123-38848 RAINBOW LC28-78-1HNA 05-123-38853 RAINBOW LC28-79-1HNA - ❑ Footnotes: 1 Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 APEN-Addendum Condensate Tanks Feb 2015 kes .7 a a) " 0 0 0 a3i E o n °• O o. 3 > Z z z = e° ° 0 00 w d ❑ anEn C.1 N C ICI .b a, t I. L -. 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U y fn 'raj o V 0 C 0 ._ - , x > N > 0 w a) h t a) a) o ..o •O �s L..x gv) v) w .cn 0 5. U a' o .o U p 1.! W e `° x U a°i aoi a c 0 a' o ,S I o o I a - - -° o I I y a O O OU N 0 .2 C) ) I - a °' e Q 'n O r ° a ° ao o, o Z > aa o T x E o ° 3 O G G) 2 Cq ° O .. ,6 O E a = H i C ^, �--I 7 .p o C mZ g o › ,, a! . U Ca o '- u o W W o ` Y ¢o " a ono ca w ❑ ❑ ▪ 3 a ; ® N -n_ , as V] cID CI) CID cn) • E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Forml CompanyEnergy,Name: Noble Inc. Source Name: Cutthroat,Brook,Rainbow LC28 Econode Emissions Source AIRS ID2: N/A/ / ,'f ?— Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05-123-38852 CUTTHROAT LC28-75-1AHNB 05-123-38851 CUTTHROAT LC28-77HNB 05-123-38846 CUTTHROAT LC28-78HNB 05-123-38855 CUTTHROAT LC28-79HNB 05-123-38615 RAINBOW LC28-73-1HNA 05-123-38849 RAINBOW LC28-74-11INA 05-123-38847 RAINBOW LC28-74HNA 05-123-38854 RAINBOW LC28-76-1BHNA 05-123-38848 RAINBOW LC28-78-1HNA 05-123-38853 RAINBOW LC28-79-1HNA Footnotes: 1 Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 APEN-Addendum Condensate Tanks Feb 2015 LO mo �1 C. T y 0._.r In d' h , o as T y 0 _. C p a C C y `� i G en e+1 rn ^ y L • F is u L. ▪ G ` .0 O. > as , o s. �� - - rCL >- C Q L +. • _ u O G i. 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