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Home My WebLink About20142205.tiff A CDPHE COLORADO CO tr, Department of Public .. Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150O St PO Box 758 Greeley, CO 80632 RECEIVED February 17, 2015 FEB 2 0 2015 WELL COUNTY COMMISSIONERS Dear Sir or Madam: On February 18, 2015, the Air Pollution Control Division will begin a 30-day public notice period for Bonanza Creek Energy Operating Company, LLC - State Antelope P-30 Production Facility. 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, f.awez . 7A.-25-1-4,4,) Clara Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure ?ubut, I�euieu.) CC•.7l � -a�5 .1A°) 4 aao ao �f O_g5 ;015- flew . 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303692-2000 www.colorado.govfcdphe of '., + \- John W. Hickenlooper, Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer - CDPHE Air Pollution Control Division Co i Notice of a Proposed Project or Activity Warranting Public ' Comment Website Title: Bonanza Creek Energy Operating Company, LLC - State Antelope P-30 Production Facility - Weld County Notice Period Begins: February 18, 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: Bonanza Creek Energy Operating Company, LLC Facility: State Antelope P-30 Production Facility Oil and gas exploration and production facility NENE Sec 30, T5N, R62W Weld County The proposed project or activity is as follows: The applicant proposes to operate a new oil and gas exploration and production facility. 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): • 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 14WE0197.CP2 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: Carissa Money 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 aitV COLORADO aeOLO vHaas:: IF STATE OF COLORADO oF Rm•LOR 1 • D • `T' e� •F P - C HEALTH AND ENVIRONMENT cods AIR POLLUTION CONTROL DIVISION F TELEPHONE: (303)692-3150 �+ y *187s* CONSTRUCTION PERMIT PERMIT NO: 1 4WE0 1 97 Issuance 2 DATE ISSUED: ISSUED TO: Bonanza Creek Energy Operating Company LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas exploration and production facility known as the State Antelope P-30 Production Facility, located in the NENE Section 30, Township 5N, Range 62W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Condensate Fifteen 500 bbl above ground atmospheric condensate storage Tanks 004 tanks controlled by nine enclosed flares. Each flare has a minimum control efficiency of 95%. Two(2)500 bbl above ground produced water storage tanks PW Tanks 005 and two (2)60 bbl concrete vaults for produced water.The 500 bbl storage tanks are controlled by nine enclosed flares. Each flare has a minimum control efficiency of 95%. Truck Condensate Loadout that is controlled by using Truck dedicated vapor balance service and nine enclosed flares. Loadout 006 Collection system is 70%efficient and each flare has a minimum control efficiency of 95%. FUG 007 Fugitive VOC equipment leaks One (1) pneumatic water transfer pump, rated at 600 scf/hr P-1 008 (Sandpiper, Model G1 F, Serial number 2091586). The pneumatic pump is controlled by nine enclosed flares. Each flare has a minimum control efficiency of 95%. One low-pressure separator controlled by nine enclosed flares Sep-1 009 during VRU downtime. Each flare has a minimum control efficiency of 95%. One emergency flare used to combust separator gas during FL-3 014 emergencies or when the pipeline is not available. Flare has a minimum control efficiency of 95%. The flare is not enclosed. AIRS ID: 123/9BDB Page 1 of 24 olor epa en li Environment it Pollutionealthand Control Division Facility AIRS Equipment Point Description ID One vapor recovery tower controlled by nine enclosed flares VRT-1 015 during VRU downtime. Each flare has a minimum control efficiency of 95%. One low-pressure separator controlled by nine enclosed flares Sep-2 016 during VRU downtime. Each flare has a minimum control efficiency of 95%. One low-pressure separator controlled by nine enclosed flares Sep-3 017 during VRU downtime. Each flare has a minimum control efficiency of 95%. One low-pressure separator controlled by nine enclosed flares Sep-4 018 during VRU downtime. Each flare has a minimum control efficiency of 95%. One low-pressure separator controlled by nine enclosed flares Sep-5 019 during VRU downtime. Each flare has a minimum control efficiency of 95%. Point 008: This pump may be replaced with another pump in accordance with the provisions of the Alternate Operating Scenario(AOS)in this permit. 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 sell), 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. AIRS Point 014: YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after commencement of operation, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. AIRS Point 014: The following information shall be provided to the Division within fifteen (15)days after commencement of operation. • 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.) 3. AIRS Point 014: Within one hundred and eighty days (180) after commencement of operation, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with AIRS ID: 123/9BDB Page 2 of 24 olor Depa en P li ealth and Environment it Pollution Control Division the condition a to e w' 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 4. AIRS Points 004 — 009, 015 — 019: YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, y submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 5. AIRS Points 004 — 009, 015 — 019: Within one hundred and eighty days (180) after issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 6. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, I I I.F.4.) 7. AIRS Points 009, 015-019: Within one hundred and eighty (180) days after issuance of this permit, the operator shall install a flow meter to monitor and record volumetric flowrate of natural gas vented from the low pressure separators and vapor recovery tower. The operator shall use the gas flow rate listed in the application for actual flow rate until the flow meter is installed, not to exceed one hundred and eighty (180) days after issuance of this permit. 8. 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.) 9. 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 10. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Emission Type Equipment ID Point NOx VOC CO Condensate 004 --- 3.2 --- Point Tanks PW Tanks 005 --- 2.3 --- Point AIRS ID: 123/9BDB Page 3 of 24 olor epa en P li ealth and Environment 'r Pollution Control Division Truck Loado 06 — -- Point FUG 007 24.4 Fugitive P-1 008 -- 2.6 1.3 Point Sep-1 009 — 2.7 -- Point FL-3 014 — 7.5 3.8 Point VRT-1 015 — 1.8 -- Point Sep-2 016 -- 1.7 -- Point Sep-3 017 — 1.6 — Point Sep-4 018 — 1.2 -- Point Sep-5 019 — 1.6 -- Point See "Notes to Permit Holder"(or information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 11. AIRS Point 007: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent extended gas analysis, as required in the Compliance Testing and Sampling section of this permit.The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. 12. 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 Condensate 004 Enclosed Flare VOC Tanks PW Tanks 005 Enclosed Flare (500 bbl tanks only) VOC Truck Loadout 006 Vapor balance and Enclosed Flare VOC AIRS ID: 123/9BDB Page 4 of 24 olor epa en P:;.li "' ealth and Environment it Pollution Control Division P-1 "" ''�08 lave -- VOC Sep-1 009 Enclosed Flare VOC FL-3 014 Open Flare VOC VRT-1 015 Enclosed Flare VOC Sep-2 016 Enclosed Flare VOC Sep-3 017 Enclosed Flare VOC Sep-4 018 Enclosed Flare VOC Sep-5 019 Enclosed Flare VOC PROCESS LIMITATIONS AND RECORDS 13. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point Condensate 004 Condensate Throughput 503,700 BBL Tanks PW Tanks 005 Produced Water Throughput 346,020 BBL Truck Loadout 006 Condensate Loaded 503,700 BBL P-1 008 Natural Gas Consumed 5.3 MMSCF Sep-1 009 Total Gas Vented from Low-Pressure 2.6 MMSCF Separator during VRU Downtime FL-3 014 Total Gas Vented from All Separators 15.0 MMSCF to Emergency Flare Total Gas Vented from Vapor VRT-1 015 Recovery Tower during VRU 0.8 MMSCF Downtime Total Gas Vented from Low-Pressure Sep-2 016 Separator during VRU Downtime 1.2 MMSCF Sep-3 017 Total Gas Vented from Low-Pressure 1.2 MMSCF Separator during VRU Downtime Sep-4 018 Total Gas Vented from Low-Pressure 0.9 MMSCF Separator during VRU Downtime Sep-5 019 Total Gas Vented from Low-Pressure 1.2 MMSCF Separator during VRU Downtime 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. 14. AIRS Points 009, 015 - 019: Upon installation of the flow meter required under Condition 7, the owner or operator shall continuously monitor and record the volumetric AIRS ID: 123/9BDB Page 5 of 24 olo epa en li ealth and Environment it Pollution Control Division flowrate of n v I r re se ors and VRT during VRU downtime using a flow meter. The flow meter shall continuously measure flowrate and record total volumetric flow vented to the enclosed flare from the low-pressure separators and VRT during VRU downtime. The owner or operator shall use monthly throughput records and calculation methods detailed in the O&M Plan to demonstrate compliance with the limits specified in Condition 13 and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 15. AIRS Points 004 -006, 008, 009, 014 - 019: 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) 16. 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 II.A.1. &4.) 17. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 18. AIRS Point 004: The flare covered by this permit is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). If a combustion device is used to control emissions of volatile organic compounds to comply with Section XII.D, it shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XII. 19. AIRS Point 004: This source is subject to the recordkeeping, monitoring, reporting and emission control requirements of Regulation 7, Section XII. The operator shall comply with all applicable requirements of Section XII. 20. AIRS Point 004: 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. 21. AIRS Points 004 and 005: 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.1.b If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, AIRS ID: 123/9BDB Page 6 of 24 olor Depa en . P •.Ii ealth and Environment 1 IIit Pollution Control Division dete hz 'ng. -;a- r= The :- > -tor shall comply with all applicable requirements of Section XVII. XVII.B.2.d.(ii) All combustion devices installed before May 1, 2014, must be equipped with an operational auto-igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 22. AIRS Points 004 and 005: The storage tanks covered by this permit are subject to Regulation 7, Section XVII.C emission control requirements. These requirements include, but are not limited to: Section XVII.C.1. Control and monitoring requirements for storage tanks XVII.C.1.b. Owners or operators of storage tanks with uncontrolled actual emissions of VOCs equal to or greater than six (6) tons per year based on a rolling twelve- month total must operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98%for hydrocarbons. XVII.C.1.b.(i)(b) Control requirements of Section XVII.C.1.b. must be achieved by May 1, 2015. XVII.C.1.d. Beginning May 1, 2014, or the applicable compliance date in Section XVII.C.1.b.(i), whichever comes later, owners or operators of storage tanks constructed before May 1, 2014 subject to Section XVII.C.1. must conduct audio, visual, olfactory ("AVO") and additional visual inspections of the storage tank and any associated equipment (e.g. separator, air pollution control equipment, or other pressure reducing equipment) at the same frequency as liquids are loaded out from the storage tank. These inspections are not required more frequently than every seven (7) days but must be conducted at least every thirty one (31) days. Monitoring is not required for storage tanks or associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section XVII.C.1.e. The additional visual inspections must include, at a minimum: XVII.C.1.d.(i) Visual inspection of any thief hatch, pressure relief valve, or other access point to ensure that they are closed and properly sealed; XVII.C.1.d.(ii) Visual inspection or monitoring of the air pollution control equipment to ensure that it is operating, including that the pilot light is lit on combustion devices used as air pollution control equipment; XVII.C.1.d.(iii) If a combustion device is used, visual inspection of the auto-igniter and valves for piping of gas to the pilot light to ensure they are functioning properly; 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. AIRS ID: 123/9BDB Page 7 of 24 I olor pa en P li earth and Environment it Pollution Control Division XVII.C.1.e. If n ed t is , difficult, or inaccessible to monitor, the owner or operator is not required to monitor such equipment until it becomes feasible to do so. XVII.C.2. Capture and monitoring requirements for storage tanks that are fitted with air pollution control equipment as required by Sections XII.D. or XVII.C.1. XVII.C.2.a. Owners or operators of storage tanks must route all hydrocarbon emissions to air pollution control equipment, and must operate without venting hydrocarbon emissions from the thief hatch (or other access point to the tank) or pressure relief device during normal operation, unless venting is reasonably required for maintenance, gauging, or safety of personnel and equipment. Compliance must be achieved in accordance with the schedule in Section XVII.C.2.b.(ii). XVII.C.2.b. Owners or operators of storage tanks subject to the control requirements of Sections XII.D.2., XVII.C.1.a, or XVII.C.1.b. must develop, certify, and implement a documented Storage Tank Emission Management System ("STEM") plan to identify, evaluate, and employ appropriate control technologies, monitoring practices, operational practices, and/or other strategies designed to meet the requirements set forth in Section XVII.C.2.a. Owners or operators must update the STEM plan as necessary to achieve or maintain compliance. Owners or operators are not required to develop and implement STEM for storage tanks containing only stabilized liquids. The minimum elements of STEM are listed below. XVII.C.2.b.(i) STEM must include selected control technologies, monitoring practices, operational practices, and/or other strategies; procedures for evaluating ongoing storage tank emission capture performance; and monitoring in accordance with approved instrument monitoring methods following the applicable schedule in Section XVII.C.2.b.(ii) and Inspection Frequency in Table 1. XVII.C.2.b.(ii) Owners or operators must achieve the requirements of Sections XVII.C.2.a. and XVII.C.2.b. and begin implementing the required approved instrument monitoring method in accordance with the following schedule: XVII.C.2.b.(ii)(b) A storage tank constructed before May 1, 2014, must comply with the requirements of Sections XVII.C.2.a. and XVII.C.2.b. by May 1, 2015. Approved instrument monitoring method inspections must begin within ninety (90) days of the Phase-In Schedule in Table 1, or within thirty(30) days for storage tanks with uncontrolled actual VOC emissions greater than 50 tons per year. XVII.C.2.b.(ii)(d) Following the first approved instrument monitoring method inspection, owners or operators must continue conducting approved instrument monitoring method inspections in accordance with the Inspection Frequency in Table 1. Table 1 —Storage Tank Inspections Threshold: Storage Tank Approved Instrument Phase-In Uncontrolled Actual VOC Monitoring Method Inspection AIRS ID: 123/9BDB Page 8 of 24 olor 'epa P .li ealth and Environment A en . •it Pollution Control Division to s ( ° ency Schedule > 6 and < 12 Annually January 1, 2016 > 12 and < 50 Quarterly July 1, 2015 > 50 Monthly January 1, 2015 XVII.C.2.b.(iii) Owners or operators are not required to monitor storage tanks and associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section XVII.C.1.e. XVII.C.2.b.(iv) STEM must include a certification by the owner or operator that the selected STEM strategy(ies)are designed to minimize emissions from storage tanks and associated equipment at the facility(ies), including thief hatches and pressure relief devices. XVII.C.3. Recordkeeping XVII.C.3. The owner or operator of each storage tank subject to Sections XII.D. or XVII.C. must maintain records of STEM, if applicable, including the plan, any updates, and the certification, and make them available to the Division upon request. In addition, for a period of two (2) years, the owner or operator must maintain records of any required monitoring and make them available to the Division upon request, including: XVII.C.3.a. The AIRS ID for the storage tank. XVII.C.3.b. The date and duration of any period where the thief hatch, pressure relief device, or other access point are found to be venting hydrocarbon emissions, except for venting that is reasonably required for maintenance, gauging, or safety of personnel and equipment. XVII.C.3.c. The date and duration of any period where the air pollution control equipment is not operating. XVII.C.3.d. Where a combustion device is being used, the date and result of any EPA Method 22 test or investigation pursuant to Section XVII.C.1.d.(v). XVII.C.3.e. The timing of and efforts made to eliminate venting, restore operation of air pollution control equipment, and mitigate visible emissions. 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. 23. AIRS Point 006: This source is located in an ozone non-attainment or attainment- maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 24. AIRS Point 006: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): AIRS ID: 123/9BDB Page 9 of 24 olor epa en P li ealth and Environment 'r Pollution Control Division a. Hoses s, v al ined event 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 on site at the time of the inspection to ensure compliance with Condition 24 (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. 25. AIRS Point 006: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 26. This source is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. The operator shall comply with all applicable requirements of Section XII. 27. AIRS Point 007: This source is subject to Regulation No. 7, Section XVII.F. leak detection and repair requirements,which include but are not limited to: XVII.F.1. As of the compliance date specified in XVII.F.4, the provisions of Section XVII.F. shall apply in lieu of any directed inspection and maintenance program requirements established pursuant to Regulation Number 3, Part B, Section III.D.2. XVII.F.4. Requirements for well production facilities XVII.F.4.b. Owners or operators of well production facilities constructed before October 15, 2014, must identify leaks from components using an approved instrument monitoring method within ninety (90) days of the Phase-In Schedule in Table 4; within thirty (30) days for well production facilities subject to monthly approved instrument monitoring method inspections; or by January 1, 2016, for well production facilities subject to a one time approved instrument monitoring method inspection. Thereafter, approved instrument monitoring method and AVO inspections must be conducted in accordance with the Inspection Frequencies in Table 4. XVII.F.4.c. The estimated uncontrolled actual VOC emissions from the highest emitting storage tank at the well production facility determines the frequency at which inspections must be performed. Table 4—Well Production Facility Component Inspections Thresholds(per XVII.F.4.c)—Well Production Facilities Approved Instrument AVO with Storage Tanks Monitoring method Inspection Phase-In (tpy) Inspection Frequency Frequency Schedule AIRS ID: 123/9BDB Page 10 of 24 olor Depa en . P;.•li ealth and Environment II •it Pollution Control Division < 6 O _O thly January 1, 2016 > 6 and < 12 Annually Monthly January 1, 2016 > 12 and < 50 Quarterly Monthly January 1, 2015 > 50 Monthly January 1, 2015 XVII.F.5. If a component is unsafe, difficult, or inaccessible to monitor, the owner or operator is not required to monitor the component until it becomes feasible to do so. XVII.F.6 Leaks requiring repair: Leaks must be identified utilizing the methods listed in Section XVII.F.6. Only leaks detected pursuant to Section X\/II.F.6. require repair under Section XVII.F.7. XVII.F.6.a. For EPA Method 21 monitoring, or other Division approved quantitative instrument based monitoring, at facilities constructed before May 1, 2014, a leak is any concentration of hydrocarbon above 2,000 parts per million (ppm) not associated with normal equipment operation, such as pneumatic device actuation and crank case ventilation, except for well production facilities where a leak is defined as any concentration of hydrocarbon above 500 ppm not associated with normal equipment operation, such as pneumatic device actuation and crank case ventilation. X\/II.F.6.c. For infra-red camera and AVO monitoring, or other Division approved non- quantitative instrument based monitoring, a leak is any detectable emissions not associated with normal equipment operation, such as pneumatic device actuation and crank case ventilation. XVII.F.6.e. For leaks identified using an approved instrument monitoring method or AVO, owners or operators have the option of either repairing the leak in accordance with the repair schedule set forth in Section XVII.F.7. or conducting follow-up monitoring using EPA Method 21 within five (5) working days of the leak detection. If the follow-up EPA Method 21 monitoring shows that the emission is a leak as defined in Section XVII.F.6.,the leak must be repaired and remonitored in accordance with Section XVII.F.7. XVII.F.7. Repair and remonitoring XVII.F.7.a. First attempt to repair a leak must be made no later than five (5) working days after discovery, unless parts are unavailable, the equipment requires shutdown to complete repair, or other good cause exists. If parts are unavailable, they must be ordered promptly and the repair must be made within fifteen (15) working days of receipt of the parts. If shutdown is required, the leak must be repaired during the next scheduled shutdown. If delay is attributable to other good cause, repairs must be completed within fifteen (15) working days after the cause of delay ceases to exist. XVII.F.7.b. Within fifteen (15) working days of completion of a repair, the leak must be remonitored to verify the repair was effective. AIRS ID: 123/9BDB Page 11 of 24 olo epa en P li ealth and Environment it Pollution Control Division XVII.F.7.c. Le v u ot tecti thods of Section XVII.F.6. shall not be subject to enforcement by the Division unless the owner or operator fails to perform the required repairs in accordance with Section XVII.F.7. XVII.F.8. Recordkeeping: The owner or operator of each facility subject to the leak detection and repair requirements in Section XVII.F. must maintain the following records for a period of two (2) years and make them available to the Division upon request. XVII.F.8.a. Documentation of the initial approved instrument monitoring method inspection for new well production facilities; XVII.F.8.b.The date and site information for each inspection; XVII.F.8.c. A list of the leaking components and the monitoring method(s) used to determine the presence of the leak; XVII.F.8.d. The date of first attempt to repair the leak and, if necessary, any additional attempt to repair the leak; XVII.F.8.e.The date the leak was repaired; XVII.F.8.f.The delayed repair list, including the basis for placing leaks on the list; XVII.F.8.g. The date the leak was remonitored to verify the effectiveness of the repair, and the results of the remonitoring; and XVII.F.8.h. A list of components that are designated as unsafe, difficult, or inaccessible to monitor, as described in Section XVII.F.5., an explanation stating why the component is so designated, and the plan for monitoring such component(s). XVII.F.9. Reporting: The owner or operator of each facility subject to the leak detection and repair requirements in Section XVII.F. must submit reports as specified in Section XVII.F.9. 28. AIRS Point 007: Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). Upon the compliance dated specified in Regulation No. 7, Section XVII.F.4., the provisions of Section XVII.F. shall apply in lieu of RACT requirements established pursuant to Regulation Number 3, Part B, Section III.D.2. This requirement to apply RACT shall be satisfied by installing/implementing the following emission controls: a. Directed Inspection & Maintenance as described below shall satisfy the requirement to apply RACT. i. Auditory/visual/olfactory inspection (AVO) will be performed on a semi-annual basis.The first AVO inspection must be completed within 180 days of permit issuance. ii. For each leak found in the AVO inspection, a gas detector may be used to determine the size of the leak. The gas detector shall be regularly calibrated. Component leaks greater than 10,000 ppm shall be managed in accordance with Item (vi)below, unless it is unfeasible to make the repair without shutting down the affected operation of the AIRS ID: 123/9BDB Page 12 of 24 olor •epe en • P •Ii '' ealth and Environment i IIo, it Pollution Control Division ty. _ • •- le. - " han a:°6:10 ppm shall not require repair. For such component leaks that require a shutdown to be repaired, repair shall occur during the first shutdown of the affected operation after the leak is discovered. Hi. For repair, valves adjacent to the equipment to be repaired will be closed if practicable, minimizing the volume released. iv. Repaired components shall be re-screened using AVO to determine if the leak is repaired. v. The following records shall be maintained for a period of two years: • The name of the site screened via AVO inspection and the name of the inspector. • Components evaluated with the gas detector. • Repair methods applied. • Dates of the AVO inspections, gas detector calibrations, attempted repairs, successful repairs, repair delays, and post- repair screenings. vi. Leaks shall be repaired as soon as practicable, but no later than 15 calendar days after detection, unless it is technically or operationally infeasible to make the repair within 15 calendar days. Records documenting the rationale shall be maintained if it is technically or operationally infeasible to make the repair within 15 calendar days. 29. AIRS Point 014: No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.5.) OPERATING & MAINTENANCE REQUIREMENTS 30. 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.) 31. AIRS Point 006: The owner or operator of a loadout at which vapor balancing is used 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 and return these vapors to the stationary source storage tanks. 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. AIRS ID: 123/9BDB Page 13 of 24 olor epa en li ealth and Environment 'r Pollution Control Division d. Opera v n sa nt at 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 32. AIRS Point 007:Within one hundred and eighty days(180)after issuance of this permit, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. 33. AIRS Point 014: Within one hundred and eighty (180) days after commencement of operation, the owner or operator shall demonstrate compliance with opacity requirements, using EPA Method 9 to measure opacity from the flare when the flare is receiving gas from the separator. This measurement shall consist of a minimum twenty- four consecutive reading taken at fifteen second intervals over a 6 minute period. (Reference: Regulation No. 1, Section II.A.5). 34. AIRS Point 015: The operator shall complete an initial site specific extended gas analysis of the natural gas vented from the vapor recovery tower at this site in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4- trimethylpentane 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. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. Periodic Testing Requirements 35. AIRS Point 007: On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. ALTERNATE OPERATING SCENARIOS 36. AIRS Point 008: This pump may be replaced with a like-kind pump in accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a revision to this permit or obtaining a new construction permit. A like-kind replacement pump shall be the same make, model and capacity as authorized in this permit. AIRS ID: 123/9BDB Page 14 of 24 lik olor Pepe en . P ell ealth and Environment lir`, `: •it Pollution Control Division 37. AIRS Point 0 o .r; _: or - ' tain on-site or at a local field office to contemporaneously record the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of the replacement pump. 38. AIRS Point 008: All pump replacements installed and operated per the alternate operating scenarios authorized by this permit must comply with all terms and conditions of this construction permit. ADDITIONAL REQUIREMENTS 39. All previous versions of this permit are cancelled upon issuance of this permit. 40. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30'" whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5)tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO,) in ozone nonattainment areas emitting less than 100 tons of VOC or NQ per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 41. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS 42. 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 AIRS ID: 123/9BDB Page 15 of 24 epa en li ealth and Environment it Pollution Control Division AQCC RegulDolor , on a r for transfer of ownership and the submittal of a revised APEN and the required fee. 43. 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. 44. 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. 45. 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. 46. 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 indio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 47. 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. 48. 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: Carissa Money Permit Engineer AIRS ID: 123/9BDB Page 16 of 24 litolor Depa en : P .li ealth and Environment it Pollution Control Division Permit History Issuance Date Description Issuance 2 This Issuance Modification to convert AIRS Point 004 from GP01 to this permit.Also added tanks, increased throughput and emissions. Modification to Point 5 to add tank, increase throughput, and increase emissions. Modification to Point 006 to increase throughput and emissions and to add control. Modification to Point 007 to increase counts and emissions. Modification to Point 008 to increase emissions. Modification to Point 009 to account for additional process control and decrease emissions. Adding new points 014 through 019. Issuance 1 August 20, 2014 Issued to Bonanza Creek Energy Operating Company LLC for Points 005- 009 AIRS ID: 123/9BDB Page 17 of 24 epa en P li ealth and Environment it Pollution Control Division Notes to Permit HolderDolor o e a 1) The permit holder is required to pay fees for the processing time for this permit.An invoice for these fees will be issued after the permit is issued.The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice(APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: http://www.colorado.gov/cs/Satellite?c=Document C&childpagename=CDPHE- Main%2FDocument C%2FCBONAddLinkView&cid=1251599389641&panename=CBONW rapper 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 Emission Are the Controlled AIRS Rate emissions Emission Rate Point Pollutant CAS# (Ib/yr) reportable? (ib/yr) Benzene 71432 573 Yes 29 n-Hexane 110543 3,541 Yes 177 Toluene 108883 453 Yes 23 004 Ethylbenzene 100414 48 No 2 Xylenes 1330207 145 No 7 2'2'4- 540841 347 Yes 17 trimethylpentane Benzene 71432 2,422 Yes 121 005 n-Hexane 110543 7,612 Yes 381 Benzene 71432 484 Yes 162 n-Hexane 110543 3,853 Yes 1,291 006 Toluene 108883 316 Yes 106 Ethylbenzene 100414 29 No 10 Xylenes 1330207 94 No 32 Benzene 71432 276 Yes 276 ' n-Hexane 110543 1,651 Yes 1,651 007 Toluene 108883 539 Yes 539 Ethylbenzene 100414 137 No 137 AIRS ID: 123/9BDB Page 18 of 24 olor Depa en : P .li '' ealth and Environment •it Pollution Control Division 450 Benzene 71432 286 Yes 14 n-Hexane 110543 1,814 Yes 91 008 Toluene 108883 227 No 11 Ethylbenzene 100414 25 No 1 Xylenes 1330207 75 No 4 Benzene 71432 230 No 11 n-Hexane 110543 1,366 Yes 68 009 Toluene 108883 163 No 8 Ethylbenzene 100414 19 No 1 Xylenes 1330207 42 No 2 Benzene 71432 816 Yes 41 n-Hexane 110543 5,178 Yes 259 014 Toluene 108883 649 Yes 32 Ethylbenzene 100414 71 No 4 Xylenes 1330207 214 No 11 Benzene 71432 838 Yes 42 n-Hexane 110543 5,091 Yes 255 015 Toluene 108883 612 Yes 31 Ethylbenzene 100414 58 No 3 Xylenes 1330207 163 No 8 Benzene 71432 220 No 11 n-Hexane 110543 1,377 Yes 69 016 Toluene 108883 174 No 9 Ethylbenzene 100414 19 No 1 Xylenes 1330207 55 No 3 Benzene 71432 202 No 10 n-Hexane 110543 1,267 Yes 63 017 Toluene 108883 160 No 8 Ethylbenzene 100414 17 No 1 Xylenes 1330207 50 No 3 Benzene 71432 158 No 8 018 n-Hexane 110543 992 Yes 50 Toluene 108883 125 No 6 AIRS ID: 123/9BDB Page 19 of 24 olor epa en li ealth and Environment 'r Pollution Control Division Ethyl 1 Xylenes 1330207 39 No 2 Benzene 71432 202 No 10 n-Hexane 110543 1,267 Yes 63 019 Toluene 108883 160 No 8 Ethylbenzene 100414 17 No 1 Xylenes 1330207 50 No 3 5) The emission levels contained in this permit are based on the following emission factors: Point 004: Emission Factors Emission Factors Uncontrolled Controlled lb/BBL lb/BBL Condensate Condensate Pollutant Throughput Throughput Source NOx 0.068 lb/MMBtu 0.068 lb/MMBtu AP-42,Table 13.5 CO 0.37 lb/MMBtu 0.37 lb/MMBtu AP-42,Table 13.5 VOC 0.2525 0.0126 Promax n-Hexane 0.0070 0.00035 Promax Benzene 0.0011 0.00006 Promax Toluene 0.0009 0.00004 Promax Ethylbenzene 0.0001 4.81 x 10" Promax Xylenes 0.0003 0.00001 Promax 2,2,4- 0.0007 0.00003 Promax trimethylpentane Note: The controlled emissions for this point are based on the flare control efficiency of 95%. A HHV of 2,493 BTU/scf was used for combustion calculations. Point 005: Emission Factors Emission Factors Uncontrolled Controlled lb/BBL Produced lb/BBL Produced Pollutant Water Throughput Water Throughput Source VOC 0.262 0.0131 CDPHE n-Hexane 0.022 0.0011 CDPHE Benzene 0.007 0.0004 CDPHE Note: The controlled emissions for this point are based on the flare control efficiency of 95%. Point 006: Uncontrolled Controlled Pollutant lb/BBL loaded lb/BBL loaded Source VOC 0.1299 0.0435 AP-42 Benzene 0.0010 0.0003 AP-42 n-Hexane 0.0077 0.0026 AP-42 Toluene 0.0006 0.0002 AP-42 Ethylbenzene 0.0001 1.9 x 10' AP-42 Xylenes 0.0002 0.0001 AP-42 AIRS ID: 123/9BDB Page 20 of 24 0104 Depa en . P •li ealth and Environment II •it Pollution Control Division •nco Pollutant lb/BBL loaded lb/BBL loaded Source 2,2,4- AP-42 trimethylpentane 0.0003 0.0001 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 = 1 (Submerged loading:dedicated vapor balance service) P(true vapor pressure)=2.51 psia M (vapor molecular weight) =56.43 Ib/Ib-mol T(temperature of liquid loaded)=524 R The uncontrolled non-criteria reportable air pollutant (NCRP)emission factors were calculated by multiplying the mass fraction of each NCRP in the stable condensate by the VOC emission factor. Point 007: Component Gas Heavy Oil Light Oil Water/Oil Connectors 3013 0 1483 0 Flanges 147 0 50 0 Open-ended Lines 99 0 15 0 Pump Seals 8 0 0 0 Valves 453 0 194 0 Other 215 0 26 0 VOC Content(wt. 0.3149 1 0.9973 1 fraction) Benzene Content(wt. 0.0009 0 0.00997 0 fraction) Toluene Content(wt. 0.0007 0 0.0242 0 fraction) Ethylbenzene (wt. 0.00007 0 0.0066 0 fraction) Xylenes Content(wt. 0.0002 0 0.0218 0 fraction) n-hexane Content(wt. 0.0055 0 0.0582 0 fraction) *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors(kg/hr-component): Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: Standard EFs-EPA-453/R-95-017 Table 2-4 AIRS ID: 123/9BDB Page 21 of 24 epa en li ealth and Environment T Pollution Control Division Compliance with e m' t it onstr by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent extended gas analysis. Point 008: Emission Factors- Emission Factors- Uncontrolled Controlled Pollutant lb/MMscf vented lb/MMscf vented Source NOx (Ib/MMBTU) 0.068 0.068 AP-42 CO(lb/MMBTU) 0.37 0.37 AP-42 VOC 19,936 996.82 Gas Analysis Benzene 54.409 2.7205 Gas Analysis n-Hexane 345.18 17.259 Gas Analysis Toluene 43.274 2.1637 Gas Analysis Xylenes 14.287 0.7143 Gas Analysis The displacement equation can found in "EPA Emission Inventory Improvement Program Publication:Volume II, Chapter 10-Displacement Equation(10.4-3)." Emission factors for CO and NOx found in AP-42 Table 13.5-1. A HHV of 1,379 BTU/scf was used for combustion calculations. Point 009: Weight Emission Emission Fraction of Factors Factors Gas(%) Uncontrolled Controlled Pollutant lb/MMscf lb/MMscf Source NOx(Ib/MMBTU) — 0.068 0.068 AP-42 CO(lb/MMBTU) -- 0.37 0.37 AP-42 VOC 50.9 42,086 2,104.3 Gas Analysis Benzene 0.11 89.251 4.4625 Gas Analysis Toluene 0.08 63.459 3.1730 Gas Analysis Ethylbenzene 0.01 7.2834 0.3642 Gas Analysis Xylenes 0.02 16.248 0.8124 Gas Analysis n-hexane 0.64 530.50 26.525 Gas Analysis Note: The uncontrolled VOC and HAP emissions were calculated using a gas sample collected 9/20/2013 of the gas vented from the low pressure separator from State Antelope 41-44-3OHNB to estimate the VOC and HAP content of the stream and a Promax model to estimate stream flow. Emission factors for CO and NOx are based on AP-42 Table 13.5-1. A HHV of 1,783 BTU/scf was used for calculations. Point 014: Weight Emission Emission Fraction of Factors Factors Gas(%) Uncontrolled Controlled Pollutant lb/MMscf lb/MMscf Source NOx(lb/MMBTU) — 0.068 0.068 AP-42 CO(Ib/MMBTU) -- 0.37 0.37 AP-42 VOC 31.5 19,936 996.82 Gas Analysis Benzene 0.09 54.409 2.7208 Gas Analysis Toluene 0.07 43.274 2.1639 Gas Analysis Ethylbenzene 0.01 4.7622 0.2381 Gas Analysis Xylenes 0.02 14.287 0.7143 Gas Analysis n-hexane 0.55 345.17 17.259 Gas Analysis AIRS ID: 123/9BDB Page 22 of 24 olor Depa en + P .li ' ealth and Environment •it Pollution Control Division Emission factor :;; ll d , o •.:';t,,,P 'f,, .5-1. -.V of 1,379 BTU/scf was used for calculations. Point 015: Weight Emission Emission Fraction of Factors Factors Gas(°/0) Uncontrolled Controlled Pollutant lb/MMscf lb/MMscf Source NOx (lb/MMBTU) --- 0.068 0.068 AP-42 CO (lb/MMBTU) --- 0.37 0.37 AP-42 VOC 74.1 87,169 4,358.4 Gas Analysis Benzene 0.86 1,007.1 50.354 Gas Analysis Toluene 0.63 736.25 36.813 Gas Analysis Ethylbenzene 0.06 70.039 3.5020 Gas Analysis Xylenes 0.17 195.80 9.7901 Gas Analysis n-hexane 5.20 6,121.1 306.05 Gas Analysis 2,2,4- 0.25 292.67 14.634 Gas Analysis tnmethylpentane Note: The uncontrolled VOC and HAP emissions were calculated based on a Promax model to estimate the VOC and HAP content of the stream and stream flow. Emission factors for CO and NOx are based on AP-42 Table 13.5-1. A HHV of 2,415 BTU/scf was used for calculations. Points 016, 017, 018 and 019: Weight Emission Emission Fraction of Factors Factors Gas(%) Uncontrolled Controlled Pollutant lb/MMscf lb/MMscf Source NOx(lb/MMBTU) --- 0.068 0.068 AP-42 CO (lb/MMBTU) --- 0.37 0.37 AP-42 VOC 60.2 54,769 2,738.5 Gas Analysis Benzene 0.19 175.82 8.7911 Gas Analysis Toluene 0.15 139.32 6.9660 Gas Analysis Ethylbenzene 0.02 15.127 0.7564 Gas Analysis Xylenes 0.05 43.701 2.1850 Gas Analysis n-hexane 1.21 1,101.9 55.096 Gas Analysis Note: The uncontrolled VOC and HAP emissions were calculated using a gas sample collected 5/22/2014 of the gas vented from the low pressure separator for State Antelope P41-T44-30HNB to estimate the VOC and HAP content of the stream and a Promax model to estimate stream flow. Emission factors for CO and NOx are based on AP-42 Table 13.5-1. A HHV of 1,956 BTU/scf was used for calculations. 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) This facility is classified as follows: Applicable Status AIRS ID: 123/9BDB Page 23 of 24 olor epa en P li ealth and Environment it Pollution Control Division Requirement Operating Permit Synthetic Minor Source of: VOC, CO, NOx,and n-hexane NANSR Synthetic Minor Source of: VOC and NOx MACT HH Not Applicable 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.apoaccess.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 7777—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX 9) 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.00v/pacific/cdphe/air-permit-self-certification AIRS ID: 123/9BDB Page 24 of 24 Division Information Engineer: Carissa Money Control Engineer: NA Review Date: 01/07/2015 Application Date: 06/23/2014 Facility Identifiers Permit No. 14WE0197 E0197 AIRS County 123 Weld facility# 9BDB Facility Type: exploration and production facility 0 Located in the 8-hour non-attainment area? 0 True Minor O Synthetic Minor for: )✓ VOC P NOx r CO Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: State Antelope P-30 Production Facility Source Location: NENE Section 30,Township 5N, Range 62W SIC: 1311 Address 1: Bonanza Creek Energy Operating Company LLC Mailing Address 2: 410 17th Street,Suite 1500 Address :ity,State Zip: Denver,CO 80202 Name: Peg Young Person To Phone: 720-440-6133 Contact Fax: 720-279-2331 Email: pyoung(abonanzacrk.com 'Requested Action Self Certification Required? Yes Issuance Number: 2 Source Description: Oil and gas exploration and production facility known as the State Antelope P-30 Production Facility,located in the NENE Section 30,Township 5N,Range 62W,Weld County,Colorado. Point Name Type Control Action Existing point-Adding tanks, increasing Condensate 004 Condensate Tanks Flare throughput and converting from GP01 to this Tanks facility wide permit Existing point-adding 1 tank and 1 vault, 005 PW Tanks Water Tanks Flare increasing throughput from 43,800 bbl to 346,020 bbl/yr 006 Truck Loadout Flare Existing point-increasing throughput from Loadout 131,400 bbl/yr to 503,700 007 FUG Fugitives None Existing point-increasing counts and emission limit from 5.2 to 24.4 tpy 008 P-t Pump Flare Existing point-increasing emission limit from 2.5 to 2.6 tpy based on updated gas analysis 009 Sep-1 Separator Venting Flare Existing point-modifying control strategy to include VRU and flare 014 FL-3 Separator Venting Flare New point-emergency flare 015 VRT-1 Separator Venting Flare New point-Venting from Vapor Recovery Tower controlled by VRU and flare New point-Venting from Low Pressure 016 Sep-2 Separator Venting Flare Separator controlled by VRU and flare New point-Venting from Low Pressure 017 Sep-3 Separator Venting Flare Separator controlled by VRU and flare 018 Sep-4 Separator Venting Flare New point-Venting from Low Pressure Separator controlled by VRU and flare New point-Venting from Low Pressure 019 Sep-5 Separator Venting Flare Separator controlled by VRU and flare *Points 001,002,010-012 are engines covered by GP02 'Points 003 and 013 were temporary flares that have already been removed from the site and are cancelled 004 Fifteen 500 bbl above ground atmospheric condensate storage tanks controlled by nine encic Requsted Throughput 503700 bbl Control Flare Efficiency 95.00%I Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.2525 lb/bbl 63.6 tpy 3.2 tpy Promax Benzene 0.0011 lb/bbl 573 lb/yr 29 lb/yr Promax n-Hexane 0.0070 lb/bbl 3541 lb/yr 177 lb/yr Promax Toluene 0.0009 lb/bbl 453 lb/yr 23 lb/yr Promax Ethylbenze 0.0001 lb/bbl 48 lb/yr 2 lb/yr Promax Xylenes 0.0003 lb/bbl 145 lb/yr 7 lb/yr Promax 2,2,4-TMP 0.0007 lb/bbl 347 lb/yr 17 lb/yr Promax Nox 0.068 lb/Mmbtu 0.1 tpy 0.1 tpy AP-42 Table 1 CO 0.37 lb/Mmbtu 0.8 tpy 0.8 tpy AP-42 Table 1 Regulatory Review Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20%opacity.This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes.The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR, Part 60, Appendix A(July, 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 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 6-New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. The 500 bbl tanks are above the minimum capacity threshold of-471 bbl. However,the tanks are located at the wellhead site,store condensate, and are prior to custody transfer;thus,the tanks are exempt from NSPS Kb (60.110b(d)(4)) . NSPS OOOO:for storage vessels in the natural gas production,transmission,and processing segments. This source is not subject because each tank emits less than 6 tpy VOC. 14WE0197.CP2 123/9BDB Wilton 7-Volatile()manic Compounds XII.VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS Applicant is subject to the emission control requirements for condensate tanks since it is located in the nonattainment area. XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... Applicant is currently subject to this since actual uncontrolled emissions are greater than 20 tpy of VOC and actual uncontrolled emissions are greater than 6 tpy. 14WE0197.CP2 123/9BDB 005 Two(2)500 bbl above ground produced water storage tank and two(2)60 bbl concr Emissions Calculations Requsted Throughput 346020 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.262 lb/bbl 45.3 tpy 2.3 tpy CDPHE Benzene 0.007 lb/bbl 2422 lb/yr 121 lb/yr CDPHE n-Hexane 0.022 lb/bbl 7612 lb/yr 381 lb/yr CDPHE Regulatory Review Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20%opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes.The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR, Part 60,Appendix A(July, 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 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 7—Volatile Organic Compounds XVII.C.1.b Applicant is subject since actual uncontrolled emissions are greater than 6 tpy. 14WE0197.CP2 123/9BDB 006 Truck Condensate Loadout that is controlled by using dedicated vapor balance service and nine c Calculations L=12.46'S'P'M/T(AP-42:Chapter 5.2,Equation 1) L=loading losses in lb per 1000 gallons loaded Factor Meaning Value Units Source 5 Saturation Factor 1 AP-42 P True Vapor Pressure 2.514 psia Calculated TVP of liquid based on oil analysis an M Molecular Weight of Var 56.43 lb/lb-mole Calculated MW of liquid based on oil analysis an. T Liquid Temperature 523.67 deg.R EPA Tanks Met Data for Denver.CO L 3.09 lb/10^3 gal 1.30E-01 lb/bbl Annual requested Throughput 503700 BBL/yr 21155400 gal/yr Annual requested VOC emissions 65454 lb/yr 32.73 tpy Control: Flare Efficiency: 66.50% Source assumes 95%control efficiency and 70%collection efficiency NCRPs Component Mass Fraction VOC 0.9166 Benzene 0.0074 n-hexane 0.0589 Toluene 0.0048 Ethylbenzen. 0.0004 Xylenes 0.0014 2,2,4-TMP 0.0026 Source: Sales oil composition and Eq 1-22 of AP-42 Ch 7 Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.1299 lb/bbl 32.7 tpy 11.0 tpy AP-42 Benzene 0.0010 lb/bbl 484 lb/yr 162 lb/yr AP-02 n-Hexane 0.0077 lb/bbl 3853 lb/yr 1291 lb/yr AP-42 Toluene 0.0006 lb/bbl 316 lb/yr 106 lb/yr AP-42 Ethylbenzen 0.0001 lb/bbl 29 lb/yr 10 lb/yr AP-42 Xylenes 0.0002 lb/bbl 94 lb/yr 32 lb/yr AP-42 2,2,4-TMP 0.0003 lb/bbl 170 lb/yr 57 lb/yr AP-42 Regulatory Review (Regulation 7-Volatile Organic Compounds This facility is not considered a bulk plant(in Reg.7)because it does not distribute gasoline. 14WE0197.CP2 123/9BDB 007 Fugitive VOL equipment leaks Regulation I Information Operating Hours'. 8750 hourslyear Emission Factor Source Standard EFs•EPA-453/R-95-017 Table 2-4 Control Efficiency Source None Calculations Emission Factor(kgrhr- Emlesions Service Component Type Countsource) Control(%)Pollutant Mass Fraction spy) Table 24 Table 2-8 Reg.3 Connectors 3013 1.WE04 I00E05 00% VOC 0.314889 10 618151 Flanges 147 3.90E-04 570).06 0 Benzene 0.000859 0.0398775 Open-Ended Lines 99 1.00)03 1.50E-05 0 0% Toluene 0.000684 0.0317535 Gas Pump Seals 0 240E-03 350E-04 0 0% Etts1benzene 0000074 00034353 Valves 453 650E-03 250).05 0 0% Xylenes 0000228 00105845 Other 215 8.80E-03 1.20E-04 0 n-Helene 0 005453 0.2531456 Connectors 0 7.50E-06 7.50E-06 0 VOC 1 0 Flanges 0 3.90E-07 3.90E-07 00% Benzene 0 Heavy 011 Open-Ended Lines 0 140).04 7.20E-06 0.0% Toluene 0 Pump Seals 0 0.001.00 000E+00 0.0% Ethpbenzene 0 Valves 0 8.40E-06 e40E-06 0.0% Xylenes 0 Other 0 3.20).05 3.20E-05 0.0% r-Hexane 0 Connectors 1483 2.10E-04 7.50E-06 00% VOC 0.99733 9.8030385 Flanges 50 110E-04 240E-06 00% Benzene 0.009971 00980078 Light Oil Open-Ended Lines 15 140E-03 140E-05 0.0% Toluene 0.024168 0.2375541 Pump Seals 0 1.30)02 5.10E-04 00% Emylbenzene 0006629 00651583 Valves 194 2.50E-03 1.90E-05 00% Xylenes 0021793 02142096 Other 26 ]S0E03 ]10EJN 0.0% n-Hexane 0058237 05724279 Connectors 1.10)04 100E-05 0.0% VOC 1 0 Flanges x90).06 290E-06 0 Benzene 0 Water/Oil Open-Ended Lines 2.50E-04 3.50E-06 00% Toluene 0 Pump Seals 2.40E-05 2.40)os 0.0% Embbenzene 0 Valves 980E-05 970E-06 0.0% Xylenes 0 Other 1.40).02 590).05 0 n-Hexane 0 Emissions Summary Table Pollutant Uncontrolled Emissions Controlled Emissions Source I0y VOC 244 tpy 24.4 toy Standard EFs-EPA-453/R-95-017 Table 2-4 Benzene 276 lb/yr 2761bryr Standard EFs-EPA-453/R-95-017 Table 2-4 0.14 Toluene 539 lb/yr 539 lb/yr Standard EFs-EPA-453/R-95-017 Table 2-4 0.27 Etu/berzene 137 lb/yr 137 lb/yr Standard EFs-EPA483/R-95-017 Table 24 0.07 Xylenes 450 lb/yr 450 th/yr Standard EFs-EPA453/R-95017 Table 2-4 022 rvHerane 1651 lb/yr 3453 lb/yr Standard EFs-EPA453/R-95-017 Table 24 0.83 Regulatory Applicability The date of interest for determining whether the source is new or modified is therefore November 20,2007(the dale on the 8-hour ozone NA area designation)Since the site was built after the date above(operation began 8/1/20135,this Reg.3 source is nsidered'ne8 or moStied.'Operator has agreed an the Division's standard conditions. VOC and HAP concentrations Mr gas service are based on sales gas sample collected 5/22/2014 from State Antelope P41-T44-30HNB.Since site-specific and within 1 year of application date,no initial sampling required. 14WE0197,CP2 123/960B One(1)pneumatic water transfer pump,rated at 600 scf/hr(Sandpiper, Model G1 F,Serial number 2091586).The pneumatic pump is controlled by 008 nine enclosed flares.Each flare has a minimum control efficiency of 95%. Pump Information Manufactur Sandpiper Model Number:GIP Serial Pump Number:2091586 Information Pump capadty 9.1 gallons per minute pumped natural gas 600 scf/hour used consumptio Control Flare 95.00%Efficiency Calculations EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q•MW•Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas•MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm a 800 scf/hr I MW 23.97 Ih/Ih-mot Hours of Op. 8760 houmyr Requested Throughput 5.256 MMscf/yr Component mole% MW mass fraction Component lb/hr lb/yr tpy CO2 2.2224 44 0.0408 CO2 1.548 13560.979 6.780 nitrogen 0.5817 28 0.0068 nitrogen 0.258 2258.776 1.129 methane 88.377 16.04 0.4576 methane 17.363 152100.469 76.050 ethane 143929 30.07 0.1806 ethane 6.852 60020.261 30.010 propane 8.8812 44.09 0.1634 propane 6.199 54303.509 27.152 isobutane 0.891 58.12 0.0216 isobutane 0.820 7181.571 3.591 n-butane 2.7051 58.12 0.0656 n-butane 2.489 21803.443 10.902 isopentane 0.5104 72.15 0.0154 isopentane 0.583 5106.968 2.553 n-pentane 0.666 72.15 0.0200 n-pentane 0.761 6663.873 3.332 cyclopentane 0.0491 70.15 0.0014 cyclopentane 0.055 477.667 0.239 n-hexane 0.1518 86.18 0.0055 n-hexane 0.207 1814.239 0.907 cyclohexane 0.0393 84.18 0.0014 cyclohexane 0.052 458.794 0.229 Other hexanes 02469 86.18 0.0089 Other hexane. 0.337 2950.827 1.475 heptanes 0.1253 100.21 0.0052 heptanes 0.199 1741.319 0.871 methylcyclohexa 0.0317 98.19 0.0013 methylcyclohe 0.049 431.661 0.216 224-IMP 0.0001 114.22 0.0000 224-TMP 0.000 1.584 0.001 Benzene 0.0264 78.11 0.0009 Benzene 0.033 285.974 0.143 Toluene 0.0178 92.14 0.0007 Toluene 0.026 227.449 0.114 Ethylbenzene 0.0017 106.17 0.0001 Ethylbenzene 0.003 25.030 0.013 Xylenes 0.0051 106.17 0.0002 Xylenes 0.009 75.091 0.038 C8+Heavies 0.0769 116 0.0037 CS+Heavies 0.141 1237.088 0.619 Mass Fraction VOC: 0.3152 Total VOC 52.393 Heating Value I 1379 EITU/scf I _ Combustan emission recta source: AP-42:chapter 13.5 14WE0197.CP2 123/9BDB 0.07 lb NOYAMABlu 0 37 lb COaIMBtu Notes Mole%,MW,and mass fractions are based on weighted average of sales gas analysis collected 5/22/2014 from State Antelope I041-- Source used MW of 116 for C8+. Emissions Summary Table Pollutant Uncontrolled Emission Fa Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 19936.47 lb/MMscf 996.82 lb/MMscf 52.39 tpy 2.62 tpy Gas Analysis Nox 0.07 Ib/MMBTU 0.07 Ib/MMBTU 0.25 tpy 0.25 tpy AP-42 CO 0.37 Ib/MMBTU 0.37 Ib/MMBTU 1.34 tpy 1.34 tpy AP-42 Benzene 54.41 lb/MMscf 2.72 lb/MMscf 286 lb/yr 14 lb/yr Gas Analysis n-Hexane 345.17 lb/MMscf 17.26 lb/MMscf 1814 lb/yr 91 lb/yr Gas Analysis Toluene 43.27 lb/MMscf 2.16 lb/MMscf 227 lb/yr 11 lb/yr Gas Analysis Xylenes 14.29 lb/MMscf 0.71 lb/MMscf 75 lb/yr 4 lb/yr Gas Analysis Ethylbenzene 4.76 lb/MMscf 0.24 lb/MMscf 25 lb/yr 1 lb/yr Gas Analysis 14WE0197.CP2 123/9BDB One low-pressure separator controlled by rune enclosed flares during VRU downtime.Each Bare has a minimum control 009 efficiency of 95%. Equipment Description This source vents natural gas from: a low-pressure separator when the VRU is down Emissions from this source are: routed to a flare (Natural gas venting from a tow-pressure separator when the VRU is down.Emissions from this source are routed to a flare. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II.Chapter 10-Displacement Equation(10.4-3) Ex=O'MW•Xx/C Ex=emissions of pollutant x 0=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 sd/b-mol)at 60F and 1 atm Throughput(O) 2.575878 MMedM I 29405Isct'hr I MW 31.316Bb-md 0.0070572 MMwi/d mole% MW Ibxlbmol mass fraction IWh dyr toy Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.90 CO2 2.51 44.01 1.105 0.035 0.86 7507.71 3.75 _ N2 0.10 28.013 0.028 0.001 0.02 190.39 0.10 __ methane 40.31 16.041 6.467 0.207 5.02 43950.16 21.98 ethane 25.89 30.063 7.764 0.249 6.04 52903.25 26.45 propene 20.27 44.092 8.937 0.288 6.93 60741.88 30.37 isobulane 1.97 58.118 1.144 0.037 0.89 7775.17 3.89 0butane 5.67 58.118 3.293 0.105 2.55 22380.29 11.19 Isopenntene 0.94 72.114 0.675 0.022 0.52 4588.09 229 n-pentane 1.17 72.114 0.846 0.027 0.66 5749.64 2.87 cydopenlane 0.08 70.13 0.058 0.002 0.05 394.66 0.20 n-Hexane 0.23 88.18 0.201 0.006 0.16 1366.49 0.68 cydohexae 0.06 84.16 0.051 0.002 0.04 347.20 0.17 Other heroines xa 0.39 86.18 0.337 0.011 0.26 2290.18 1.15 Impieties 0.18 10021 0.182 0.000 0.14 124024 0.62 �e 0.05 98.19 0.045 0.001 0.04 308.32 0.15 224-TMP 0.00 11423 0.000 0.000 0.00 0.78 0.00 Benzene 0.04 78.12 0.034 0.001 0.03 229.90 0.11 Toluene 0.03 92.15 0.024 0.001 0.02 163.46 0.08 Et ylbenzene 0.00 106.17 0.003 0.000 0.00 18.76 0.01 Aviaries 0.01 106.17 0.006 0.000 0.00 41.85 0.02 cat Heavies 0.10 116 0.114 0.004 0.09 772.63 0.39 VOC mass fox 0.510 Total VOC(Uncontrolled) 5420 Notes Mole%,MW,and mass fractions are based on LP separator gas analysis colected 920/2013 from State Antelope 4144-30HNB Flowyate is based on Promax results and 25%VRU downtime.Emissions are based on 8760 hours of operation per year. Typically I calculate the average MW of C8+based an the average MW on the analysis for the gas.This method resulted in minimal emissions increase Source used MW of 116 for C8+.Since there is minimal difference In emissions,I used the source's values. • 14WE0197.CP2 123/9606 Flaring Information Equipment Description Flare to combust low-pressure separator gas when the VRU is down. Manufacturer Lead and Abutec Model _eed 48"1_30-0010 Serial Number 21142,21143,21730,21734,21728,21729,90001.026,90001.02,9001.27 Gas Heating Value 1783 Btu/scf Throughput 4592.790474 MMBtu/yr VRU Information Equipment Description Engine to recompress tow-pressure separator gas to sales line.The VRU is considered part of the process and not included as an air pollution control devio Make Model Requested Control 100.00% Annual Bypass Tim 25.00% Backup Flare 'Overall Control 95.00%I Combustion emission factor source: AP-42:Chapter 13.5 0.07 NOX/MMBtu 0.37 lib CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 4208616/MMscf 2104.3 lb/MMscf 54.2 tpy 2.7 tpy Gas Analysis Nos 0.07 Ib/MMBTU 0.07 lb/MMBTU 0.2 tpy 0.2[PP AP-42 CO 0.37 lb/MMBTU 0.37 lb/MMBTU 0.8 tpy 0.8 tpy AP-42 Benzene 89.251 lb/MMscf 4.4625 lb/MMscf 230 lb/yr 11 lb/yr Gas Analysis n-Hexane 530.50 lb/MMscf 26.525 lb/MMscf 1366 lb/yr 68 lb/yr Gas Analysis Toluene 63.459 lb/MMscf 3.1730 lb/MMscf 163 lb/yr 8 lb/yr Gas Analysis xylenes 16.248 lb/MMscf 0.8124 lb/MMscf 42 lb/yr 2 lb/yr Gas Analysis Ethylbenzene 7.283 lb/MMscf 0.3642 lb/MMscf 19 lb/yr 1 lb/yr Gas Analysis Regulatory Applicability AOCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' AOCC Regulation 2 Section I.A applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air." 14WE➢197.CP2 123/9BOB One emergency flare used to combust separator gas during emergencies or when the pipeine is not 014 available.Flare has a minimum control efficiency of 95%. The flare is not enclosed. Equipment Description This source vents natural gas from: a eel head separator=when the sales gas pipeline is not available or during emergencies Emissions from this source are: routed to a flare (Natural gas venting from a wel head separator when the sales gas pipeine is not available or during emergencies.Emissions from this source are routed to Calculations Fmission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Cr MW*Xx/C Ex=emissions of polutanl x O=Volumetric flow rateNokime of gas processed MW=Molecular weigh of gas=SG of gas•MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 sof/Ib-mol)at 60F and 1 atm Throughput(0) 15 MMsoVyr I 1712.328767 scabs MW 24 IMb-md J 0.04109589 MMscf/d mole% MW IbxIb of mess fraction IMr Ibryr 1pv Helium 0.01 4.0026 0.000 0.000 0.00 15.84 0.01 CO2 2.22 44.01 0.978 0.041 4.42 38710.22 19.36 N2 0.58 28.013 0.163 0.007 0.74 6449.27 3.22 methane 68.38 16.041 10.968 0.457 49.58 43410174 217.05 ethane 14.39 30.063 4.327 0.180 19.55 171250.83 85.63 propane 8.88 44.092 3.916 0.163 17.69 154982.80 77.49 iscbutane 0.89 58.118 0.518 0.022 2.34 20494.85 10.25 ndh4ane 2.71 58.118 1.572 0.066 7.10 82222.30 31.11 isopentwne 0.51 72.114 0.368 0.015 1.86 14587.41 7.28 n-pentane 0.67 72.114 0.480 0.020 2.17 19008.41 9.50 cydopenlene 0.05 70.13 0.034 0.001 0.18 1362.82 0.68 n-Hexane 0.15 86.18 0.131 0.0055 0.59 5177.82 2.59 cydohexane 0.04 84.16 0.033 0.001 0.15 1309.03 0.65 Other hexanes 025 86.18 0.213 0.003 0.96 8421.31 4.21 heptanes 0.13 10021 0.126 0.005 0.57 4969.52 2.48 netMgclotexane 0.03 98.19 0.031 0.001 0.14 1231.91 0.82 224-TMP 0.00 11423 0.000 0.000 0.00 4.52 0.00 Benzene 0.03 78.12 0.021 0.0009 0.09 81624 0.41 Toxene 0.02 92.15 0.016 0.0007 0.07 649.18 0.32 Etwlbenzane 0.00 106.17 0.002 0.0001 0.01 71.43 0.04 Xylenes 0.01 106.17 0.005 0.0002 0.02 214.30 0.11 C8+Heavies 0.08 116 0.089 0.004 0.40 3530.50 1.77 VOC mass frac 0.315 Total VOC(Uncoraoted) 149.52 No es Mole%,MW,and mass fractions are based on weighted average of sales gas analysis colected 5/22/2014 from State Antelope P41-T44-30HNB and colec Emissions are based on 8760 hours of operation per year. Source used MW of 116 for C8+. • 14WE0197.CP2 123/9808 Flaring Information Equipment Description Flare to combust separator gas when ipeline is not available or during emergencies. Manufacturer TBD Model TBD Serial Number TBD Gas Heating Value, 1379 Btu/scf Throughput 20685 MMI9tu/yr VRU Information-NOT APPLICABLE Equipment Description Engine to recompress gas to sales line. Make Model Requested Control 100.00% Annual Bypass Tin 50.00% Backup Flare 'Overall Control I 95.00A Combustion emission factor source: AP-02:Chapter 13.5 0.07 to NOX/MMBtu I 0.37 Ilb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 19936 lb/MMscf 996.78 lb/MMscf 149.5 tpy 7.5 tpy Gas Analysis Nox 0.07 lb/MMBTU 0.071b/MMBTU 0.7 tpy 0.7 tpy AP-42 CO 0.37 lb/MMBTU 0.3716/MMBTU 3.8 tpy 3.8 tpy AP-42 Benzene 5441616/MMscf 2.72081b/MMscf 816 lb/yr 411b/yr Gas Analysis n-Hexane 345.17 lb/MMscf 17.259 lb/MMscf 5178 lb/yr 259 lb/yr Gas Analysis Toluene 43.279 lb/MMscf 2.1639 lb/MMscf 6491b/yr 321b/yr Gas Analysis Xylenes 14.28716/MMscf 0.7143 lb/MMscf 214 tb/yr 111b/yr _Gas Analysis Ethylbenzene 4762216/MMscf 0.23811b/MMscf 711b/yr 41b/yr Gas Analysis Regulatory Applicability AOCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' AOCC Regulation 2 Section I.A applies to all emission sources.'No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air" 14WE0197.CP2 123/9800 is One vapor recovery tower controied by nine enclosed flares during VRU downtime.Each flare has a minimum control 015 efficiency of 95%. Equipment Description This source vents natural gas from: a vapor recovery tower when the VRU is down Emissions Iron,this source are: routed to a flareNatural gas venting from a vapor recovery tower when the VRU is down.Emissions from this source are routed to a flare. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Pubication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex 60'MW*Xx/C Ex=emissions of polutant x 0=Volumetric flow rate/vohme 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 sd/Ib-mol)at 60F and 1 atm Throughput(0) 0.8317182 MMed(w 94.945 acbhr MW 44.8 Iblb.nd 0.00227888 MMsef d mole% MW IbNbmd mess fraction IMr Ibyr 1py Helium 4.0028 0.000 0.000 0.00 0.00 0.00 CO2 44.01 0.000 0.015 0.17 1484.48 0.74 N2 28.013 0.000 0.030 0.34 2944.38 1.47 methane 16.041 0.000 0.054 0.80 5281.23 2.64 ethane 30.083 0.000 0.181 1.79 15719.80 7.88 propene 44.092 0.000 0.250 2.80 24495.67 12.25 isabutane 58.118 0.000 0.036 0.41 3565.93 1.78 n-butane 58.118 0.000 0.120 1.34 11774.38 5.89 iscpentane 72.114 0.000 0.027 0.30 2681.20 1.33 npentane 72.114 0.000 0.034 0.38 3383.78 1.88 cydoPentane 70.13 0.000 0.017 0.19 1847.39 0.82 nHexene 86.18 0.000 0.052 0.58 5091.02 2.55 c/ddiexene 84.16 0.000 0.015 0.17 1498.58 0.75 Otherhexares 86.18 0.000 0.099 1.11 9694.99 4.85 heptanes 10021 0.000 0.038 0.43 378028 1.88 methylcydohexane 98.19 0.000 0.012 0.13 1180.88 0.59 224-TMP 11423 0.000 0.002 0.03 243.42 0.12 Benzene 78.12 0.000 0.009 0.10 837.80 0.42 Toluene 92.15 0.000 0.006 0.07 812.36 0.31 EfMbenzene 106.17 0.000 0.001 0.01 5825 0.03 Xytpes 106.17 0.000 0.002 0.02 162.85 0.08 Ca+Heavies 137.4837288 0.000 0.019 0.21 1861.35 0.93 VOC mass free 0.741 Total VOC(Uncontrolled) 36.25 Notes Mass fractions are based on Promax results for the VRT stream Flowers is based on Promax results and assuming 25%downtime for VRU.Emissions are based on 8760 hours of operation per year. 14WE0197.CP2 123/9808 Flaring Information Equipment Description Flare to combust VRT gas when the VRU is down. Manufacturer Leed and Abutec Model and 48"L30-0010 Serial Number 21142,21143,21730,21734,21728,21729,90001.026,90001.02,9001.27 Gas Heating Value 2415 Btu/scf Throughput 2008.599453 MMBtu/yr VRU Information-NOT APPLICABLE Equipment Description Engine to recompress VRT gas to sales line.The VRU is considered part of the process and not included as an air pollution control device. Make Model Requested Control 100.00% Annual Bypass Tin 25.00% Backup Flare 'Overall Control I 95.00%4 Combustion emission factor source: AP-42:Chapter 13.5 0.07 lib NOX/MMBtu 0.37 CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 87169 lb/MMscf 4358.4 lb/MMscf 36.2 tpy 1.8 tpy Gas Analysis Nox 0.07 lb/MMBTU 0.07 lb/MMBTU 0.1 tpy 0.1 tpy AP-42 CO 0.37 lb/MMBTU 0.37 lb/MMBTU 0.4 tpy 0.4 tpy AP-42 Benzene 1007.1 lb/MMscf 50.354 lb/MMscf 838 lb/yr 42 lb/yr Gas Analysis n-Hexane 6121.1 lb/MMscf 306.05 lb/MMscf 5091.lb/yr 255 lb/yr Gas Analysis Toluene 736.25 lb/MMscf 36.813 lb/MMscf 61216/yr 31 lb/yr Gas Analysis Xylenes 195.80 lb/MMscf 9.7901 lb/MMscf 163 lb/yr 8 lb/yr Gas Analysis Ethylbenzene 70.039 lb/MMscf 3.5020 lb/MMscf 58 lb/yr 3 lb/yr Gas Analysis 224-TMP 292.67 lb/MMscf 14.6336 lb/MMscf 243 lb/yr 12 lb/yr Gas Analysis Regulatory Applicability AOCC Regulation 1 This source is subject to the opacity requirements for flares in Section ILA.5'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' AOCC Reoulation 2 Section IA applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air." 14WE0197.CP2 123/9308 One low-pressure separator controlled by nine enclosed flares during VRU downtime.Each flare has a minimum control 016 efficiency of 95%. Equipment Description This source vents natural gas from: a low-pressure separator when the VRU is down Emissions from this source are: routed to a flare 'Natural gas venting from a low-pressure separator when the VRU is down.Emissions from this source are routed to a flare. Calculations - Fmissinn Calculatbn Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=O•MW•Xx IC Ex=emissions of polutant x 0=Volumetric Sow ratehrolume 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 sd/lb-mol)at 60F and 1 atm Throughout(0) 125 MMscf/yr 1425940639 ser/hr MW 34.5 Ib1b-mol 0.003424858 MMacf/d rode% MW t.Mbmd mass fraction Ils/hr Ibyr by Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.00 C02 2.54 44.01 1.118 0.032 0.42 3656.85 1.04 N2 0.13 28.013 0.036 0.001 0.01 120.11 0.06 methane 35.58 16.041 5.720 0.168 2.15 18856.96 9.43 ethane 22.95 30.063 6.901 0.200 260 22750.13 11.38 propane 21.87 44.092 9.642 0.279 3.63 3180208 15.90 isobaane 2.58 58.118 1.487 0.043 0.56 4905.53 245 n-butane 8.11 58.118 4.712 0.137 1.77 15540.62 7.77 isopenta.e 1.59 72114 1.150 0.033 0.43 3791.48 1.90 n-pentane 2.08 72.114 1.502 0.044 0.57 4953.32 2.48 cydopenlane 0.15 70.13 0.103 0.003 0.04 338.15 0.17 n-Hexane 0.48 86.18 0.418 0.0121 0.16 1377.40 0.59 cydohexene 0.13 84.16 0.108 0.003 0.04 355.02 0.18 Other hexarws 0.80 86.16 0.689 0.020 0.26 2273.31 1.14 heptanes 0.41 10021 0.411 0.012 0.15 1356.73 0.88 mehylccbhexane 0.10 98.19 0.102 0.003 0.04 335.18 0.17 224TMP 0.00 11423 0.000 0.0000 0.00 0.75 0.00 Benzene 0.09 78.12 0.067 0.0019 0.03 219.78 0.11 Toluene 0.06 92.15 0.053 0.0015 0.02 174.15 0.09 EMyiberaene 0.01 106.17 0.006 0.0002 0.00 18.91 0.01 Xyaps 0.02 106.17 0.017 0.0005 0.01 54.63 0.03 C8+Heavies 0.25 116 0.292 0.008 0.11 964.50 0.48 VOC mass frac 0.6017 Total VOC(Uncontrolled) 34.23 Mole Mole%,MW,and mass max r tics-Guns are based on LP separator gas analysis each d 5/22/2014 from State Antelope P41-T44-30HNB Fbveate Is based on Promax results„adjusted for expected production from separator,and 25%VRU downtime.Emissions are based on 6750 hours Typically I calculate the average MW of C8+based on the average MW on the analysis for the gas.This method resulted in minimal emissions increase Source used MW of 116 for CB+.Since there is minimal difference in emissions,I used the source's values. 14WE0197.CP2 123/99DB Flaring Information Equipment Description Flare to combust low-pressure separator gas when the VRU is down. Manufacturer Lead and Abutec Model _eed 48"L30-0010 Serial Number 21142,21143,21730,21734,21728,21729,90001.026,90001.02,9001.27 Gas Heating Value 1951 Btu/scf Throughput 2445 MMBIu/yr VRU Information-NOT APPLICABLE Equipment Description Engine to recompress low-pressure separator gas to sales line.The VRU is considered part of the process and not included as an air pollution control devio Make Model Requested Control Efficiency Annual Bypass Time Backup I Flare Overall Control I 95.00A Combustion emission factor source: AP-42:Chapter 13.5 0.07 NOX/MMBtu 0.37 jIb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 54769 lb/MMscf 2738.5 lb/MMscf 34.2 spy 1.7 spy Gas Analysis Nos 007 lb/MMBTU 0.07 lb/MMBTU 0.1 spy 0.1 tpy AP-42 CO 0,37 lb/MMBTU 0.37 lb/MMBTU 0.5 spy 0.5 tpy AP-42 Benzene 175,82 lb/MMscf 8.7911 lb/MMscf 220 lb/yr 11 lb/yr Gas Analysis n-Hexane 1101.9 lb/MMscf 55.096 lb/MMscf 1377 lb/yr 69 lb/yr Gas Analysis Toluene 139.32 lb/MMscf 6.9660 lb/MMscf 174 lb/yr 9lb/yr Gas Analysis xylenes 43.70d lb/MMscf 2.1850 lb/MMscf 55 lb/yr 3 lb/yr Gas Analysis Ethylbenzene 15.127 lb/MMscf 0.7564 lb/MMscf 19 lb/yr 11b/yr Gas Analysis Regulatory Applicability AOCC Regulation I This source is subject to the opacity requirements for flares in Section ll A.5'No owner or operator of a smokeless Flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' AOCC Regulation 2 Section IA applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air." 14VJE0197.CP2 123/9BDB at One low-pressure separator controlled by nine enclosed flares during VRU downtime.Each flare has a minimum control 017 efficiency of 95%. Equipment Description This source vents natural gas from: a bw-pressure separator when the VRU is down Emissions from this source are: routed to a flare Natural gas venting from a low-pressure separator when the VRU is down.Emissions from this source are routed to a flare. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q•MW•Xx IC Ex=emissions of pollutant x Q=Volumebic 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 sdM-mol)at 60F and 1 atm Throughput(0) 1.15 MMscfNr 131.2785388 sd/hr MW 34.5 IbIbmd 0.003150685 MMscffd mole% MW bx8bmol mass fraction lb/hr IWyr qty Helium 0.00 4.0026 0.000 0.000 0.00 - 0.00 0.00 00'2 2.54 44.01 1.118 0.032 0.39 3391.91 1.70 N2 0.13 28.013 0.036 0.001 0.01 110.50 0.06 methane 35.66 16.041 5.720 0.166 1.98 17357.80 8.68 ethane 22.95 30.063 6.901 0.200 2.39 20939.32 10.47 propane 21.87 44.092 9.642 0.279 3.34 29257.92 14.63 iscbuta a 2.58 58.118 1.487 0.043 0.52 4513.09 2.26 (=butane 8.11 58.118 4.712 0.137 1.63 14297.37 7.15 isopentane 1.59 72.114 1.150 0.033 0.40 3488.14 1.74 naemmne 2.08 72.114 1.502 0.044 0.52 4557.05 2.28 cydopentane 0.15 70.13 0.103 0.003 0.04 311.11 0.16 n-Hexane 0.43 86.18 0.418 0.012 0.14 1267.21 0.63 cyddlexane 0.13 84.16 0A08 0.003 0.04 326.61 0.16 Other heanes 0.80 86.18 0.889 0.020 0.24 2091.45 1.06 hectares 0.41 10021 0.411 0.012 0.14 124820 0.62 melhylcyclohexane 0.10 98.19 0.102 0.003 0.04 308.37 0.15 224-TMP 0.00 114.23 0.000 0.000 0.00 0.89 0.00 Benzene 0.09 78.12 0.067 0.0019 0.02 202.19 0.10 Toluene 0.08 9215 0.053 0.0015 0.02 160.22 0.08 Elhylbenzana 0.01 108.17 0.008 0.0002 0.00 17.40 0.01 Xylenes 0.02 106.17 0.017 0.0005 0.01 50.26 0.03 C8+Heavies 0.25 116 0.292 0.0095 0.10 887.34 0.44 VOC mass frac 0.602 Total VOC(Uncontrolled) 31.49 totfl$ Mole%,MW,and mass fractions are based on LP separator gas analysis corrected 5/22/2014 from State Antebpe P41-744-30HNB Flowrate is based on Promax results„adjusted for expected production from each separator,and 25%VRU downtime.Emissions are based on 8760 hours Typically I calculate the average MW of C8+based on the average MW on the analysis for the gas.This method resulted in minimal emissions increase Source used MW of 116 for 08+.Since there is minimal difference in emissions,I used the source's values. 14WE0197.CP2 123/9606 Flaring Information Equipment Description Flare to combust low-pressure separator gas when the VRU is down. Manufacturer Leed and Abutec Model _eed 48"130-0010 Serial Number 21142,21143,21730,21734,21728,21729,90001.026,90001 02,9001.27 Gas Heating Value 1956 Btu/scf Throughput 2249.4 MMBtu/yr VRU Information-NOT APPLICABLE Equipment Description Engine to recompress low-pressure separator gas to sales line.The VRU is considered part of the process and not included as an air pollution control devio Make Model Requested Control 100.00%Annual Bypass Tier 25.00% Backup Flare 'Overall Control I 9500%I Combustion emission factor source: AP-42:Chapter 13.5 0.07 IIb NOX/MMBIu 0.37 jib CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOL 54769 lb/MMscf 2738.5 lb/MMscf 31.5 spy 1.6 tpy Gas Analysis Nos 0.07 lb/MMBTU 0.07 lb/MMBTU 0.1 tpy 0.1 tpy AP-42 co 0.37 lb/MMBTU 0.37 lb/MMBTU 0.4 toy 0.4 tpy AP-42 Benzene 175.82 lb/MMscf 8.7911 lb/MMscf 2021b/yr 10 lb/yr Gas Analysis n-Hexane 1101.9 lb/MMscf 55.096 lb/MMscf 1267 lb/yr 63 lb/yr Gas Analysis Toluene 139.32 lb/MMscf 6.9660 lb/MMscf 160 lb/yr 8 lb/yr Gas Analysis Xylenes 43.701 lb/MMscf 2.1850 lb/MMscf 50 lb/yr 3Ib/yr Gas Analysis Ethylbenzene 15.127 lb/MMscf 0.7564 lb/MMscf 17 lb/yr 1lb/yr Gas Analysis Regulatory Applicability AOCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' AOCC Regulation 2 Section I.A applies to all emission sources.'No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air.' 14WE0197.CP2 123/9505 One low-pressure separator controlled by nine enclosed flares during VRU downtime.Each flare has a minimum control 018 efficiency of 95%. Equipment Description This source vents natural gas from: a low-pressure separator when the VRU is down Emissions from this source are: routed to a flare Natural qas venting from a low-pressure separator when the VRU is down.Emissions from this source are muted to a flare. Calculations . Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II.Chapter 10-Displacement Equation(10.4-3) Ex=O'MW•Xx/C Ex=emissions of polulant x 0=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gar MW of air Xx=mass fraction of x In gas C=molar volume of Ideal gas(379 sd/b-mol)at 60F and 1 atm Thmugtput(CO 0.9 MMscfNr 102.739726 scf/hr MW 34.51b1Wnd 0.002465753 MMsef/d male% MW Ibxfib of mass fraction IMx Ibyr ON I Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.00 C02 2.54 44.01 1.118 0.022 0.30 2654.53 1.33 N2 0.13 28.013 0.036 0.001 0.01 86.48 0.04 methane 35.68 16.041 5.720 0.186 1.55 13584.21 6.79 ethane 22.95 30.063 6.901 0.200 1.87 1638729 8.19 propane 21.87 - 44.092 9.642 0.279 2.61 22897.50 11.45 isobutne 2.58 58.118 1.487 0.043 0.40 3531.98 1.77 n-butane 8.11 58.118 4.712 0.137 1.28 1118925 5.59 iscpentane 1.59 72.114 1.150 0.033 0.31 2729.85 1.38 n-penlane 2.08 72.114 1.502 0.044 0.41 3568.39 1.78 cydapentane 0.15 70.13 0.103 0.003 0.03 243.48 0.12 n-Rexene 0.48 88.18 0.418 0.012 0.11 991.73 0.50 cycbhexane 0.13 84.16 0.108 0.003 0.03 255.61 0.13 Other hexanes 0.80 86.18 0.889 0.020 0.19 1636.78 0.82 heptanes 0.41 10021 0.411 0.012 0.11 975.85 0.49 methylcldohexane 0.10 98.19 0.102 0.003 0.03 241.33 0.12 • 224-TMP 0.00 114.23 0.000 0.000 0.00 0.54 0.00 Benzene 0.09 78.12 0.067 0.002 0.02 158.24 0.08 Toluene 0.06 92.15 0.053 0.002 0.01 125.39 0.08 Ethylbenzane 0.01 106.17 0.006 0.000 0.00 13.81 0.01 Xylenee 0.02 106.17 0.017 0.000 0.00 39.33 0.02 08+Heavies 0.25 116 0.292 0.006 0.08 694.46 0.35 VOC mass frac 0.602 Total VOC(Uncontrolled) 24.65 tholes Mole%.MW,and mass fractions are based on LP separator gas analysis colected 5/22/2014 from State Antelope P41-T44.30NN8 Floverate is based on Promax results„adjusted for expected production from each separator,and 25%VRU downtime.Emissions are based on 8760 hours Typic ally I calculate the average MW of O8+based on the average MW on the analysis for the gas.This method resulted in minimal emissions increase Source used MW of 116 for CEP.Since there is minimal difference in emissions.I used the source's values. 14WE0197.CP2 123/9608 Flaring Information Equipment Description Flare to combust low-pressure separator gas when the VRU is down. Manufacturer Leed and Abutec Model _eed 48"L30-0010 Serial Number 21142,21143,21730,21734,21728,21729,90001.026,90001.02,9001.27 Gas Heating Value 1956 Btu/scf Throughput 1760.4 MMBtu/yr VRU Information-NOT APPLICABLE Equipment Description Engine to recompress low-pressure separator gas to sales line.The VRU is considered part of the process and not included as an air pollution control devic Make Model Requested Control 100.00% Annual Bypass Tim 25.00% Backup Flare 'Overall Control I 95.00%' Combustion emission factor source: AP-42:Chapter 13.5 0.07 jIb NOX/MMBtu 0.37 llb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source V0C 54769 lb/MMscf 2738.5 lb/MMscf 24.6 tpy 1.2 tpy Gas Analysis Nos 0.07 lb/MMBTU 0.0716/MMBTU 0.1 tpy 0.1 tpy AP-42 CO 0.37 lb/MMBTU 0.3716/MMBTU 0.3 tpy 0.3 tpy AP-42 Benzene 175.82 lb/MMscf 8.7911 Ib/MMscf 1581b/yr 5 lb/yr Gas Analysis n-Hexane 1101.9 lb/MMscf 55.096 Ib/MMscf 992 lb/yr 50 lb/yr Gas Analysis Toluene 139.32 lb/MMscf 6.9660 lb/MMscf 125 lb/yr 6 lb/yr Gas Analysis %ylenes 43.701 lb/MMscf 2.1850 lb/MMscf 39 lb/yr 2 lb/yr Gas Analysis Ethylbenzene 15.127 lb/MMscf 0.7564 lb/MMscf 14 lb/yr 1 lb/yr Gas Analysis Regulatory Applicability AOCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' AOCC Reoulation 2 Section I.A applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air" 14WE0197.CP2 123/9BOB One low-pressure separator controlled by nine enclosed flares during VRU downtime.Each flare has a minimum control 019 efficiency of 95%. Equipment Description This source vents natural gas from: a low-pressure separator when the VRU is down Emissions from this source are: routed to a flare (Natural gas venting from a low-pressure separator when the VRU is down.Emissions from this source are routed to a flare. Calculations Emission Calculation Methoq EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(104-3) Ex=O'MW'Xx/C _ Ex=emissions of pollutant x 0=Volumetric flow rale/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 scfM-mol)at 60F and 1 stm Throughput(0) 1.15 MMscfM 131.2785388 actor MW 34.5 Iblbmd 0.003150885 MMad/d mole% MW lbMbnol mess fraction Mr Ibyr Ipy Helium 0.00 4.0026 0.000 0000 0.00 0.00 0.00 C02 2.54 44.01 1.118 0.032 0.39 3391.91 1.70 N2 0.13 28.013 0.036 0.001 0.01 110.50 0.06 methane 35.88 16.041 5.720 0.166 1.98 17357.60 8.68 ethane 22.95 30.063 6.901 0.200 2.39 20939.32 10.47 propene 21.87 44.092 9.642 0.279 3.34 29257.92 14.83 isobutane 2.56 58.118 1.487 0.043 0.52 4513.09 2.26 nbulane 8.11 56.118 4.712 0.137 1.83 14297.37 7.15 iscpentane 1.59 72114 1.150 0.033 0.40 3488.14 1.74 n-pentane 2.08 72114 1.502 0.044 0.52 4557.05 2.28 cydoPentane 0.15 70.13 0.103 0.003 0.04 311.11 0.16 n-Hexane 0.48 86.18 0.418 0.012 0.14 1287.21 0.63 cydohexane 0.13 84.16 0.108 0.003 0.04 326.61 0.16 Other hexanes 0.80 86.18 0.689 0.020 0.24 2091.45 1.05 heptanes 0.41 10321 0.411 0.012 0.14 1248.20 0.62 methylcydahexane 0.10 98.19 0.102 0.003 0.04 308.37 0.15 224-TMP 0.00 11423 0.000 0.000 0.00 0.69 0.00 Benzene 0.09 78.12 0.067 0.002 0.02 202.19 0.10 Toluene 0.06 92.15 0.053 0.002 0.02 160.22 0.08 EMNbenzene 0.01 106.17 0.006 0.000 0.00 17.40 0.01 Xylenes 0.02 106.17 0.017 0.000 0.01 50.28 0.03 C8+Heavies 025 118 0.292 0.008 0.10 887.34 0.44 VOC mass frac 0.602 Total VOC(Unconedled) 31.49 Nolen Mole%,MW,and mass fractions are based on LP separator gas analysis collected&22/2014 from State Antelope P41-T44JOHN8 Roseate is based an Promax results„adjusted for expected production from each separator,and 25%VRU downtime.Emissions are based an 8760 hours Typically I calculate the average MW of C8+based on the average MW on the analysis for the gas.This method resulted in minimal emissions increase Source used MW of 116 for C8+.Since there is minimal difference in emissions,I used the sources values. 14WE0197.CP2 123/9B0B Flaring Information Equipment Description Flare to combust low-pressure separator gas when the VRU is down. Manufacturer Leed and Abutec Model _eed 48'L30-0010 Serial Number 21142,21143,21730,21734,21728,21729,90001.026,90001.02,9001.27 Gas Heating Value 1956 BWlscf Throughput 224941 MMBtu/yr VRU Information-NOT APPLICABLE Equipment Description Engine to recompress low-pressure separator gas to sales line.The VRU is considered part of the process and not included as an air pollution control devio Make Model Requested Control 100.00% Annual Bypass Tirr 25.00% -Backup Flare Overall Control I 95.00%I Combustion emission factor source: AP-42:Chapter 13.5 0.07 jib NOX/MMBtu 0.37 ]tb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VCC 54769 Ib/MMscf 2738.5 lb/MMscf 31.5 tpy 1.6 toy Gas Analysis Noy 0.071b/MMBTU 0.07 lb/MMBTU 0.1 tpy O.1 MY AP-42 CO 0.37 Ib/MMBTU 0.37 lb/MMBTU 0.4 tpy 0.4 toy AP-42 Benzene 175821b/MMscf 8.7911 lb/MMscf 202 lb/yr 10 lb/Yr Gas Analysis n-Hexane 1101.916/MMscf 55.096 lb/MMscf 1267 lb/yr 63 lb/VF Gas Analysis Toluene 139.32 Ib/MMscf 6.9660 lb/MMscf 160 lb/yr 5 lb/yr Gas Analysis xylenes 43.7011b/MMscf 2.1850 lb/MMscf 50 lb/yr 3 lb/yr Gas Analysis Ethylbenzene 15.127 lb/MMscf 0.7564 lb/MMscf 17 lb/yr 1 lb/Yr Gas Analysis Regulatory Applicability AOCC Regulation 1 This source is subject to the opacity requirements for flares in Section I I.A.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' AOCC Regulation 2 Section I.A applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air." 14WE0197.CPz 123/9BDB mole% mole% average Helium 0.0100 0.0100 0.0100 CO2 2.3300 2.1800 2.2550 N2 0.4900 0.6200 0.5550 methane 66.3815 69.1003 67.7409 ethane 16.7170 13.5095 15.1133 propane 9.5812 8.6139 9.0976 isobutane 0.8351 0.9117 0.8734 n-butane 2.3285 2.8458 2.5872 isopentane 0.3718 0.5621 0.4670 n-pentane 0.4633 0.7417 0.6025 cyclopenta 0.0330 0.0552 0.0441 n-Hexane 0.0930 0.1739 0.1335 cyclohexar 0.0240 0.0451 0.0346 Other hexa 0.1551 0.2838 0.2195 heptanes 0.0735 0.1459 0.1097 methylcycli 0.0182 0.0367 0.0275 224-TMP 0.0001 0.0001 0.0001 Benzene 0.0172 0.0298 0.0235 Toluene 0.0109 0.0204 0.0157 Ethylbenze 0.0011 0.0019 0.0015 Xylenes 0.0034 0.0058 0.0046 C8+Heavi 0.0416 0.0856 0.0636 AIRS(County/Plant)123/9600 Permit No.14W E0197 Date 1/7/2015 Controlled Controlled Actual Requested NCRP= Uncontrolled Emission Emissions Emissions CM. reportable Point A SCC Pollutant or CAS Factor Emisison Factor Source ppyl• (tpy)• PTE(tpyy EX% VOC 6.0106 lb/1000 gallon Promax 2.6 3.2 63.6 95% Yes _ NOx 0.068 lb/Mmbtu AP-42 Table 135 0.1 0.1 0% No 0O 0.37 Ib/Mmbtu AP-42 Table 13.5 0.8 0.8 0% No Benzene 0.0271 lb/1000 gallon Promax 2 29 573 95% Yes 004 40400311 n-Hexane 0.1674 lb/1000 gallon Promax 14 177 3541 95% Yes Toluene 0.0214 lb/1000 gallon Promax 1 23 453 95% Yes Elbylbenzene 0.00231W1000 gallon Promax 2 48 95% No Xylenes 0.0068 lb/1000 gallon Promax 7 145 95% No 224-TMP 0.01641W1000 gallon Promax 1 17 347 95% Yes VOC 6.238 lb/1000 gallon COPHE 2.3 45.3 95% Yes 005 40400315 Benzene 0.167 lb/1000 gallon COPHE 121 2422 _ 95% Yes n-Hexane 0.524 lb/1000 gallon COPHE 381 7612 95% Yes / VOC 3094 lb/1000 gallon AP-42 11 32.7 66% Yes Benzene 0.023 lb/1000 gallon AP-42 162 484 66% Yes 006 40600132 n-Hexane 0.182 lb/1000 gallon AP-42 1291 3853 66% Yes Toluene 0.01510/1000 gallon AP-42 106 316 p 66% Yes Etbylbenzene 0.002 lb/1000 gallon AP-42 10 29 66% No Xylenes 0.005 lb/1000 gallon-AP-42 32 94 166% No Standard EFs-EPA-453/R-95- VOC 017 Table 2-4 24.4 24.4 0% Yes Standard EFs-EPA453/R-95- Benzene 017 Table 2-4 276 276 0% Yes Standard EFs-EPA453/R-95- 007 31000220 n-Hexane 017 Table 24 1651 1651 0% Yes • Standard EFs-EPA453/R-95- Toluene 017 Table 2-4 539 539 0% Yes Standard EFs-EPA453/R-95- Etbylbenzene 017 Table 2-4 137 137 0% No Standard EFs-EPA453/R-95- XNenes 017 Table 24 450 450 0% Yes VOC 19936 lb/MMsd Gas Analysis 2.6 52.4 '. 95% Yes NOx 0.068 lb/MMBTl1 AP-42 0.2 0.2 0% No CO 0.37 lb/MMBTO AP-42 1.3 1.3 0% Yes Benzene 54.409 lb/MMsd Gas Analysis 14 286 _ 95% Yes 008 31000299 n-Hexane 345.175 lb/MMscf Gas Analysis i 91 1814 95% Yes AIRS(County/Plant)1231BBDB Pam*No.14WE0197 Date 1/7/2015 Controlled Controlled Actual Requested NCRP= Uncontrolled Emission Emissions Emissions CM. reportable Paint# SCC Pollutant or CAS Factor Emkem Factor Source (¢y)' (ipyy PTE(tpyl' EB% 7 Triune J 43214 Ib#AMacl Gas Analysis 11 227 95% No Ethylbenzene 4.7621bMMsd Gas Analysis 1 25 95% No %yips 14.267 b%lMad Gas Analysis 4 75 95% No VOC 42088 Ib7AMsd Gas Analyse 2.7 54.2 95% Yes NOx 0.068 bMMBTU AP-42 02 0.2 0% No CO 0.37 IMMMBTU AP-42 0.8 0.8 0% No Benzene 69]51 Ib/ Med Gas Analysis 11 230 95% No 009 31000205 nNeme 530.509JMMed Gas Analysis 68 1366 95% Yes Toluene 63.459 blMMedd Gas Analysis8 163 95% No EOytbenzene 7.283 bIMGasMed G Analyse 19 19 95% No Xylens 16.248 tMMacf Gas AaNsis 2 42 95% No VOC 19938 9YMMacf Gas Analysis 7.5 149.5 95% Yes NOx 0.088 I MMBTU AP-42 0.7 0.7 0% No CO 0.37 bMMBTU AP-42 3.8 3.8 0% Yes Baron as yyi Yes 54.409 IMMMed G As 41 816 95% 14 31000205 n-Nsane 345.175 lb/lAlhed Ges Analysis 259 5178 95% Yes Toluene 43.2741blMsof Gas Analysis 32 649 95% Yes Ethylbszene 4.762 'MAMsd Gas Analysis 4 71 95% No %yams 14.287 IMAMsl Gas Maysis 11 214 95% No . VOC 07169 lbIAMad Gas Analysis 1.8 36.2 95% Yes NOx 0.07 IMMMBTU AP-42 0.1 0.1 0% No CO 0.37 Ib7AMBTU PP-42 0.4 0.4 0% No Beene 1007.1 IMAMed Gas G Analyse Yes 42 838 95% 15 31000205 n-Hexane 6121.1 lb/MMsd Gas Analysis 255 5091 95% Yes Triune 736.251bMMed Gas Analyse 31 812 95% Yes Ethylbentene 70.039 lb/MMect Gas Mays 3 58 95% No Xylens 195.80 IbMMed Gas Analysis 8 163 95% No VOC 54769 bAMed Gsa Analyse 1.7 34.2 95% Yes NOx 0.07 bMMBTU AP-42 0.1 0.1 0% No CO 0.37 bNMBTU AP-42 0.5 0.5 0% No Benzene 175.62 dM 16 31000205 Mad AnalysisGoreAnalysis11 220 95% No n-Nexane 1101.9 t/MMscf Gas Anayds 69 1377 95% Yes Toluene 139.32 bMMed Gs Analyse 9 174 95% No Eerylbenzaoe 15.127 MMed Gas Analysis 19 95% No XMelee I 43.701 bMMed Gas Analyse 3 55 95% No AIRS(County/Plant)123/9600 Pemlit No.14WE019] Date 1/7/2015 Controlled Controlled Actual Requested NCRP= Uncontrolled Emission Emissions Emissions Ctrl. reportable Pointe SCC Pollutant or CAS Factor Emisison Factor Source JIuvY POW PTE ttpvY Eff% ] VOC 547691b/MMsct Gas Analysis 1.6 31.5 95% Yes NOx 007 lb/MMDTU AP-42 0.1 0.1 0% No CO 0.37 lb/MMETU AP-42 0.4 0.4 0% No 17 31000205 Benzene 175.82 Ib/MMsct Gas Analysis 10 202 95% No n-Hexane 1101.91bRAMscf Gas Analysis _ 63 1267 95% Yes Toluene 139.321b/MMsct Gas Analysis 8 160 95% No Et0ylbenzene 15.12]IbIMMscf Gas Analysis 1 17 95% No Xylenes 43.701 lb/MMscf Gas Analysis 3 50 95% No _ VOC 54769 lb/MMsd Gas Analysis _ 1.2 24.6 95% Yes NOx 0.07 Ib/MMBTU AP-42 0.1 0.1 0% No CO 0.37 IbIMMBTU AP-42 0.3 0.3 0% No Benzene 175.821blMMscf Gas Analysis 8 158 95% No 18 31000205 n-Hexane 1101.9 lb/MMscO Gas Analysis 50 992 95% Yes Toluene 139.321btlMscf Gas Analysis 6 125 95% No Elhylbenzene 15.127 b/MMsc1 Gas Analysis1 14 95% No Xylenes i 4370110IMMsc1 Gas Analysis 2 39 95% No VOL 54769 lb/MMscf Gas Analysis 1.6 31.5 95% _Yes _ NOx 0.07 lb/MMBTU AP-42 0.1 0.1 0% No OO 0.37 lb/MMBTU AP-42 0.4 0.4 0% No 19 31000205 Benzene 175.82 lb/MMscf Gas Analysis 10 202 95% No n-Hexane 1101.91bAr1Mscf Gas Analysis 63 1267 95% Yes Toluene 139.321btMMscf Gas Analysis 8 160 95% No Elbylbenzene 15.127 lb/MMsd Gas Analysis 1 17 95% No Xylenes I 43.701 lb/MMscf Gas Analysis 3 50 95% No Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CRUDE Om STORAGE TANK BATTERY_ Current Status(Check all that apply) Reason for APEN Submittal(Check all that apply) JJt1'^ - AIRS ID#': 123/9BDB/004 ❑ APEN update only° `... ❑ New or previously unreported battery ® Modification to existing sources ❑ Previously grandfathered battery2 ❑ Registration for coverage under general permit no.GPM. ❑ Synthetic minor facility &cancellation request for individual permits: Ni Located in the 8-hr Ozone Control Areas El Application for or Modification of an individual permit ® Registered under general permit no.GPOI ❑ Administrative permit amendment ❑ Permitted under individual permit: I oW EQ1147 ® Other: Reouest for individualpermit and.cancellation of coverage under GPOI. For individual permit applications,check if you wants: ®A copy of the preliminary analysis conducted by the Division ®To review a draft of the permit prior to issuance Company Names: Bonanza Creek Energy Operating Company LLC OGCC Operator#: 8960 _ Mailing Address1s: 410 17t°Street,Suite 1500 City: Denver State: CO Zip: 80202 E-mail: pyoung@BonanzaCrk.com Contact Name: Peg Young Phone: 720-440-6133 Fax: 720-279-2331 Tank Battery Name": State Antelope P-30 Production Facility(COGCC#433004) Number of tanks: 15 -500 bbl Location12(QQ Sec.Twp.Range.): NE/NE,Sec 30,T5N,R62W County: Weld Total tank capacity[bbl]: 7,500 Calendar year for which"Actual"data applies1s: NA Year(s)tank(s)were placed in service1°: 3-2013 and 12-2014 Six(6)Leed L30-0010(SN:21142,21143,21730,21734,21728,&21729) Control Descriptions: and Three(3)Abutec(SN:90001.026,90001.02,&9001.27) Control Effrciency1s: 95% Condensate Throughput"[bbl/year] Requested": 503,700 Maximum for PTE calculation's: 503,700 _ Actual3s: 419,750 While Controls Operational21 419,750 Other equipment at facility22: Heated separators,produced water tanks,natural gas-fired engines,pneumatic pump,vapor recovery tower Request for individual permit and cancellation of coverage under GPOI.2-yr APEN update not required(uncontrolled VOC Comments: emissions<80 tpy) Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit ❑Check if the Division is to calculate emissions. ®Check if site-specific emission factors provided to calculate emissions23. Emission Factor Battery Requested Emission's Actual Emissions20 4 25 2fi 27 26 27 Pollutan [lb/bbl] PTE Uncontrolled Controlled Uncontrolled Controlled 2", VOC[tons/year] 0.25 / 63.58 63.58 ,/ 3.18 - 52.98 - 2.65 NOx[tons/year] 0.14 " 0.12 CO[tons/year] 0.77 , 0.66 Benzene[lbs/year] 0.001 / 572.7 572.7 / 28.6 - 477.3 ./ 23.9 ; n-Hexane[lbs/year] 0.007 '' 3,540.8 3,540.8 = 177.0 - 2,950.6 ./ 147.5 ✓ Wells serviced by this tank or tank batter? API#: 05-123-37406 Name: State Antelope 41-44-3OHNB ❑Newly Reported Well API#: 05-123-38589 Name: State Antelope U-Y-3OHNB ®Newly Reported Well API#: 05-123-38588 Name: State Antelope U41-Y44-301NB ®Newly Reported Well API#: 05-123-38587 Name: State Antelope P-T-3OHNB ®Newly Reported Well API#: 05.123-38590 Name State Antelope P41-T44-30HNB ®Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: ❑Newly Reported Well The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of my knowledge and belief. If this is a registration for coverage under general permit GPOI,I further certify that this source is and will be operated in full compli5naewith each condrti feral permit GPOI. / -etrwl Signature of Legally Aut'rized Person(not a vendor or consultant) Date David J.Lillo Vice President,Rocky Mtn.Asset Mgmt. Type or Print Name of Person Signing Above Official Title Submit this form,along with$152.90 for each Colorado Department of Public Health and Environm t For information call: filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-B1 $281 (303)692-3150 $250 General Permit fee for each new GP 4300 Cherry Creek Drive South registration to: Denver,CO 80246-1530 FORM APCD-205 Page 1 of 2 FormAPCD-205-E&PCondensateTankAPEN.docz $To co § 7 % il- o c � � / O a ) 0 \ M _ Z Lu 7 § , . 0 7 a o . a < ) • ` J w CO ( \ 75 \ \ / E 9 e / ) f , CC 2 Z « a < O 0 _ - ~ r . . . c 0 Z 2 $ § § \ { - - / § § Ts k ) o m [ 2 C02 . 8 2 m ; j \ 0 - O k \ 0 5 k E \ c § / A . . w a § x k k CO I ZE . _ � � - I- ( so �4\ D | . 0 2 o \` / � —1 -(e) u k § 2 ) . _ - - % �.a c kf \ -� k re__ v [ = o CO ' « J c @ � E § r ) E § i % I- \ \ \ q \) § ( .1- / f te > 2 + I / _ . 0 / E •� ' O . b 92 y ) 0 ~ \ / a. ar CO / o LU cc % / § ! CZ k .) 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O n o — © a .'E B E L d C a W U x o K N v `� y u c u 9 Z ❑ 0 m o > v,' cc a F 01 o o o O> OZ U O. d o ''� ' A o 'u a m Ca U Lie 'u 'u O. ro F ,E X c •u C 0 m 0 W O m as ❑ „ Q ® W ae m W CI) ft V1 _ V] v) STATE OF COLORADO John W.Hickenlooper,Governor Larry Wolk,MD,MSPH • wo* cot, ,P Executive Director and Chief Medical Officer ,e- Dedicated to protecting and improving the health and environment of the people of Colorado .<; 4300 Cherry Creek Dr.S. Laboratory Services Division �. — Denver,Colorado 80246-1530 8100 Lowry Blvd. 1gj6 Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health ww.v.colorado.gov/cdphe and Environment Weld County-Clerk to the Board 1150 O St POBox758 RECEIVED Greeley, CO 80632 JUL 1 7 2014 July 9, 2014 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On July 15,2014, the Air Pollution Control Division will publish a public notice for Bonanza Creek Energy Operating Company LLC—State Antelope P-30, in the The Greeley Tribune. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty(30) days from the date the public notice is published. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health& Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, RECEIVED yt �a F f JUL 1 8 2014 Clara Gonzales Public Notice Coordinator WELD COUNTY Stationary Sources Program COMMISSIONERS Air Pollution Control Division Enclosure 7Wb uuw) PL(mm,me) H-L/p3) —7- 2.3- ►t-1 18 141 2014-2205 STATE OF COLORADO John W.Hickenlooper, Governor - Larry Wolk, MD,MSPHOF cot°de fr Executive Director and Chief Medical Officer / T/ °o A Dedicated to protecting and improving the health and environment of the people of Colorado • 4300 Cherry Creek Dr.S. Laboratory Services Division •/an Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.gov/cdphe and Environment Website Title: Bonanza Creek Energy Operating Company LLC —State Antelope P-30— Weld County Released To: The Greeley Tribune On: July 9,2014 Published: July 15, 2014 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Bonanza Creek Energy Operating Company LLC Facility: State Antelope P-30 Wellhead Facility NENE Section 30 T5N R62W Weld County The proposed project or activity is as follows: Bonanza Creek is operating a well pad in Weld County. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section 111!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 14WE0197 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at www.colorado.gov/cdphe/AirPublicNotices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Peter Armington Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South,APCD-SS-B 1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us 8 ``` STATE OF COLORADO v Ee� Zw':s :.a'�sk, +s ,„•y of Cot. COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT �``,* le AIR POLLUTION CONTROL DIVISION �� , TELEPHONE: (303)692-3150 ' ` rr. 1816 CONSTRUCTION PERMIT PERMIT NO: 14WE0197 Issuance 1 DATE ISSUED: ISSUED TO: Bonanza Creek Energy Operating Company LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas exploration and production facility known as the State Antelope P-30 Production Facility, located in the NENE Section 30 T5N R62W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Point Description Equipment ID PW Tanks 005 One (1) above ground 300 bbl produced water storage tank Truck Loadout 006 Truck Condensate Loadout FUG 007 Fugitive VOC leak emissions P-1 008 One (1)water transfer pump, rated at 600 scf/hr. Separator controlled by two enclosed flares. HLP Sep-1 009 Flares have a minimum combustion efficiency of 95%. The flares are enclosed. Point 008: This pump may be replaced with another pump in accordance with the provisions of the Alternate Operating Scenario (AOS) in this permit. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, b rtsubmittinq a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. AIRS ID: 123/9BDB Page 1 of 12 olor Depa en li ealth and Environment it Pollution Control Division 2. Within one hu d ' 80 ance is 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. Point 009: Within one-hundred and eighty (180) days after issuance of this permit, the operator shall install a flow meter to monitor and record volumetric flowrate of natural gas vented from the low pressure separator. The operator shall use the gas flow rate listed in the application for actual flow rate until the flow meter is installed, not to exceed one-hundred and eighty(180) days after issuance of this permit. 5. 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.) 6. The operator shall retain the permit final authorization letter issued by the Division, after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility Tons per Year Equipment ID AIRS Point NOx VOC CO Emission Type PW Tanks 005 --- 5.7 — Point Truck 006 --- 20.4 --- Point Loadout FUG 007 -- 5.2 -- Fugitive P-1 008 — 2.5 1.3 Point HLP Sep-1 009 --- <10.8 3.4 Point See "Notes to Permit Holder"for information on emission factors and methods used to calculate limits. AIRS ID: 123/9BDB Page 2 of 12 iii I ' olor .. Depa en • P.. •liit Health Pollution andControl EnvironDivisment ion Compliance '. _ .nn - I b- , .: _= ed b 1_ •rding the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 8. The 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 Point Control Device Pollutants Equipment ID Controlled P-1 008 Enclosed Combustor VOC & HAPs HLP Sep-1 009 Enclosed Combustor VOC & HAPs 9. Point 007: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas analysis, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. PROCESS LIMITATIONS AND RECORDS 10. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Point Process Parameter Annual Limit Equipment ID PW Tanks 005 Produced Water Throughput 43,800 BBL Truck Loadout 006 Condensate Loaded 131,400 BBL P-1 008 Natural Gas Throughput 5.3 MMSCF HLP Sep-1 009 Gas Vented from Separator 10.3 MMSCF The owner or operator shall calculate monthly process rates based on the calendar month. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each AIRS ID: 123/9BDB Page 3 of 12 Depa en li ealth and Environment it Pollution Control Division month and Dolor c rd • r at cal field office with site responsibility, for Division review. 11. Point 009: Upon installation of the flow meter required under Condition 4, the owner or operator shall continuously monitor and record the volumetric flowrate of natural gas vented from each low pressure separator using a flow meter. The flow meter shall continuously measure flowrate and record total volumetric flow vented from each separator. The owner or operator shall use monthly throughput records to demonstrate compliance with the limits specified in Condition 9 and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 12. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 13. Visible emissions shall not exceed twenty percent(20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. &4.) 14. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 15. Point 006: This source is located in an ozone non-attainment or attainment-maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 16. Point 006: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): r 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 ensure compliance with Condition 16 (a) and (b) above. The inspections shall occur at least monthly. 17. Point 006: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 18. Point 007: This source is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained so as to AIRS ID: 123/9BDB Page 4 of 12 Depa en . P .li `Health and Environment � olor ,t•it Pollution Control Division minimize lea ,= Iof , r, . :.. t,. . , o ;,, c o th , %sosphere to the maximum extent practicable. The operator shall comply with all applicable requirements of Section XII. 19. Point 007: Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). This requirement to apply RACT shall be satisfied by installing/implementing the following emission controls: a. Directed Inspection & Maintenance as described below shall satisfy the requirement to apply RACT. i. Auditory/visual/olfactory inspection (AVO) will be performed on a semi-annual basis. The first AVO inspection must be completed within 180 days of permit issuance. ii. For each leak found in the AVO inspection, a gas detector may be used to determine the size of the leak. The gas detector shall be regularly calibrated. Component leaks greater than 10,000 ppm shall be managed in accordance with Item (vi) below, unless it is unfeasible to make the repair without shutting down the affected operation of the facility. Component leaks less than 10,000 ppm shall not require repair. For such component leaks that require a shutdown to be repaired, repair shall occur during the first shutdown of the affected operation after the leak is discovered. iii. For repair, valves adjacent to the equipment to be repaired will be closed if practicable, minimizing the volume released. iv. Repaired components shall be re-screened using AVO to determine if the leak is repaired. v. The following records shall be maintained for a period of two years: • The name of the site screened via AVO inspection and the name of the inspector. • Components evaluated with the gas detector. • Repair methods applied. • Dates of the AVO inspections, gas detector calibrations, attempted repairs, successful repairs, repair delays, and post- repair screenings. vi. Leaks shall be repaired as soon as practicable, but no later than 15 calendar days after detection, unless it is technically or operationally infeasible to make the repair within 15 calendar days. Records documenting the rationale shall be maintained if it is technically or operationally infeasible to make the repair within 15 calendar days. OPERATING & MAINTENANCE REQUIREMENTS 20. 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 AIRS ID: 123/9BDB Page 5 of 12 olor Depa en li Health and Environment it Pollution Control Division Division, in or m t Ha ongo. sis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 21. Point 007: Within one hundred and eighty days (180) after issuance of this permit, the owner or operator shall complete the initial extended gas analysis of gas samples that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the gas analysis and emission calculations to the Division as part of the self-certification process to ensure compliance with emissions limits. 22. Point 007: Within one hundred and eighty days (180) after issuance of this permit, the operator shall complete a hard count of components at the source and establish the j number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. Periodic Testing Requirements 23. Point 007: On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. ALTERNATE OPERATING SCENARIOS 24. Point 008: This pump may be replaced with a like-kind pump in accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a revision to this permit or obtaining a new construction permit. A like-kind replacement pump shall be the same make, model and capacity as authorized in this permit. 25. Point 008: The owner or operator shall maintain a log on-site or at a local field office to contemporaneously record the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of the replacement pump. 26. Point 008: All pump replacements installed and operated per the alternate operating scenarios authorized by this permit must comply with all terms and conditions of this construction permit. ADDITIONAL REQUIREMENTS 27. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30`h whenever a significant increase in emissions occurs as follows: AIRS ID: 123/9BDB Page 6 of 12 olor Depa en' . P •Ii Health and Environment •it Pollution Control Division For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO),) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 28. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS 29. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 30. 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. AIRS ID: 123/9BDB Page 7 of 12 olor Depa en li Health and Environment it Pollution Control Division 31. This permit i in t y an pleteness 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. 32. 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. 33. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 34. 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. 35. 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: Peter Armington Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bonanza Creek Energy Operating Company LLC AIRS ID: 123/9BDB Page 8 of 12 olor Depa ' nen'o P :-.Ii Health and Environment it Pollution Control Division Notes to Permit Holder - irne o e a 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: http://www.colorado.gov/cs/Satellite?c=Document C&childpariename=CDPHE- Main%2FDOcument C%2FCBONAddLinkView&cid=1251599389641&pagename=CBONWrapper 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS# Uncontrolled Reportable? Controlled Emissions (Ib/yr) Emissions (lb/yr) 005 Benzene 71432 306.6 Yes 306.6 n-Hexane 110543 963.6 Yes 963.6 Benzene 71432 497.3 Yes 497.3 006 n-Hexane 110543 3057.3 Yes 3057.3 Toluene 108883 1141.4 Yes 1141.4 Ethylbenzene 100414 203.8 No 203.8 Xylenes 1330207 2935 Yes 2935 Benzene 71432 51.1 No 51.1 007 n-Hexane 110543 275.5 Yes 275.5 Toluene i, 108883 97.2 No 97.2 Ethylbenzene 100414 17.7 No 17.7 Xylenes 1330207 62.1 No 62.1 008 Benzene 71432 186.3 _ No 9.3 n-Hexane 110543 1111.5 Yes 55.6 Benzene 71432 919.3 Yes 46 009 n-Hexane 110543 5464.1 Yes 273.2 Toluene 108883 653.6 Yes 32.7 5) The emission levels contained in this permit are based on the following emission factors: Point 005: Emission Factors CAS # Pollutant Uncontrolled Source Ib/BBL Produced Water Throughput VOC 0.262 CDPHE 110543 n-Hexane i 0.022 CDPHE AIRS ID: 123/9BDB Page 9 of 12 olor Depa en li Health and Environment it Pollution Control Division CAS# Pollutant Uncontrolled Source lb/BBL Produced Water Throughput 71432 Benzene 0.007 CDPHE Point 006: Emission Factors-Uncontrolled CAS Pollutant lb/BBL loaded Source VOC 0.31 AP-42 71432 Benzene 0.0038 AP-42 110543 n-Hexane 0.023 AP-42 108883 Toluene 0.0087 AP-42 100414 Ethylbenzene 0.0016 AP-42 1330207 Xylenes 0.022 AP-42 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) = 7.83 psia M (vapor molecular weight) = 66.12 Ib/Ib-mol T(temperature of liquid loaded) = 524 °R Point 007: Component Gas Service Light Oil Water/Oil Service Connectors 459 268 267 Flanges 13 8 10 Open-ended Lines 15 3 1 Pump Seals 0 0 1 Valves 58 33 29 Other* 33 3 10 VOC Content(wt. 0.2963 0.9963 1.000 fraction) Benzene Content(wt. 0.0006 0.0122 0.0012 fraction) Toluene Content(wt. 0.0004 0.0283 0.0003 fraction) Ethylbenzene(wt. 0.0001 0.0050 0.0001 fraction) Xylenes Content(wt. 0.0002 0.0184 0.0001 fraction) n-hexane Content(wt. 0.0033 0.0722 0.0001 fraction) *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors(kg/hr-component): Component Gas Service Heavy Oil Light Oil Water/Oil AIRS ID: 123/9BDB Page 10 of 12 olor 1Depa a, en S P .li Health and Environment , 'it Pollution Control Division• „ Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas analysis. Point 008: Emission Factors Emission Factors - Uncontrolled -Controlled CAS# Pollutant lb/MMscf vented lb/MMscf vented Source VOC 18,724 936 All emission factors are 108883 Toluene 26.5 1.3 based on the displacement 1330207 Xylenes 9.5 0.48 equation and the State 110543 n-Hexane 211.5 10.6 Antelope 41-44-30HNB wet 71432 Benzene 35.5 1.8 gas analysis. Point 009: Weight Emission Emission CAS # Pollutant Fraction of Factors Factors Source Gas (°/.) Uncontrolled Controlled NOx 0.068 0.068 AP-42 lb/MMBtu• Ib/MMBtu • CO 0.37 AP-42 0.37 1b/MMBtu Ib/MMBtu VOC 51 42096 2105 Engineering lb/mmscf lb/mmscf Calculation 71432 Benzene 0.11 89.25 4.5 lb/mmscf Engineering lb/mmscf Calculation 108883 Toluene 0.08 63.5 lb/mmscf 3.2 lb/mmscf Engineering Calculation 100414 Ethylbenzene 0.01 7.3 lb/mmscf 0.36 Engineering lb/mmscf Calculation 1330207 Xylenes 0.02 16.2 lb/mmscf 0.81 Engineering lb/mmscf Calculation 110543 n-hexane 0.64 530.5 26.5 Engineering lb/mmscf lb/mmscf Calculation 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 AIRS ID: 123/9BDB Page 11 of 12 olor Depa en li Health and Environment it Pollution Control Division most recent annual - e t A tion d each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC NANSR Synthetic Minor Source of:VOC 8) 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 7777-Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXX)O( 9) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: www.colorado.qov/cdphe/oilqaspermits AIRS ID: 123/9BDB Page 12 of 12 Division Information Engineer: Peter Armington Control Engineer: Stefanie Rucker Review Date: 03/17/2014 Application Date: 10/30/2013 Facility Identifiers Permit No. 14WE0197 AIRs County# 123 Weld Facility# 9BDB Facility Type: exploration and production facility Located in the 8-hour non-attainment area? 0 True Minor 0 Synthetic Minor for: W VOC r NOx r CO Section 01: Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: State Antelope P-30 Production Facility Source Location: NENE Section 30 T5N R62W SIC: 1311 Address 1: Bonanza Creek Energy Operating Company LLC Mailing Address 2: 410 17th St., Suite 1500 Address ty, State Zip: Denver, CO 80202 Name: Peg Young Person To Phone: 720-440-6133 Contact Fax: 720-279-2331 Email: pvoung@bonanzacrk.com (Section 02: Requested Action Self Certification Required? Yes Issuance Number: 1 Source Description: Oil and gas exploration and production facility known as the State Antelope P-30 Production Facility, located in the NENE Section 30 T5N R62W, Weld County, Colorado. Point Name Type Control 005 PW Tanks Water Tanks None 006 Truck Loadout None Loadout 007 FUG Fugitives None 008 P-1 Pump Flare 009 HLP Sep-1 Separator Venting Flare 005 One (1) above ground 300 bbl produced water storage tank Emissions Calculations Pollutant E.F. Source VOC 0.262 lb/bbl CDPHE Benzene 0.007 Ib/bbl CDPHE n-Hexane 0.022 lb/bbl CDPHE Requsted Throughput 43800 bbl Control 0 No Control 0 Flare Pollutant Uncontrolled Emissions Controlled Emissions VOC 5.7378 tpy 5.7378 tpy Benzene 306.6 lb/yr 306.6 lb/yr n-Hexane 963.6 lb/yr 963.6 lb/yr Regulatory Review Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR, Part 60, Appendix A(July, 1992)) in all subsections of Section II.A and B of this regulation. R ulation 2 Odor Section I.A- No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are 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. 006 Truck Condensate Loadout Calculations 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] 1 degree Fahrenheit=460.67 degree Rankine • Source S 0.6 Submerged loading: ded AP-42 P 7.83 psia Sales Oil Analysis M 66.12 lb/lb-mole AP-42 T 524 deg. R Field Data L 7.39 lb/10^3 gal 3.10E-01 lb/bbl Annual requested Throughput 131400 BBL/yr 5518800 gal/yr Annual requested VOC emissions 40764 lb/yr 20.38 tpy Regulatory Considerations 1 his facility is not condisdered a terminal (in Reg. 7) because average daily throughput will be below 20,000 gallons at 3,956 gallons per day. This facility is not considered a bulk plant(in Reg. 7) because it does not distribute gasoline. NCRPs Component Mass Frac. lb/yr Emission Factor Benzene 0.0122 497.32 0.00378479 lb/bbl n-hexane 0.075 3057.30 0.023267149 lb/bbl Toluene 0.028 1141.39 0.008686402Ib/bbl Ethylbenzene 0.005 203.82 0.001551143 lb/bbl Xylenes 0.072 2935.01 0.022336463 lb/bbl • a n O I O O 'I N m o - 0 P. N N O O O O O O O O O O O ' p OO N vi OO 'i .Ni O m m .r O O OO Y O .. N H U co a S a E i. b O N m m T a q a.. N N O o O O O O m .. 0 0 2 a a' N O b o w vi o 'i . 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Section 04: Pump Information Manufactur Sandpiper Model Number: G1F Serial Pump Number: 2091586 Information Pump capacity 9.1 gallons per minute pumped natural gas 600 scf/hour used consumptio Control 0 Uncontrolled 0 Flare Section 05: Emission Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10- Displacement Equation (10.4- 3) Ex=Q* MW * Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas * MW of air Xx= mass fraction of x in gas C=molar volume of ideal gas (379 scf/Ib-mol)at 60F and 1 atm Q soo scf/hrr MW 23.9 Ib/Ib-mol Hours of Op. 8760 hours/yr Requested Throughput 5.256 MMscf/yr Component mole% MW mass fraction Component lb/hr lb/yr tpy CO2 2.33 44 0.0429 CO2 1.623 14217.549 7.109 nitrogen 0.49 28 0.0057 nitrogen 0.217 1902.700 0.951 methane 66.38147 16.04 0.4455 methane 16.856 147661.534 73.831 ethane 16.717 30.07 0.2103 ethane 7.958 69712.060 34.856 propane 9.5812 44.09 0.1768 propane 6.688 58583.613 29.292 isobutane 0.8351 58.12 0.0203 isobutane 0.768 6731.010 3.366 n-butane 2.3285 - 58.12 0.0566 n-butane 2.142 18768.000 9.384 isopentane 0.3718 72.15 0.0112 isopentane 0.425 3720.162 1.860 n-pentane 0.4633 72.15 0.0140 n-pentane 0.529 4635.694 2.318 cyclopentane 0.033 72.15 0.0010 n-pentane 0.038 330.192 0.165 n-hexane 0.093 86.18 0.0034 n-hexane 0.127 1111.490 0.556 cyclohexane 0.024 84.18 0.0008 cyclohexane 0.032 280.179 0.140 Other hexanes 0.1551 86.18 0.0056 Other hexane≤ 0.212 1853.679 0.927 heptanes 0.0735 100.21 0.0031 heptanes 0.117 1021.444 0.511 methylcyclohexa 0.0182 98.19 0.0007 methylcyclohe 0.028 247.831 0.124 224-TMP 0.0001 114.22 0.0000 224-IMP 0.000 1.584 0.001 Benzene 0.0172 78.11 0.0006 Benzene _ 0.021 186.316 0.093 Toluene 0.0109 92.14 0.0004 Toluene 0.016 139.281 0.070 Ethylbenzene 0.0011 106.17 0.0000 Ethylbenzene 0.002 16.196 0.008 Xylenes 0.0034 106.17 0.0002 Xylenes 0.006 50.061 0.025 C8+ Heavies 0.0416 128 0.0022 C8+ Heavies 0.084 738.447 0.369 Mass Fraction VOC: 0.2969 Total 49.208 Heating Value I 1384 BTU/scf Combustion emission factor source: AP-42:Chapter 13.5 0.07 I lb NOX/MMBtu 0.37 I lb CO/MMBtu I Notes Mole%, MW,and mass fractions from extended gas analysis from State Antelope 41-44-30HNB facility dated 9/20/2013. Emissions Summary . U 0.2 tpy NOX ncontrolle d/PTE 1.3 tpy CO 49.2 tpy VOC Controlled 2.5 tpy VOC Scenario A Controlled CAS* Total (Ib/yr) Bin Reportable Total n-hexane 110543 1111.5 C Yes 56 224-TMP 540841 1.6 C No 0 Benzene 71432 186.3 A Yes 9 Toluene 108883 139.3 C No 7 E-Benzene 100414 16.2 C No 1 Xylenes 1330207 50.1 C No 3 Resultant Emission Factors VOC 18724.349 lb/MMscf natural gas used Benzene 35.448 lb/MMscf natural gas used n-hexane 211.471 lb/MMscf natural gas used Toluene 26.499 lb/MMscf natural gas used E-Benzene 3.081 lb/MMscf natural gas used Xylenes 9.524 lb/MMscf natural gas used 224-TMP 0.301 lb/MMscf natural gas used t 009 Separator controlled by two enclosed flares.Flares have a minimum combustion efficiency of 95%. The flares are enclosed. Equipment Description This source vents natural gas from: a low pressure separator Emissions from this source are: routed to a flare Natural gas venting from a low pressure separator.Emissions from this source are routed to a flare. Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q'MW'Xx IC Ex=emissions of pollutant x 0=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas'MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm Throughput(0) 10 MMsci/yr 1175.8 scf/hr 0.87 MMscf/mo MW 31.300 Ib/Ib-mol 0.028 MMscf/d mole% MW Ibx/Ibmol mass fraction E lb/hr lb/yr tpy Helium 0 4.0026 0.000 0.000 Helium 0.0 0 0.00 CO2 2.51 44.01 1.105 0.035 CO2 3.4 30021 15.01 N2 0.1 28.013 0.028 0.001 N2 0.1 761 0.38 methane 40.3128 16.041 6.467 0.207 methane 20.1 175741 87.87 ethane 25.8919 30.063 7.784 0.249 ethane 24.1 211541 105.77 propane 20.2694 44.092 8.9372 0.286 propane 27.7 242884 121.44 isobutane 1.9684 58.118 1.1440 0.037 isobutane 3.5 31090 15.55 n-butane 5.6659 58.118 3.2929 0.105 n-butane 10.2 89491 44.75 isopentane 0.9357 72.114 0.6748 0.022 isopentane 2.1 18338 9.17 n-pentane 1.1731 72.114 0.8460 0.027 n-pentane 2.6 22991 ' 11.50 cyclopentane 0.0828 70.13 0.0581 0.002 cyclopentane 0.2 1578 0.79 n-Hexane 0.2333 86.18 0.2011 0.006 n-Hexane 0.6 5464 2.73 cyclohexane 0.0607 84.16 0.0511 0.002 cyclohexane 0.2 1388 0.69 Other hexanes 0.391 86.18 0.3370 0.011 Other hexanes 1.0 9158 4.58 heptanes 0.1821 100.21 0.1825 0.006 heptanes 0.6 4959 2.48 methylcyclohexane 0.0462 98.19 0.0454 0.001 methylcyclohexane 0.1 1233 0.62 224-IMP 0.0001 114.23 0.0001 0.000 224-IMP 0.0 3 0.00 Benzene 0.4433 78.12 0.0338 0.001 Benzene 0.1 919 0.46 Toluene 0.0261 92.15 0.0241 0.001 Toluene 0.1 654 0.33 Ethylbenzene 0.0026 106.17 0.0028 0.000 Ethylbenzene 0.0 75 0.04 Xylenes 0.0058 106.17 0.0062 0000 Xylenes 0.0 167 0.08 C8+Heavies 0.098 120.000 0.1176 0.004 C8+Heavies 0.4 3196 1.60 VOC mass fraction: 0.5097 Total VOC Emissions(Uncontrolled) 216.8 31.337 . Notes Mole%,MW,and mass fractions from a State Antelope 41-44-30HNB L.P.separator gas anaysis. Emissions are based on 8760 hours of operation per year. I calculated the average MW of C8+based on the average MW on the analysis for the gas. Flaring Information Equipment Description Flare to combust produced gas until pipeline is available at this wellhead facility. Manufacturer Leed Model L30-0010 Serial Number 21142,21143 Gas Heating Value 1796 Btu/scf Throughput 18498.8 MMBtu/yr VRU Information Equipment Description Engine to recompress gas to sales line. Make Model Requested Control Efficiency Annual Bypass Time Backup Overall Control 95.00% Combustion emission factor source: AP-42: Chapter 13.5 0.07 lb NOX/MMBtu 0.37 lb CO/MMBtu 0.63 tpy NOX 3.42 tpy CO Emissions Summary 0.6 tpy NOX Uncontrolled/PTE 3.4 tpy CO 216.8 tpy VOC Controlled 10.8 tpy VOC Uncontrolled Scenario A Controlled Total Total (Ib/yr) Bin Reportable? (Iblyr) Benzene 919 A Yes 46 Toluene 654 C No 33 Ethylbenzene 75 C No 4 Xylenes 167 C No 8 n-hexane 5464 C Yes 273 224-TMP 3 C No 0 Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a AQCC Regulation 2 Section I.A applies to all emission sources. "No person, wherever located, shall cause or allow the emission AQCC Regulation 3 Is public comment Public Comment Required required? Emission Factors for Permit Uncontrolled NOX 122.128 lb/MMscf !r(1 CCA Cpl 1..PR AR 1h....S C v .. 9 _ a e aE o" = z l o cE v = E. 4' N - =1 R a e C Iiz-. OVG V ` f�i r•i 7'i e0i 4 ❑ G V O O. C v (at : O. O, `. Z, F- • r m U g sI. _ � N : T302pl3 c c ° o u M ..rr'. a c 0400 — % $ ° ° u a r4 3.'"' v O .9 C °� t„ ON`az a �! rL ru e. CQ 0 .o a _N -' ° .. a 1 in o e... ..;,.l.. > c CC D ` i� 0 7 A E .C S N g u 00 'D < H cc 2 •, i.7 (r u • ❑ .Y r" = .� te. a YE r c 7 s %... 0 a o. u o Ewa. : ` G ` rA °O C 3 w ♦. 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