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Home My WebLink About20142251.tiff STATE OF COLORADO John W.Hickenlooper,Governor Larry Wolk,MD,MSPH WOF COC6 bc.Executive Director and Chief Medical Officer 61 ?off Dedicated to protecting and improving the health and environment of the people of Colorado a „,- i 4300 Cherry Creek Dr.S. Laboratory Services Division g Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.govlcdphe and Environment Weld County- Clerk to the Board 1150 O St PO Box 758 Greeley, CO 80632 RECEIVED July 17, 2014 JUL 2 3 2014 • WELD COUNTY COMMISSIONERS Dear Sir or Madam: On July 23,2014,the Air Pollution Control Division will publish a public notice for Bonanza Creek Energy Operating Company LLC—State Antelope T-28 Production Facility, 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, v; ;} r cari Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 410-UL 4 ., et cam,-rp)wLPP) TP) 2014-2251 1'30 - 2-5 -(, STATE OF COLORADO John W.Hickenlooper,Governor •Larry Wolk, MD,MSPH oF cozoq Executive Director and Chief Medical Officer ire ::90 < o Dedicated to protecting and improving the health and environment of the people of Colorado I,, t`* 4300 Cherry Creek Dr.S. Laboratory Services Division *x a s;* Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)6922000 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 T-28—Weld County Released To: The Greeley Tribune On: July 17, 2014 Published: July 23, 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 T-28 Oil and gas production facility SESE Section 28, T5N, R62W Weld County The proposed project or activity is as follows: The applicant proposes to operate two new oil and gas production facilities. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.l.a (25 tpy in a non-attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application,the Division's analysis,and a draft of Construction Permit 14WE0040 have been filed with the Weld County Clerk's office. A copy of the draft permits 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: 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 STATE OF COLORADO ,E'cot° PAD D RTM T F P BLIC HEALTH AND ENVIRONMENT �`` AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 CONSTRUCTION PERMIT PERMIT NO: 14WE0040 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 T-28, located in the SESE Section 28, 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 Six (6) 500 bbl above ground atmospheric condensate storage Condensate 003 tanks. The condensate storage tanks are controlled by six Tanks enclosed flares. Each flare has a minimum combustion efficiency of 95%. Two (2)400 bbl above ground atmospheric produced water storage tanks and two (2) 60 bbl concrete vaults for produced PW Tanks 004 water. The 400 bbl produced water storage tanks are controlled by six enclosed flares. Each flare has a minimum combustion efficiency of 95%. Truck 005 Truck Condensate Loadout Loadout FUG 006 Fugitive VOC equipment leaks One (1) pneumatic water transfer pump, rated at 1,320 scf/hr P-1 007 (Sandpiper, Model G20, Serial number 2091585). The pneumatic pump is controlled by six enclosed flares. Each flare has a minimum combustion efficiency of 95%. One emergency flare with a minimum combustion efficiency of FL-1 008 95%. The flare is not enclosed. The emergency flare is used during periods when the pipeline is not available. One low-pressure separator controlled by a VRU and six enclosed HLP Sep-1 009 flares. Each flare has a minimum combustion efficiency of 95%. HLP Sep-2 010 One low-pressure separator controlled by a VRU and six enclosed flares. Each flare has a minimum combustion efficiency of 95%. AIRS ID: 123/9BB0 Page 1 of 21 olor epa en P Ii ealth and Environment it Pollution Control Division Point 007: 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. AIRS Point 008: 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 008: 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 008: 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 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). 4. AIRS Points 003 - 007, 009 and 010: YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, f 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 003 - 007, 009 and 010: 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 AIRS ID: 123/9BB0 Page 2 of 21 olor Depa en .. P .li ealth and Environment it Pollution Control Division • of eighteen ,, .at- (i n to c., action 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 and 010: 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 each 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. 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 Equipment ID Point NOx VOC CO Emission Type Condensate 003 --- 6.7 1.4 Point Tanks PW Tanks 004 1.0 Point Truck Loadout 005 30.1 Point FUG 006 12.6 Fugitive P-1 007 -- 5.1 2.9 Point FL-1 008 --- 6.3 3.5 Point HLP Sep-1 009 --- 6.9 2.0 Point HLP Sep-2 010 --- 6.9 2.0 Point See "Notes to Permit Holder"for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record AIRS ID: 123/9BB0 Page 3 of 21 9 epa en P li ealth and Environment it Pollution Control Division on site or atDolor de r lily, f ision review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 11. AIRS Point 006: 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 003 Enclosed Flare VOC Tanks PW Tanks 004 Enclosed Flare VOC P-1 007 Enclosed Flare VOC FL-1 008 Open Flare VOC HLP Sep-1 009 VRU and Enclosed Flare VOC HLP Sep-2 010 VRU and 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/Constnnption Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point Condensate 003 Condensate Throughput 214,620 BBL Tanks PW Tanks 004 Produced Water Throughput 148,920 BBL Truck 005 Condensate Loaded 214,620 BBL Loadout P-1 007 Natural Gas Consumed 11.6 MMSCF FL-1 008 Gas Vented from Separator 14.2 MMSCF HLP Sep-1 009 Gas Vented from Low Pressure Separator 11.2 MMSCF HLP Sep-2 010 Gas Vented from Low Pressure Separator 11.2 MMSCF 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: 123/98B0 Page 4 of 21 olo4 Depa en Y P .li ' ealth and Environment it Pollution Control Division tv month and k a = - o ,.�- .r at .cal field office with site responsibility, for Division review. 14. AIRS Points 009 and 010: Upon installation of the flow meter required under Condition 7, 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 13 and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 15. AIRS Points 003 - 005, and 007 - 010: 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.1.c 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. 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.) 19. AIRS Point 003: 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. 20. AIRS Point 003: 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. 21. AIRS Point 003: The condensate storage tanks covered by this permit are subject to Regulation 7, Section XVII.C emission control requirements. These requirements include, but are not limited to: XVII.C.1.a. Beginning May 1, 2008, owners or operators of all atmospheric condensate storage tanks with uncontrolled actual emissions of volatile organic compounds equal to or greater than 20 tons per year based on a rolling twelve-month total shall operate air pollution control equipment that has an average control efficiency of at least 95% for VOCs on such tanks. AIRS ID: 123/9BB0 Page 5 of 21 epa en ealth and Environment T llution Control Division 22. AIRS PointsDolor 0 e v 's pbject 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, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XVII. XVIl.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. 23. AIRS Points 003 and 004: 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 XV[I.C.1. must conduct audio, visual, olfactory("AVO")and additional visual inspections of the storage tank and any associated equipment (e.g. separator, air pollution control equipment, or other pressure reducing equipment) at the same frequency as liquids are loaded out from the storage tank. These inspections are not required more frequently than every seven (7) days but must be conducted at least every thirty one (31) days. Monitoring is not required for storage tanks or associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section XVII.C.1.e. The additional visual inspections must include, at a minimum: XVII.C.1.d.(i) Visual inspection of any thief hatch, pressure relief valve, or other access point to ensure that they are closed and properly sealed; XVII.C.1.d.(ii) Visual inspection or monitoring of the air pollution control equipment to ensure that it is operating, including that the pilot light is lit on combustion devices used as air pollution control equipment; XVII.C.1.d.(iii) If a combustion device is used, visual inspection of the auto-igniter and valves for piping of gas to the pilot light to ensure they are functioning properly; AIRS ID: 123/9BB0 Page 6 of 21 • olor Depa en P4.Ii ealth and Environment it Pollution Control Division vffi XVII.C. is • s of olluti.:a .=, trol equipment to ensure that the valves for the piping from the storage tank to the air pollution control equipment are open; and XVII.C.1.d.(v) If a combustion device is used, inspection of the device for the presence or absence of smoke. If smoke is observed, either the equipment must be immediately shut-in to investigate the potential cause for smoke and perform repairs, as necessary, or EPA Method 22 must be conducted to determine whether visible emissions are present for a period of at least one (1) minute in fifteen (15) minutes. XVII.C.1.e. If storage tanks or associated equipment is unsafe, difficult, or inaccessible to monitor, the owner or operator is not required to monitor such equipment until it becomes feasible to do so. XVII.C.2. Capture and monitoring requirements for storage tanks that are fitted with air pollution control equipment as required by Sections XII.D. or XVII.C.1. XVII.C.2.a. Owners or operators of storage tanks must route all hydrocarbon emissions to air pollution control equipment, and must operate without venting hydrocarbon emissions from the thief hatch (or other access point to the tank) or pressure relief device during normal operation, unless venting is reasonably required for maintenance, gauging, or safety of personnel and equipment. Compliance must be achieved in accordance with the schedule in Section XVII.C.2.b.(ii). XVII.C.2.b. Owners or operators of storage tanks subject to the control requirements of Sections XII.D.2., XVII.C.1.a, or XVII.C.1.b. must develop, certify, and implement a documented Storage Tank Emission Management System ("STEM") plan to identify, evaluate, and employ appropriate control technologies, monitoring practices, operational practices, and/or other strategies designed to meet the requirements set forth in Section XVII.C.2.a. Owners or operators must update the STEM plan as necessary to achieve or maintain compliance. Owners or operators are not required to develop and implement STEM for storage tanks containing only stabilized liquids. The minimum elements of STEM are listed below. XVII.C.2.b.(i) STEM must include selected control technologies, monitoring practices, operational practices, and/or other strategies; procedures for evaluating ongoing storage tank emission capture performance; and monitoring in accordance with approved instrument monitoring methods following the applicable schedule in Section XVII.C.2.b.(ii) and Inspection Frequency in Table 1. XVII.C.2.b.(ii) Owners or operators must achieve the requirements of Sections XVII.C.2.a. and XVII.C.2.b. and begin implementing the required approved instrument monitoring method in accordance with the following schedule: XVII.C.2.b.(ii)(b) A storage tank constructed before May 1, 2014, must comply with the requirements of Sections XVII.C.2.a. and XVII.C.2.b. by May 1, 2015. Approved instrument monitoring method inspections must begin within ninety (90) days of the Phase-In Schedule in Table 1, or within AIRS ID: 123/9BB0 Page 7 of 21 olor epa en P li ealth and Environment I) it Pollution Control Division f e un led actual VOC emissions greater than 50 tons per year. XVII.C.2.b.(ii)(d) Following the first approved instrument monitoring method inspection, owners or operators must continue conducting approved instrument monitoring method inspections in accordance with the Inspection Frequency in Table 1. Table 1 —Storage Tank Inspections Threshold: Storage Tank Approved Instrument Phase-In Uncontrolled Actual VOC Monitoring Method Inspection Schedule Emissions(tpy) Frequency > 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. AIRS ID: 123/9BB0 Page 8 of 21 olor Depa ent ' Psli "' ealth and Environment it Pollution Control Division XVII.C.3.f. A : i _, .ui t to star-a= ank 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. 24. AIRS Point 005: 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) 25. AIRS Point 005: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations on site at the time of the inspection to ensure compliance with Condition 25 (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. 26. AIRS Point 005: 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. 27. 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. 28. AIRS Point 006: 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. AIRS ID: 12319BB0 Page 9 of 21 epa en li ealth and Environment it Pollution Control Division XVIIF.4.c. ThDolor o a emis ' 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 XV I I.F.4.c)—Well Production Facilities Approved Instrument AVO with Storage Tanks Monitoring method Inspection Phase-In (tpy) Inspection Frequency Frequency Schedule > 0 and < 6 One time Monthly 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 XVII.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. XVII.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. AIRS ID: 12319BB0 Page 10 of 21 olor Depa en P li ealth and Environment it Pollution Control Division XVII.F.7. Rep ' e 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. XVII.F.7.c. Leaks discovered pursuant to the leak detection methods 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. 29. AIRS Point 006: 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. AIRS ID: 123/9BB0 Page 11 of 21 epa en ealth and Environment T llution Control Division Dolor o ' n l 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 30. AIRS Points 003, 004, 006— 010: 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 I I I.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 31. AIRS Point 006:Within one hundred and eighty (180)days 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 AIRS ID: 123/90B0 Page 12 of 21 olor Depa en P li ealth and Environment it Pollution Control Division Division as p ens mpliance with emissions limits. 32. AIRS Point 008: 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. (Reference: Regulation No. 1, Section I I.A.1 &4) 33. AIRS Points 009 and 010: The operator shall complete an initial site-specific extended gas analysis of the natural gas vented from each low pressure separator 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 34. AIRS Point 006: 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 35. AIRS Point 007: 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. 36. AIRS Point 007: 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. 37. AIRS Point 007: 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 38. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5)tons per year or more. above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO.) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or AIRS ID: 123/9BB0 Page 13 of 21 epa en li ealth and Environment it Pollution Control Division For soDolor ' pe mo ange 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. 39. 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 40. 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. 41. 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. 42. 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. 43. 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. AIRS ID: 123/9BB0 Page 14 of 21 ,g.Y. ✓"y3 gc olor.' -Depa en 1 P li Health and Environment rs+ ur1 „ it Pollution Control Division 44. Each and evaa, tacos` to i.vr -e.: ial pagabareof 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 in/tio. 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. 45. 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. 46. 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 Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bonanza Creek Energy Operating Company LLC AIRS ID: 123/9BB0 Page 15 of 21 olor Depa en li ealth and Environment it Pollution Control Division Notes to Permit Holder - me o e a . 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The 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.00v/cs/Satellite?c=Document C&childoaaename=CDPHE- Main%2FDocument C%2FCBONAddLinkView&cid=1251599389641&pagename=CBONWraDoer 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? (1b/yr) Benzene 71432 2,038 Yes 102 n-Hexane 110543 11,676 Yes 584 Toluene 108883 1,248 Yes 62 003 Ethylbenzene 100414 77 No 4 Xylenes 1330207 242 No 12 2,2,4- 540841 504 Yes 25 trimethylpentane Benzene 71432 1,042 Yes 52 004 n-Hexane 110543 3,276 Yes 164 Benzene 71432 754 Yes 754 n-Hexane 110543 3,871 Yes 3,871 Toluene 108883 1,693 Yes 1,693 005 Ethylbenzene 100414 328 Yes 328 ' Xylenes 1330207 1,181 Yes 1,181 2,2,4- 540841 497 Yes 497 trimethylpentane Benzene 71432 129 No 129 006 n-Hexane 110543 641 Yes 641 AIRS ID: 123/9B80 Page 16 of 21 olor. Depa en . P s.li ar ealth and Environment fir Pollution Control Division 239 Ethylbenzene 100414 45 No 45 Xylenes 1330207 160 No 160 Benzene 71432 434 Yes 22 n-Hexane 110543 2,574 Yes 129 007 Toluene 108883 312 Yes 16 Ethylbenzene 100414 36 No 2 Xylenes 1330207 104 No 5 Benzene 71432 535 Yes 27 n-Hexane I 110543 3,172 I Yes 159 008 Toluene '�i 108883 385 I Yes 19 Ethylbenzene 100414 44 No I 2 Xylenes 1330207 128 No 6 Benzene 71432 1,177 Yes 29 n-Hexane 110543 7,057 Yes 176 009 Toluene 108883 782 Yes 20 Ethylbenzene 100414 94 No 2 Xylenes 1330207 179 No 5 Benzene 71432 1,177 Yes 29 n-Hexane 110543 7,057 Yes 176 010 Toluene 108883 782 Yes j 20 Ethylbenzene I 100414 94 No I 2 Xylenes I 1330207 179 No 5 5) The emission levels contained in this permit are based on the following emission factors: Point 003: Emission Factors Emission Factors Uncontrolled Controlled Pollutant Ib/BBL lb/BBL Source Condensate Condensate Throughput Throughput 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 1.2449 0.0622 E&P TANK n-Hexane 0.0544 0.0027 E&P TANK Benzene 0.0095 0.0005 E&P TANK Toluene 0.0058 0.0003 E&P TANK Ethylbenzene 0.0004 _ 0.00002 E&P TANK _ Xylenes 0.0011 0.00006 E&P TANK AIRS ID: 123/9BB0 Page 17 of 21 olor Depa en P li ealth and Environment it Pollution Control Division . . si mi Ors Uncontrolled Controlled Pollutant lb/BBL lb/BBL Source Condensate Condensate Throughput Throughput 2,Z4- 0.0023 0.0001 E&P TANK trimethylpentane Note: The controlled emissions for this point are based on the flare control efficiency of 95%. A HHV of 2,294 BTU/scf was used for combustion calculations. Point 004: Emission Factors Emission Factors Pollutant Uncontrolled Controlled Source Ib/BBL Produced lb/BBL Produced Water Throughput Water Throughput 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 005: Emission Factors- Uncontrolled Pollutant lb/BBL loaded Source VOC 0.2807 AP-42 Benzene 0.0035 AP-42 n-Hexane 0.0180 AP-42 • Toluene 0.0079 AP-42 Ethylbenzene 0.0015 AP-42 Xylenes 0.0055 AP-42 2,2,4- 0.0023 AP-42 trimethylpentane 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)=6.98 psia M (vapor molecular weight)=67.06 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 006: Component Gas Heavy Oil Light Oil Water/Oil Connectors 1270 0 606 534 Flanges 58 0 16 20 AIRS ID: 123/9BB0 Page 18 of 21 olor Depa en 3 P ).li ' ealth and Environment it Pollution Control Division Open-ended Line s- t. 2 Pump Seals 4 I 0 0 1 Valves 167 i 0 78 58 Other 94 0 10 20 VOC Content(wt. 0.2855 1 0.9968 1 fraction) Benzene Content(wt. 0.0006 0 0.0125 0.0012 fraction) Toluene Content(wt. 0.0004 0 0.0281 0.0003 fraction) I __ __ Ethylbenzene(wt. i 0.00005 0 0.0054 0.0001 fraction) Xylenes Content(wt. 0.0001 0 0.0196 0.0001 fraction) n-hexane Content(wt. 0.0036 0 0.0643 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): Water/Oil Component Gas Service Heavy Oil Light 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 J 1.4E-02 Source: EPA-453/R-95-017 Table 2-4 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 extended gas analysis. Point 007: Emission Emission I Factors - Factors - Uncontrolled Controlled Pollutant lb/MMscf vented lb/MMscf vented Source NOx 0.068 0.068 AP-42 (lb/MMBTU) . CO 0.37 0.37 AP-42 (lb/MMBTU) VOC 17598 879.88 Gas Analysis Benzene 37.509 I 1.8755 Gas Analysis n-Hexane 222.61 11.131 Gas Analysis Toluene 26.986 1.3493 I Gas Analysis Xylenes 8.9642 0.4482 I Gas Analysis AIRS ID: 123/9BBO Page 19 of 21 epa en li ealth and Environment T Pollution Control Division The displacementDolor i m' ntory I ement 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 1,346 BTU/scf was used for calculations. Point 008: Weight Emission Emission Pollutant Fraction of Factors Factors Source Gas r/o) Uncontrolled Controlled lb/MMscf lb/MMscf NOx - 0.068 0.068 AP-42 (Ib/MMBTU) CO -- 0.37 0.37 AP-42 (Ib/MMBTU) VOC 28.5 17598 879.88 Gas Analysis Benzene 0.06 37.509 1.8755 Gas Analysis Toluene 0.04 26.986 1.3493 Gas Analysis Ethylbenzene 0.005 3.0815 0.1541 Gas Analysis Xylenes 0.01 8.9642 0.4482 Gas Analysis n-hexane 0.36 222.61 11.131 Gas Analysis Emission factors for CO and NOx found in AP-42 Table 13.5-1. A HHV of 1,346 BTU/scf was used for calculations. Points 009 and 010: Weight Emission -- - _- Pollutant Fraction of Factors Gas(%) Uncontrolled Source lb/MMscf NOx --- 0.068 AP-42 (Ib/MMBTU) CO --- 0.37 AP-42 (Ib/MMBTU) VOC 56.7 49,639 Gas Analysis Benzene 0.12 105.12 Gas Analysis Toluene 0.08 69.781 Gas Analysis Ethylbenzene 0.01 8.4040 Gas Analysis Xylenes 0.02 15.968 Gas Analysis n-hexane 0.72 630.09 Gas Analysis Note: The uncontrolled VOC and HAP emissions were calculated using a gas sample collected 9/11/2013 of the gas vented from the low pressure separator at State Antelope J-F-28HNB (which is not a site-specific sample)to estimate the VOC and HAP content of the stream and a Promax model to estimate stream flow. Actual controlled VOC and HAP emissions shall be calculated based on actual VRU operating time, a control efficiency of 100%during VRU uptime, and a flare control efficiency of 95%during VRU downtime. Emission factors for CO and NOx are based on AP-42 Table 13.5-1. A HHV of 1,895 BTU/sd 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 AIRS ID: 123/9BB0 Page 20 of 21 • olor :i Depa en P li ealth and Environment it Pollution Control Division associated with thi 9Wor . Lqu=: •+9. .reg ecific ' tion date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Status Requirement Synthetic Minor Source of: Operating Permit VOC, total HAPs, n-hexane 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 OOO-Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 163,8980-End Subpart NNNNN—Subpart XXXXXX 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/oilqa spermits AIRS ID: 123/9880 Pape 21 of 21 Division Information Engineer: Carissa Money Control Engineer: Chris Laplante Review Date: 05/15/2014 Application Date: 11/18/2013 Facility Identifiers Permit No. 14WE0040 AIRs County# 123 Weld Facility# 9BB0 Facility Type: exploration and production facility E Located in the 8-hour non-attainment area? 0 True Minor 0 Synthetic Minor for: i VOC IM NOx I— CO Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: State Antelope T-28 Source Location: SESE Section 28,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@bonanzacrk.com IRequested Action Self Certification Required? Yes Issuance Number: 1 Source Description: Oil and gas exploration and production facility known as the State Antelope T-28, located in the SESE Section 28,Township 5N, Range 62W,Weld County,Colorado. Point Name Type Control 003 Condensate Condensate Tanks Flare Tanks 004 PW Tanks Water Tanks Flare 005 TL Loadout None 006 FUG Fugitives None 007 P-1 Pump Flare 008 FL-1 Separator Venting Flare This is an emergency flare when pipline not av 009 HLP Sep-1 Separator Venting Flare Also controlled by VRU 010 HLP Sep-2 Separator Venting Flare Also controlled by VRU 003 Six(6)above ground 500 bbl atmospheric condensate storage tanks Requsted Throughput 214620 bbl Control Flare 1 Efficiency 95.00%I Emissions Summary Table Pollutant Emission Factor - Uncontrolled Emissions Controlled Emissions Source VOC 1.2449 lb/bbl 133.6 tpy 6.7 tpy E&P TANK Benzene 0.0095 lb/bbl 2038 lb/yr 102 lb/yr E&P TANK n-Hexane 0.0544 lb/bbl 11676 lb/yr 584 lb/yr E&P TANK Toluene 0.0058 lb/bbl 1248 lb/yr 62 lb/yr E&P TANK Ethylbenze 0.0004 lb/bbl 77 lb/yr 4 lb/yr E&P TANK Xylenes 0.0011 lb/bbl 242 lb/yr 12 lb/yr E&P TANK 2,2,4-TMP 0.0023 lb/bbl 504 lb/yr 25 lb/yr E&P TANK Nox 0.068 lb/Mmbtu 0.26 tpy 0.26 tpy AP-42 Table 1 CO 0.37 lb/Mmbtu 1.39 tpy 1.39 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. 14WE0040.CP1 123/9880 003 Six(6)above ground 500 bbl atmospheric condensate storage tanks Regulation 7—Volatile Organic Compounds. XII.VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS Applicant is subject to the emission control requirements for condensate tanks 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. 14WE0040.CP1 123/98B0 • 004 Two(2)above ground 400 bbl atmospheric produced water storage tanks and two(S Emissions Calculations Requsted Throughput 148920 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.262 lb/bbl 19.5 tpy 1.0 tpy CDPHE Benzene 0.007 lb/bbl 1042 lb/yr 52 lb/yr CDPHE n-Hexane 0.022 lb/bbl 3276 lb/yr 164 lb/yr CDPHE Pollutant Controlled Emission Factor VOC 0.0131 lb/bbl Benzene 0.00035 lb/bbl n-Hexane 0.0011 lb/bbl 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. 14WE0040.CP1 123/9880 005 Truck Condensate Loadout 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 S Saturation Factor 0.6 AP-42 P True Vapor Pressure 6.98 psia Sales Oil Analysis documenting RVP 9.1 and AP M Molecular Weight of Vaf 67.06 lb/lb-mole Sales oil analysis for RVP 9.1 and interpolating v T Liquid Temperature 523.67 deg. R EPA Tanks Met Data for Denver, CO L 6.68 lb/10^3 gal 2.81E-01 lb/bbl Annual requested Throughput 214620 BBL/yr 9014040 gal/yr Annual requested VOC emissions 60235 lb/yr 30.12 tpy Control: None Efficiency: 0.00% NCRPs Component Mass Fraction Benzene 0.0125 n-hexane 0.0643 Toluene 0.0281 Xylenes 0.0196 Ethylbenzen 0.0054 2,2,4-TMP 0.0083 Source: Pressurized oil analysis Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.2807 lb/bbl 30.12 tpy 30.12 tpy AP-42 Benzene 0.0035 lb/bbl 754 lb/yr 753.60 lb/yr AP-42 n-Hexane 0.0180 lb/bbl 3871 lb/yr 3871.25 lb/yr AP-42 Toluene 0.0079 lb/bbl 1693 lb/yr 1693.03 lb/yr AP-42 Xylenes 0.0055 lb/bbl 1181 ib/yr 1181.39 lb/yr AP-42 Ethylbenzen 0.0015 lb/bbl 328 lb/yr 328.04 lb/yr AP-42 2,2,4-TMP 0.0023 lb/bbl 497 lb/yr 497.00 lb/yr AP-42 Regulatory Review 'Regulation 7-Volatile Organic Compounds 14WE0040.CP1 123/9680 005 Truck Condensate Loadout This facility is not considered a bulk plant(in Reg.7)because it does not distribute gasoline. 14WE0040.CP1 E0040.CP1 123/98 BO 006 Fugitive VOC equipment leaks Regulation 7 Information Operating Hours 3760 hours/year Emission Factor Source EPA-453/R-95-017 Table 2-0 • Control El6C.enCy Source: None Calculations Emission Factor Ikg/hr-• Emissions Service Component Type Countsource) Control l%I Pollutant Mass Fraction (toy) • Table 2.4 Table 2A Reg.3 Connectors 1270 2.00E-04 1.00E-05 00% VOC 0.2055 53396 Flanges 58 3.90E-34 570E-06 0 0% Benzene O000609 00114 Open-Ended Lines 38 203E-03 1.50E-05 0 0% Toluene O000038 0.0002 Gas Pump Seals 4 240E-03 3.50E-04 00% Elbylbenzene 000005 0.0009 Valves 167 4.50E-03 2.50E-05 0 Xylenes 0000146 00027 Other 94 8.80E-03 120E-4 0.0% n-Hexane 0003612 0.0676 Connectors 0 7.50006 7 50E-06 00% VOL 1 00000 Flanges 0 390E-02 390E-07 0.0% Benzene 00000 Open-Ended Lines 0 1.00E-04 120E-06 0 0% Toluene 0.0000 Heavy Oil Pump Seals 0 000E+W 0.00E+00 0 Elnylbenzene 00000 Valves 0 840E-06 840E-06 00% Xylenes 0.0000 Other 0 330E-05 3.20E-05 0 n-Hexane 00000 Connectors 606 210E-0a 7.50E-06 0 0% VOC 0.9968 39133 Flanges 16 110E-0a 340E-06 00% Benzene 0.0125 00491 Open-Ended Lines 6 1.60E-03 1.40E-05 30% Toluene 0.3201 0.1103 Light Oil Pump Seals D 1.30E-02 510ECd 0.0% Ethylbenzene 00054 00212 Valves 78 250E-03 190E-05 00% Xylenes 00196 0.0766 Other 10 7.50E-03 1.10EC4 00% n-Hexane 00643 02520 Connectors 534 1.10E-04 1.00E 05 0 VOC 1 3.3245 Flanges 20 2.90E-06 290E-00 0 Benzene 0.0012 00040 open-Ended Lines 2 2.50E-04 350E-00 00% Toluene 0.0003 00010 walerro0 Pump Seals 1 240E-0E 240E-05 0.0% Elbylbeezene 00001 00003 Valves 50 980E-05 970E-06 00e Xylenes 00001 00003 Other 20 140E-02 560E-05 0 0% n-Hexane 00001 00003 Emissions Summary Table hollslanl Uncontrolled Emissions Controlled Emissions Source Ipy VOC r256IFS 12.58 Ipy EPA-453R-46517 Table 2-4 Benzene 1291luvr 128.91 lb/yr EPA-453/5-95O17 Table 2-4 006 Toluene 235 lb/yr 239.01 iblyr EPA-453/R-95-017 Table 24 012 Elbylbenzene 45 lb/yr 4493 lb/yr EPA-4530R-95-017 Table 24 002 XNenes 160 Iblyr 16002 lb/yr EPA-453/R-95-017 Table 2-4 0.08 n-Hexane 641 Iblyr 640.64 Iblyr EPA453/R-95-017 Table 2-4 032 Regulatory Applicability The dale of interest for determining wnether the source is new or modified is therefore November 20.2007(the dale of the 8-hour ozone NA area deslgnatlon).Since the site was built alter the dale above loperation began 012120131,this Reg.3 source rs considered'new or modified:Operator has agreed on rare Division's standard conditions. VOC and HAP concentrations fon gas service are based on sales gas sample collected 10/1912013 from Slate Anlelop T-29-21XRLNB.Since site-specific and eolhln I year of application dale.no initial samgling required 10WE0040.CP1 123/9500 One(1)water transfer pump,rated at 1,320 scf/hr(Sandpiper,Model G20, Serial number 2091585).The pneumatic pump is controlled by an enclosed 007 flare with a minimum combustion efficiency of 95%. Pump Information Manufactur Sandpiper Model Number: G20 Serial Pump Number: 2091585 Information Pump capacity 25.2 gallons per minute pumped natural gas 1320 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 Q 1320 scf/hr MW 23.4 Ib/Ib-mol Hours of Op. 8760 hours/yr Requested Throughput 11.5632 MMscf/yr Component mole% MW mass fraction Component lb/hr Ib/yr tpy CO2 2.4 44 0.0451 CO2 3.678 32218.309 16.109 nitrogen 867 28 0.0080 nitrogen 0.653 5723.631 2.862 methane 6965802 16.04 0.4775 methane 38.914 340890.044 170.445 ethane 14.1942 30.07 0.1824 ethane 14.865 130221.645 65.111 propane 0.6373 44.09 0.1627 propane 13.263 116186.837 58.093 isobutane 0.7809 58.12 0.0194 isobutane 1.581 13847.133 6.924 n-butane 2.3025 58.12 0.0572 n-butane 4.661 40828.561 20.414 isopentane 0.3786 72.15 0.0117 isopentane 0.951 8334.044 4.167 n-pentane 0.476 72.15 0.0147 n-pentane 1.196 - 10478.090 5.239 cyclopentane 0.0369 70.15 0.0011 cyclopentane 0.090 789.756 0.395 n-hexane 0.0979 86.18 0.0036 n-hexane 0.294 2574.115 1.287 cyclohexane 0.0253 84.18 0.0009 cyclohexane 0.074 649.783 0.325 Other hexanes 0.1658 86.18 0.0061 Other hexane 0.498 4359.431 2.180 heptanes 0O8os 100.21 0.0034 heptanes 0.281 2461.194 1.231 methylcyclohexa 0.0191 98.19 0.0008 methylcyclohe 0.065 572.189 0.286 224-TMP a 114.22 0.0000 224-TMP 0.000 0.000 0.000 Benzene 00182 78.11 0.0006 Benzene 0.050 433.727 0.217 Toluene 00111 92.14 0.0004 Toluene 0.036 312.040 0.156 • Ethylbenzene 0.0011 106.17 0.0000 Ethylbenzene 0.004 35.631 0.018 Xylenes 0.0032 106.17 0.0001 Xylenes 0.012 103.655 0.052 CB+Heavies 0.0429 116 0.0021 C8+Heavies 0.173 1518.288 0.759 Mass Fraction VOC: 0.2850 Total VOC 101.742 Heating Value I 1346 BTU/scf Combustion emission factor source: AP-42,Chapter 13.5 14WE0040.CP1 . 123/9660 One(1)water transfer pump,rated at 1,320 scf/hr(Sandpiper,Model G20. Serial number 2091585).The pneumatic pump is controlled by an enclosed 007 flare with a minimum combustion efficiency of 95%. 0 07 lb NOX/MMBtu 0 37 lb CO/MMBtu Notes Mole%,MW,and mass fractions from: sales gas analysis collected 1019/2013 at State Antelope T-28-21XRLNB Typical%I would use the calculated MW for C8t which resulted in 102.4 tpy.Source used 116 for MW for C8+Since minimal difference in emissions,I used source's values Emissions Summary Table Pollutant Uncontrolled Emission Fa Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 17598 lb/MMscf 879.88 lb/MMscf 101.74 tpy 5.09 tpy Gas Analysis Nox 0.07 Ib/MMBTU 0.07 lb/MMBTU 0.53 tpy 0.53 tpy AP-42 CO 0.37 Ib/MMBTU 0.37 Ib/MMBTU 2.88 tpy 2.88 tpy AP-42 Benzene 37.509 lb/MMscf 1.8755 lb/MMscf 434 lb/yr 221b/yr Gas Analysis n-Hexane 222.61 lb/MMscf 11.131 lb/MMscf 2574 lb/yr 12916/yr Gas Analysis Toluene 26.986 lb/MMscf 1.3493 lb/MMscf 312 lb/yr 16 lb/yr Gas Analysis Xylenes 8.9642 lb/MMscf 0.4482 lb/MMscf 104 lb/yr 5 lb/yr Gas Analysis Ethylbenzene 3.0015 lb/MMscf 0.1541 lb/MMscf 36 lb/yr 2 lb/yr Gas Analysis 14W E0040.CP1 123/9880 One emergency flare with a minimum combustion efficiency of 95%. The Bare is not enclosed.The emergency flare is 008 used during periods when the pipeline is not available. Equipment Description I This source vents natural gas from: a well head separator when the sales pipeline is not available Emissions from this source are: routed to a flare 'Natural gas venting from a well head separator when the sales pipeline is not available.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 pollutant x O=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/lb-mol)at 60F and 1 atm Throughput(O) 14.25 MMscf/yr 1626.712329 scf hr MW 23.4 IbIb-mal 0.0390410%MMscf/d I mole% MW Ibwlbmol mass fraction lb/hr lb/yr tpy Helium 0.00 4.0026 0000 0.000 0.00 0.00 0.00 CO2 2,4 44.01 1.056 0.045 4.53 39713.51 19.86 N2 0.67 28.013 0.188 0.008 0.81 7056.84 3.53 methane 6965802 16.041 11.174 0.478 47.96 420124.70 210.06 ethane 14.1942 30.063 4.287 0.182 18.32 160442.30 80.22 propane 66373 44.092 3.808 0.163 16.35 143190.25 71.60 iscbutane 07800 58.118 0.454 0.019 1.95 17064.04 8.53 n-butane 2.3025 58.118 1.338 0.057 5.74 50313.67 25.16 isopentane 03786 72114 0.273 0.012 1.17 10265.40 5.13 n-pentane 0.476 72.114 0.343 0.015 1.47 12906.31 6.45 cydopentane 0.0389 70.13 0.026 0,001 0.11 972.98 0.49 n-Hexane 0.0979 86.18 0.084 0.004 0.36 3172.23 1.59 cyclohexane 0.0253 84.16 0.021 0.001 0.09 800.57 0.40 Other hexanes 01858 86.18 0.143 0.006 0.61 5372.38 2.69 heptanes 00805 100.21 0.081 0.003 0.35 3033.07 1.52 methylcyclohexane 0.0191 98.19 0.019 0.001 0.08 705.14 0.35 224-TAP 0 114.23 0.000 0.000 0.00 0.00 0.00 Benzene 0.0182 78.12 0.014 0.0006 0.06 534.58 0.27 Toluene 0.0111 92.15 0.010 0.0004 0.04 384.59 0.19 Ethylbenzene o owl 108.17 0.001 0.0000 0.01 43.91 0.02 Xylenes 0.003.2 106.17 0.003 0.0001 0.01 127.74 0.06 C8*Heavies 00429 11e 0.051 0.0022 0.22 1903.33 0.95 VOC mass frac 0.285 Total VOC(Uncontrolled) 125.40 Notes Mole%,MW,and mass fractions are based on sales gas analysis collected 1W19/2013 from State Antelope T-28-21XRLNB Emissions are based on 8760 hours of operation per year. Typically I calculate the average MW of C8+based on the average MW on the analysis for the gas.This method resulted in 125.55 tpy Source used MW of 118 for C8*.Since there is minimal difference in emissions,I used the source's values, 14WEoo40.CP1 123/9860 One emergency flare with a minimum combustion efficiency of 95%. The flare is not enclosed.The emergency flare is 008 used during periods when the pipeline is not available. Flaring Information Equipment Description Flare to combust produced gas until pipeline is available at this wellhead facility. Manufacturer TBD Model TBD Serial Number TBD Gas Heating Value 1346 Btu/scf Throughput 19180.5 MMBtu/yr VRU Information-NOT APPLICABLE Equipment Description Make Model Requested Control Efficiency Annual Bypass Time Backup Flare [Overall Control 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.07 Ilb NOX/MMBtu 0.37 JIb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emit sons Source VOC 17599 lb/MMscf 879.97 Ib/MMSCf 125.40 tpy 6.27 tpy Gas Analysis Nox 0.071b/MMBTU 0.07lb/MMBTU 0.65 tpy 0.65 tpy AP-42 CO 0.37 lb/MMBTU 0.37 lb/MMBTU 3.55 rpy 355 tpy AP-42 Benzene 37.514 lb/mMscf 1.88 lb/MMscf 535 lb/yr 27 lb/yr Gas Analysis n-Hexane 222.61 lb/MMscf 11.13 lb/MMscf 3172 lb/yr 1591b/yr Gas Analysis Toluene 26.98916/MMscf 1.35 lb/MMscf 385 lb/yr 19 lb/yr Gas Analysis tylenes 8.9642 lb/MMscf 0.45 lb/MMscf 128 lb/yr 6 lb/yr Gas Analysis Ethylbenzene 30815 lb/MMscf 0.15 lb/MMscf 441b/yr 2 lb/yr Gas Analysis Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II A.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' AQCC Regulation 2 Section I,A applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air." 14WE0040.CP1 123/9860 One low-pressure separator controlled by a VRU and enclosed flares.Each flare has a minimum combustion efficiency 009 of 95%. Equipment Description This source vents natural gas from: a well head separator Emissions from this source are: recompressed INalural gas venting from a well head separator.Emissions from this source are recompressed. I 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 CI=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 sct/lb-mop at 60F and 1 atm Throughput(0) 11.2 MMscf/yr 1278.538813 scf/hr MW 33.2 lb/lh-rnol 0.030684932 MMscf/d mole% MW Ibxabmol mass fraction IbAy Ib/yr tpy Helium 0.0000 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 2.6100 44.01 1.149 0.035 3.87 33944.60 16.97 N2 0.1100 28.013 0.031 0.001 0.10 910.61 0.46 methane 36.4647 16.041 5.849 0.176 19.73 172855.38 86.43 ethane 24.3204 30.063 7.311 0.220 24.66 216063.72 108.03 propane 22.8132 44.092 10.059 0.303 33.93 297252.02 148.63 isobutane 2.3670 58.118 1.376 0.041 4.64 40652.54 20.33 n-butane 7.2540 58.118 4.216 0.127 14.22 124585.36 62.29 isopentane 1.1875 72.114 0.856 0.026 2.89 25306.50 12.65 n-pentane 1.4761 72.114 1.064 0.032 3.59 31456.77 15.73 cydopentane 0.1075 70.13 0.075 0.002 025 2227.88 1.11 n-Hexane 02771 86.18 0.239 0.0072 0.81 7057.03 3.53 cydohexene 0.0699 84.16 0.059 0.002. 0.20 1738.45 0.87 Other hexanes 0.4770 86.18 0.411 0012 1.39 12147.97 6.07 heptanes 0.2098 100.21 0.210 0006 0.71 6212.91 3.11 methylcycbhexane 0.0506 98.19 0.050 0.001 0.17 1468.24 0.73 224-TMP 0.0001 11423 0.000 0.000 0.00 3.38 0.00 Benzene 0.0510 78.12 0.040 0.0012 0.13 1177.37 0.59 Toluene 0.0287 9215 0.026 0.0008 0.09 781.55 0.39 EltMbenzene 0.0030 106.17 0.003 0.0001 0.01 94.12 0.05 Xylenes 0.0057 106.17 0.006 0.0002 0.02 178.64 0.09 C8+Heavies 0.1053 116 0.122 0.0037 041 3609.65 1.80 VOC mass frac 0.567 Total VOC(Uncontrolled) 277.98 Notes Mole%,MW,and mass fractions are based on LP separator gas analysis collected 9/11/2013 from State Antelope J-F-28HNB Emissions are based on 8760 hours of operation per year. 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. 14WE0040.CP1 123/9360 One low-pressure separator controlled by a VRU and enclosed flares.Each flare has a minimum combustion efficiency 009 of 95%. Flaring Information Equipment Description Flare to combust produced gas until pipeline is available at this wellhead facility. Manufacturer Leed Model L30-001048' Serial Number 20737,20736,19114,19113.20939.20940 Gas Heating Value 1895 Btu/scf Throughput 10612 MMBtu/yr VRU Information Equipment Description Engine to recompress gas to sales line. Make GasJack Model GJ230 Requested Control 100 00% • Annual Bypass Tim 50.00% Backup Flare 'Overall Control j 97.50%1 Combustion emission factor source: AP-42.Chapter 13.5 0.07 JIb NOX/MMBtu 0.37 IIb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 49638.44 lb/MMscf 1240.961h/MMscr 27798 spy 6.95 tpy Gas Analysis Non 0.07 lb/MMBTU 0.07 Ib/MMBTU 0.36 tpv 0.36 toy AP-42 CO 0.37 lb/MMBTU 0.3716/MMBTU I 96 toy 20 spy AP-42 Benzene 105.12 lb/MMscf 2.6316/MMscf 1177.37 lb/vr 29431b/yr Gas Analysis n-Hexane 63009 lb/MMscf 15.75 lb/MMscf 705703 lb/yr 17fi431b/yr Gas Analysis Toluene 69.78 lb/MMscf 1741b/MMscf 781.55 lb/vr 19.54 lb/yr Gas Analysis Xylenes 15.97 lb/MMscf 0.40 Ib/MMscf 178.84 lb/yr 4.47 lb/yr Gas Analysis Ethylbenzene 8.40 lb/MMscf 0.21 lb/MMscf 94.12 lb/yr 2.35 lb/yr Gas Analysis Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares In Section 11 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" 14WE0040.CP1 173/9850 One low-pressure separator controlled by a VRU and enclosed flares.Each flare has a minimum combustion efficiency 010 of 95%. Equipment Description This source vents natural gas from: a wel head separator Emissions from this source are: recompressed iNatural gas venting from a well head separator.Emissions from this source are recompressed. Calculations Emission Calculation Meutoq EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=O•MW•Xx/C Ex=emissions of polutant x 0=Volomebic 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/b-mal)at 60F and 1 atm TTrou9tput(CO 11.2 MMscf/yr 1278.538813 scf/hr MW 33.21Mbmd 0.030684932 MMscf/d mole% MW lbxAbmol mass traction IMr Ib/yr 4n Helium 0.0000 4.0026 0.000 0000 0.00 0.00 0.00 CO2 2.6100 44.01 1.149 0.035 3.87 33944.60 16.97 N2 0.1100 28.013 0.031 0.001 0.10 910.61 0.46 methane 36.4647 16.041 5.849 0.176 19.73 172855.38 86.43 ethane 24.3204 30.063 7.311 0.220 24.66 216063.72 108.03 propane 22.8132 44.092 10.059 0.303 33.93 297252.02 148.63 isobutane 2.3670 58.118 1.376 0041 4.64 40652.54 20.33 n-butane 7.2540 58.118 4.216 0.127 14.22 124585.36 62.29 Iscpenlane 1.1875 72.114 0.856 0.026 2.89 25306.50 12.65 n-pentane 1.4761 72.114 1.064 0.032 3.59 31456.77 15.73 rydopenlane 0.1075 70.13 0.075 0.002 0.25 2227.88 1.11 n-Hexane 0.2771 88.18 0.239 0.007 0.81 7057.03 3.53 cydohexae 0.0009 84.16 0.059 0.002 0.20 1738.45 0.87 Other haxares 0.4770 88.18 0.411 0.012 1.39 12147.97 6.07 heptanes 0.2098 100.21 0.210 0006 0.71 8212.91 3.11 methytcyclohexane 0.0506 98.19 0.050 0.001 0.17 1468.24 0.73 224-TMP 0.0001 114.23 0.000 0.000 0.00 3.38 0.00 Benzene 0.0510 78.12 0.040 0.001 0.13 1177.37 0.59 Toluene 0.0287 92.15 0.026 0.001 0.09 781.55 0.39 Ethybenzene 0.0030 106.17 0.003 0.000 0.01 94.12 0.05 Xylenes 00057 106.17 0.006 0.000 0.02 178.84 0.09 CB+Heavies 0.1053 116 0.122 0.004 0.41 3609.65 1.80 VOC mass frac 0.567 Total VOC(Uncontrolled) 277.96 Notes Mole%,MW,and mass fractions are based on LP separator gas analysis collected 9/11/2013 from Stale Antelope J-F-28HNB Emissions are based on 8760 hours of operation per year. 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 source's values. 14WE0040.CP1 123/9880 One low-pressure separator controlled by a VRU and enclosed flares.Each flare has a minimum combustion efficiency 010 of95% Flaring Information Equipment Description Flare to combust produced gas until pi line is available at this wellhead facility. • Manufacturer Leed Model L30-001048' Serial Number 20737,20736,19114,19113.20939,20940 Gas Heaing Value 1895 Btu/scf Throughput 10612 MMBtu/yr • VRU Information Equipment Description • Engine to recompress gas to sales line. Make GasJack Model GJ230 Requested Control 100.00% Annual Bypass Tim 50 00% Backup Flare Overall Control I 97.50% Combustion emission factor source. AP-42:Cha ter 13.5 0.07 Ilb NOX/MMBtu 0.37 'JIb CO/MMBtu Emissions Summary Table Pollutant Uncontolled Emission factor Controlled Emission Factor Uncontrolled Emissions controlled Emissions Source VOC 49638.44 lb/MMscf 1240.96 lb/MMscf 27798 MY 6.9 tpy Gas Analysis Noy 0.07 lb/MMBTU 0.01 Ib/MMBTU 0.36 tpy ].4 tpy AP-42 CO 0.37 lb/MMBTU 03716/MMBTU 1.96 tpy 2.0 toy AP-42 Benzene 105.1216/MMscf 2.63 lb/MMscf 112/32 lb/yr 29.43 lb/yr Gas Analysis n-Hexane 630.09 lb/MMscf b,75 lb/MMscf 705703 lb/yr 176.43 lb/yr Gas Analysis Toluene 69.78 lb/MMscf 1.74 lb/MMscf 781.55 lb/yr 19.54 lb/yr Gas Analysis Xylenes 15.97 lb/MMsf 0.40 lb/MMscf 178.134 lb/yr 4.47 lb/yr Gas Analysis Ethylbenzene 8.40 lb/MMscf 0.21 lb/MMscf 94.12 lb/yr 2.35 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.' AQCC 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 delectable 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." 14VJE0040.CP1 123/9880 m II a O:• d b b N b N b N N N N N N N b N Oa mN>2»>-2Z>-> > i ii≥≥≥≥≥≥ > ZZ Z Z > >Z?» ZZY > Z �Lweaaeaaa'aa a aaaaa aaaa a S a a aaa aaa aaaaaa e 00000,om0) mMm00000O000000O00OO a Pb a 001 Io OW ppyy y W MOB ONN r O in O yN M MNmmN OM N' 0 N 100 ,- V 0 WON(�r OON N N a V10 anrn'nrO H r r a y yy p b O NOroc r NraNaO _ N t0 ob){pmNOm N r M t0 h r^ ,nmNONNN n N O m I r f 7 N r n a n N a 10 VI O N N t O O b o m E n ow _. - 9 N a O t0 WINO rCO mN ^Vl 6�Nr Na C . 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U 0 h X w C > Z O CO X w E > Z U 0 r x w C o 2m a ' 0 -5,E C.0 U 0 0 0 0 LID 0 0 LO 0 0 0 0 0 0 0 0 0 N 0O 0 0 0 0 0 0 N N N N N N N N 0 0 0 N N 0 N 0 N 0 O (n 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Q 0 0 0 0 0 0 O O O O O O O O 0 0 O 0 0 0 0 O O c] CI CJ Co) M 000)CI C7 C) RI c] co co c] CI (7 C) CI C) at 0 o 0 0 o o 0 Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERY Current Status(Check all that apply) Reason for APEN Submittal(Check all that apply) �. AIRS ID#1: 123 - 913%0- 003 ❑ d update only . ,-\- - _ 5 New or previously unreported battery ❑ Modification / 4 to existing source' ��^vY ❑ Previously grandfathered battery' O Registration for coverage under general permit .'GP-01 8 201- O Synthetic minor facility ( I ' VO 0 &cancellation request for individual permits: , ® Located in the 8-hr Ozone Control Area' ® Application for or Modification of an individual permit O Registered under general permit no.GPOI O Administrative permit amendment' ,_ ❑ Permitted under individual permit: ❑ Other: For individual permit applications,check if you wants: ❑A copy of the preliminary analysis conducted by the Division ❑To review a draft of the permit prior to issuance Company Names: Bonanza Creek Energy Operating Company LLC OGCC Operator#: 8960 Mailing Address": 410 17th Street,Suite 1500 City: Denver State: CO Zip: 80202 E-mail: pyoung®BonanzaCrkcom Contact Name: Peg Young Phone: 720-440-6133 Fax: 720-279-2331 Tank Battery Name11: State Antelope T-28 Production Facility(COGCC#431935) Number of tanks: 6-500 bbl Location')(QQ Sec.Twp.Range.): SE/SE Sec 28,T5N,R62W County: Weld Total tank capacity[bbl]: 3000 Calendar year for which"Actuar data applies's: 2013 Year(s)tank(s)were placed in service1d: 2013 Six(6)Leed L30-0010 48"SNs:20737,20736, 19114, 19113, Control Description's: 20939,20940 Control Efficiency's: 95% Condensate Throughput"[bbl'year] Requested": N/A Maximum for PTE calculation19: 214,620 Actual2s: 178,850 While Controls Operational" 178,850 ,/ Other equipment at facility22: Heater treaters,produced water tanks, pneumatic pump,engines,flare,high/low pressure separators. Comments: 2 year update to SSEF required. Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit O Check if the Division is to calculate emissions. 5 Check if site-specific emission factors provided to calculate emissions". Emission Factor Battery Requested Emissions's Actual Emissions'° Pollutant$° [Ib/bbl] PTE'S Uncontrolled'° Controlled$' Uncontrolled's Controlled" VOC[tons/year] ] . 4r-li .2.02 i33�Jsaa " I55,LI8028 b.L/_9A1— iil.3,15p3q -7.� NOx[tons/year] C. :? .031 part. .Es CO[tons/year] _. I.'] 169 lit Benzene[lbs/year] Q.Gii t5 T `' J-383t 2 ...)--1°3,431:2 r b= ]54- l V,t$26..0- -1263 cs c n-Hexane[Ibs/year] 0.L 5yN _0,993` I ILTr°14;6B97 i IL''146877 c,c--] 834'C zi-I3};90to b r3'y Y Wells serviced by this tank or tank battery" CL,L111 L/;.)=. H API#: 05-123-36879 Name: State Antelope T-28-2IXRLNB ®Newly Reported Well API#: 05-123-36874 Name: State Antelope 34-31-281-WEI ®Newly Reported Well API#: Name: O Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name - O Newly Reported Well API#: Name: to ❑Newly Reported Well API#: Name: :fIi:i ❑Newly Reported Well The signature below indicates that I have knowledge of the facts herein sel 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 generaYpermit GPOI,I further certify that this source is and will be operated in full comp' with each fccoonnnddition of rmit GP01. Signature of Legally Aut e erson(not a vendor or consultant) 11:--„' Date David J.Lillo Vice President,Rocky Mt.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 Environment For information call: filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-BI (303)692-3150 • $250 General Permit fee for each new GP 4300 Cherry Creek Drive South 301468 registration to: Denver,CO 80246-1530 FORM APCD-205 Page I of 2 FormAPCD-205-E&PCondensateTankAPEN.docx e Y ❑ E e ` E Z O o a e o• a eI. ' a ,.o, 0 �N E a6 T ta 9 - e Y 4 tr. 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