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Home My WebLink About20150466.tiff 1 COPHE COLORADO CO Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado RECEIVED Weld County - Clerk to the Board 1150OSt F.;....- 06 L•f 1 PO Box 758 Greeley, CO 80632 WELD COUNTY COMMISSIONERS January 29, 2015 Dear Sir or Madam: On February 4, 2015, the Air Pollution Control Division will begin a 30-day public notice period for Bonanza Creek Energy Operating Company LLC - Pronghorn B-28 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, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 2015-0466 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe :�r r`? :1 oq 9 -1$ _tl s John W. Hickenlooper,Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer CDPHE Air Pollution Control Division Co Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Bonanza Creek Energy Operating Company LLC - Pronghorn B-28 Production Facility - Weld County Notice Period Begins: February 4, 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: Pronghorn B-28 Production Facility Oil and gas exploration and production facility SWNW Sec 28, T5N, R61W 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): • 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 14WE1084 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 m. COLON DO n. A 9,AZ,. STATE OF COLORADO •LO- •1i i D • • -Tr .. OF P C HEALTH AND ENVIRONMENT ff- cow AIR POLLUTION CONTROL DIVISION ye 7 TELEPHONE: (303)692-3150 ; `� •187+x' CONSTRUCTION PERMIT PERMIT NO: 14WE 1084 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 Pronghorn B-28 Production Facility, located in the SWNW Section 28, Township 5N, Range 61W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Eight(8)400 bbl above ground atmospheric condensate storage Condensate 007 tanks controlled by three enclosed flares. Each flare has a Tanks minimum control efficiency of 95%. Two (2)400 bbl above ground atmospheric produced water storage tanks and one(1) 60 bbl concrete vault for produced PW Tanks 008 water. The 400 bbl storage tanks are controlled by three enclosed flares. Each flare has a minimum control efficiency of 95%. One emergency flare with a minimum control efficiency of 95%. FL-2 009 The flare is not enclosed. The emergency flare is used during periods when the pipeline is not available or during emergencies. One low-pressure separator controlled by three enclosed flares Sep-1 010 during VRU downtime. Each flare has a minimum control efficiency of 95%. One low-pressure separator controlled by three enclosed flares Sep-2 011 during VRU downtime. Each flare has a minimum control efficiency of 95%. One low-pressure separator controlled by three enclosed flares Sep-3 012 during VRU downtime. Each flare has a minimum control efficiency of 95%. AIRS ID: 123/9C78 Page 1 of 23 olor epa en fir ealth and Environment Pollution ConUd Division AIRS Facility Equipment Point Description ID One vapor recovery tower(VRT)controlled by three enclosed VRT-1 013 flares during VRU downtime. Each flare has a minimum control efficiency of 95%. One (1) pneumatic water transfer pump, rated at 600 scf/hr P-1 014 (Sandpiper, Model G1F, Serial number 2091566).The pneumatic pump is controlled by three enclosed flares. Each flare has a minimum control efficiency of 95%. Truck Condensate Loadout that is controlled by using dedicated Truck vapor balance service and three enclosed flares. Collection Loadout 015 system is 70%and each flare has a minimum control efficiency of 95%. FUG 016 Fugitive VOC equipment leaks Point 014: 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 sec), 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 009: 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/ao/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 009: 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 009: 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). AIRS ID: 123/9C78 Page 2 of 23 olor. ■epa en P •Ii ' ealth and Environment it Pollution Control Division 4. AIRS Points •. '8, .^. ' • Y. + _: noti^ e Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, 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 007, 008, 010 — 016: 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 010-013: 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 Equipment ID Point NO VOC CO Emission Type x Condensate 007 3.2 Point Tanks PW Tanks 008 --- 1.0 --- Point FL-2 009 --- 4.2 2.4 Point AIRS ID: 123/9O78 Page 3 of 23 olor epa en P li ealth and Environment it Pollution Control Division Sep-1 10 — -- Point Sep-2 011 — 2.7 -- Point Sep-3 012 — 2.7 -- Point VRT-1 013 - 10.5 1.8 Point P-1 014 — 2.2 1.3 Point Truck Loadout 015 13.2 Point FUG 016 16.9 Fugitive See "Notes to Permit Holder"for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 11. AIRS Point 016: 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 007 Enclosed Flare VOC Tanks PW Tanks 008 Enclosed Flare(400 bbl tanks only) VOC FL-2 009 Open Flare VOC Sep-1 010 Enclosed Flare VOC Sep-2 011 Enclosed Flare VOC Sep-3 012 Enclosed Flare VOC AIRS ID: 123/9C78 Page 4 of 23 Ill olor eepa en . P >.li ealth and Environment •it Pollution Control Division VRT-1 :,...._ :- ..:::.. .,- fare VOC P-1 014 Enclosed Flare VOC Truck 015 Vapor balance and Enclosed Flare VOC Loadout 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 Equipment Point Process Parameter Annual Limit ID Condensate 007 Condensate Throughput 262,800 BBL Tanks PW Tanks 008 Produced Water Throughput 146,000 BBL FL-2 009 Total Gas Vented from All Separators to 10.0 MMSCF Emergency Flare Sep-1 010 Total Gas Vented from Low-Pressure Separator 0.9 MMSCF during VRU Downtime Sep-2 011 Total Gas Vented from Low-Pressure Separator 0.9 MMSCF during VRU Downtime Sep-3 012 Total Gas Vented from Low-Pressure Separator 0.9 MMSCF during VRU Downtime VRT-1 013 Total Gas Vented from Vapor Recovery Tower 3.1 MMSCF during VRU Downtime P-1 014 Natural Gas Consumed 5.3 MMSCF Truck 015 Condensate Loaded 262,800 BBL Loadout 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 010 - 013: 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 the low pressure separators 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. AIRS ID: 123/9C78 Page 5 of 23 olo epa en li ealth and Environment 'r Pollution Control Division STATE AND FEDE G T E NTS 15. AIRS Points 007 - 015: 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. AIRS Point 007: 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 007: 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 007: 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 007 and 008: 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, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XVII. XVII.B.2.d.(ii) All combustion devices installed before May 1, 2014, must be equipped with an operational auto-igniter by or-before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. AIRS ID: 123/9C78 Page 6 of 23 olorl Depa en : P +li " ealth and Environment iA it Pollution Control Division 22. AIRS Points .+ Ot . .T .g> .. <;n.*vere. , 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. 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. AIRS ID: 123/9C78 Page 7 of 23 olor epa en li ealth and Environment it Pollution Control Division XVII.C.2.a. O ra ust r II 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., k/II.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 Schedule Emissions (tpy) Frequency >6 and< 12 Annually January 1,2016 > 12 and <50 Quarterly July 1, 2015 AIRS ID: 123/9C78 Page 8 of 23 olor Depa en • P •li ealth and Environment a ;l it Pollution Control Division 50 r 0 thly . ::::: 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 009: 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.) 24. AIRS Point 015: 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 015: 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: 123/9C78 Page 9 of 23 olor epa en li ealth and Environment it Pollution Control Division a. Hoses s, v al fined 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 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 015: 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 016: 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 I I I.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: 123/9C78 Page 10 of 23 olor Depa en . P .Ii ealth and Environment •it Pollution Control Division i°. . <6 O I ' 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 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. 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: 123/9C78 Page 11 of 23 .r.rr...r olor epa en li om it Pollutionealthand ContrEnvirol Divisionnent XVII.F.7.c. Le v u o t 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.6. 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 016: 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: 123/9C78 Page 12 of 23 olor. •epa en • P •Ii ealth and Environment ao it Pollution Control Division ty.. s-. ' le. han ^°••0 ppm shall not require repair. For such component leaks that require a shutdown to be repaired, repair shall occur during the first shutdown of the affected operation after the leak is discovered. Hi. For repair, valves adjacent to the equipment to be repaired will be closed if practicable, minimizing the volume released. iv. Repaired components shall be re-screened using AVO to determine if the leak is repaired. v. The following records shall be maintained for a period of two years: • The name of the site screened via AVO inspection and the name of the inspector. • Components evaluated with the gas detector. • Repair methods applied. • Dates of the AVO inspections, gas detector calibrations, attempted repairs, successful repairs, repair delays, and post- repair screenings. vi. Leaks shall be repaired as soon as practicable, but no later than 15 calendar days after detection, unless it is technically or operationally infeasible to make the repair within 15 calendar days. Records documenting the rationale shall be maintained if it is technically or operationally infeasible to make the repair within 15 calendar days. OPERATING & MAINTENANCE REQUIREMENTS 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 015: 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. d. Operate all recovery and disposal equipment at a back pressure less than the pressure relief valve setting of transport vehicles. e. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. f. Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs shall be set to release at a pressure that will ensure AIRS ID: 123/9C78 Page 13 of 23 epa en li ealth and Environment 'r Pollution Control Division flashinDolor b I rout 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 009: 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) 33. AIRS Point 013: 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. 34. AIRS Point 016: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. Periodic Testing Requirements 35. AIRS Point 016: 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 014: 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. 37. AIRS Point 014: 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. 38. AIRS Point 014: All pump replacements installed and operated per the altemate operating scenarios authorized by this permit must comply with all terms and conditions of this construction permit. AIRS ID: 12319C78 Page 14 of 23 . 6 olor- ■epa en - F' di ' ealth and Environment A,, •it Pollution Control Division ADDITIONAL REQ N 39. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5)tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO,) in ozone nonattainment areas emitting less than 100 tons of VOC or NO. per year, a change in annual actual emissions of one (1)ton per year or more or five percent,whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 40. 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 41. 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. 42. 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 AIRS ID: 123/9C78 Page 15 of 23 epa en li ealth and Environment it Pollution Control Division the permit. Dolor ti I been ' wed 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. 43. 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. 44. 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. 45. 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. 46. 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. 47. 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: 123/9C78 Page 16 of 23 olor. Pepe en : P .li ealth and Environment , A it Pollution Control Division lu 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.gov/cs/Satellite?c=Document C&childpaqename=CDPHE- Main%2FDocument C%2FCBONAddLinkView&cid=1251599389641&pacename=CBONWrapper 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s)operate at the permitted limitations. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Rate Point Pollutant CAS# (Ib/yr) reportable? (Ib/yr) Benzene 71432 1,265 Yes 63 n-Hexane 110543 7,665 Yes 383 Toluene 108883 1,012 Yes 51 007 Ethylbenzene 100414 125 No 6 Xylenes 1330207 319 Yes 16 2,2,4- 540841 632 Yes 32 trimethylpentane Benzene 71432 1,022 Yes 51 008 n-Hexane 110543 3,212 Yes 161 Benzene 71432 367 Yes 18 n-Hexane 110543 2,281 Yes 114 009 Toluene 108883 265 Yes 13 Ethylbenzene 100414 34 No 2 Xylenes 1330207 78 No 4 Benzene 71432 512 Yes 26 n-Hexane 110543 3,298 Yes 165 010 Toluene 108883 359 Yes 18 Ethylbenzene 100414 29 No 1 AIRS ID: 12319C78 Page 17 of 23 olo epa en li ealth and Environment 'r Pollution Control Division XyD 0 3 Benzene 71432 512 Yes 26 n-Hexane 110543 3,298 Yes 165 011 Toluene 108883 359 Yes 18 Ethylbenzene 100414 29 No 1 Xylenes 1330207 62 No 3 Benzene 71432 512 Yes 26 n-Hexane 110543 3,298 Yes 165 012 Toluene 108883 359 Yes 18 Ethylbenzene 100414 29 No 1 Xylenes 1330207 62 No 3 Benzene 71432 5,404 Yes 270 n-Hexane 110543 32,616 Yes 1,631 Toluene 108883 4,265 Yes 213 013 Ethylbenzene 100414 518 Yes 26 Xylenes 1330207 1,305 Yes 65 2,2,4- 540841 2,293 Yes 115 trimethylpentane Benzene 71432 193 No 10 n-Hexane 110543 1,199 Yes 60 014 Toluene 108883 139 No 7 Ethylbenzene 100414 18 No 1 Xylenes 1330207 41 No 2 Benzene 71432 757 Yes 254 n-Hexane 110543 4,360 Yes 1,461 Toluene 108883 1,668 Yes 559 015 Ethylbenzene 100414 522 Yes 175 Xylenes 1330207 1,512 Yes 507 2'2'4 540841 623 Yes 209 trimethylpentane Benzene 71432 178 No 178 n-Hexane 110543 1,040 Yes 1,040 016 Toluene 108883 327 Yes 327 Ethylbenzene 100414 97 No 97 Xylenes 1330207 277 Yes 277 AIRS ID: 123/9C78 Page 18 of 23 olor Depa en . P fill '' ealth and Environment �i .F it Pollution Control Division 5) The emission level I. d i ;:• p .:..... b- •I :: .- : -- folio -..- - ission factors: Point 007: Emission Factors Emission Factors Uncontrolled Controlled Pollutant lb/BBL Ib/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 0.4916 0.0246 Promax n-Hexane 0.0292 0.0015 Promax Benzene 0.0048 0.0002 Promax Toluene 0.0038 0.0002 Promax Ethylbenzene 0.0005 0.00002 Promax Xylenes 0.0012 0.0001 Promax 2,2,4- 0.0024 0.0001 Promax trimethylpentane Note: The controlled emissions for this point are based on the flare control efficiency of 95%. A HHV of 3,172 BTU/scf was used for combustion calculations. Point 008: Emission Factors Emission Factors Pollutant Uncontrolled Controlled Source lb/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 009: Weight Emission Emission Pollutant Fraction of Factors Factors Source Gas(%) Uncontrolled Controlled lb/MMscf Ib/MMscf NOx Ob/MMBTU) --- 0.068 0.068 AP-42 (Ib/ CO(Ib/MMBTU) --- 0.37 0.37 AP-42 VOC 28.1 17,000 849.98 Gas Analysis Benzene 0.06 36.6896 1.8345 Gas Analysis Toluene 0.04 26.5022 1.3251 Gas Analysis Ethylbenzene 0.006 3.3616 0.1681 Gas Analysis Xylenes 0.01 7.8437 0.3922 Gas Analysis n-hexane 0.38 228.07 11.4035 Gas Analysis Emission factors for CO and NOx found in AP-42 Table 13.5-1. A HHV of 1,311 BTU/scf was used for calculations. AIRS ID: 123/9078 Page 19 of 23 olor epa en II ealth and Environment it Pollution Control Division Points 010,011,a Weight Emission Emission Factors Pollutant Fraction of Factors Controlled Source Gas(%) Uncontrolled Ib/MMscf Ib/MMscf NOx(Ib/MMBTU) -- 0.068 0.068 AP-42 CO (Ib/MMBTU) _ 0.37 0.37 AP-42 VOC 90.6 124,813 6,240.6 Gas Analysis Benzene 0.42 583.53 29.176 Gas Analysis Toluene 0.30 409.69 20.485 Gas Analysis Ethylbenzene 0.02 32.495 1.6248 Gas Analysis Xylenes 0.05 70.873 3.5437 Gas Analysis n-hexane 2.73 3,759.6 187.98 Gas Analysis Note: The uncontrolled VOC and HAP emissions were calculated using a gas sample collected 4/16/2014 of the gas vented from the low pressure separator at Pronghom 11-41-28HNB, 12-42- 28HNC, B-V28HNB 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 2,987 BTU/scf was used for calculations. Point 013: Weight Emission Emission Pollutant Fraction Factors Factors Source of Gas(%) Uncontrolled Controlled Ib/MMscf Ib/MMscf NOx(Ib/MMBTU) -- 0.068 0.068 AP-42 CO(lb/MMBTU) -- 0.37 0.37 AP-42 VOC 90.9 135,843 6,792.2 Gas Analysis Benzene 1.17 1,740.7 87.035 Gas Analysis Toluene 0.92 1,373.7 68.687 Gas Analysis Ethylbenzene 0.11 166.96 8.3479 Gas Analysis Xylenes 0.28 420.20 21.010 Gas Analysis n-hexane 7.03 10,505 525.27 Gas Analysis 2'2'4 0.49 738.43 36.921 Gas Analysis trimethylpentane 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 3,115 BTU/scf was used for calculations. Point 014: Emission Emission Factors- Factors- Uncontrolled Controlled Pollutant Ib/MMscf vented lb/MMscf vented Source NOx 0.068 0.068 AP-42 (Ib/MMBTU) AIRS ID: 12319C78 Page 20 of 23 olor. Depa en . P •li ealth and Environment t •it Pollution Control Division Factors- Factors- Uncontrolled Controlled Pollutant Ib/MMscf vented lb/MMscf vented Source CO 0.37 0.37 AP-42 (Ib/MMBTU) VOC 17,003 850.15 Gas Analysis Benzene 36.685 1.8342 Gas Analysis n-Hexane 228.07 11.404 Gas Analysis Toluene 26.499 1.3250 Gas Analysis Ethylbenzene 3.3616 0.1681 Gas Analysis Xylenes 7.8437 0.3922 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 1,311 BTU/scf was used for combustion calculations. Point 015: Emission Factors- Pollutant Uncontrolled Controlled Source lb/BBL loaded lb/BBL loaded VOC 0.3008 0.1008 AP-42 Benzene 0.0029 0.0010 AP-42 n-Hexane 0.0166 0.0056 AP-42 Toluene 0.0063 0.0021 AP-42 Ethylbenzene 0.0020 0.0007 AP-42 Xylenes 0.0058 0.0019 AP-42 2,2,4- 0.0024 0.0008 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= 1 (Submerged loading: dedicated vapor balance service) P(true vapor pressure)=4.61 psia M (vapor molecular weight)=65.3 lb/lb-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 016: Component Gas Heavy Oil Light Oil Water/Oil Connectors 2,313 0 954 0 Flanges 139 0 32 0 Open-ended Lines 77 0 8 0 Pump Seals 12 0 0 0 Valves 338 0 133 0 Other 162 0 24 0 AIRS ID: 123/9C78 Page 21 of 23 olo epa en li ealth and Environment it Pollution Control Division VOC Content(wt. 1 .9965 1 fraction) • Benzene Content(wt 0.000606 0 0.0096 0 fraction) Toluene Content(wt. 0.000438 0 0.0211 0 fraction) Ethylbenzene(wt. 0.000055 0 0.0066 0 fraction) Xylenes Content(wt. 0.000129 0 0.0191 0 fraction) n-hexane Content(wt. 0.00377 0 0.0551 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 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. 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 Requirement Operating Permit Synthetic Minor Source of: VOC, NOx, CO, and HAPs NANSR Synthetic Minor Source of: VOC, NOx 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/ AIRS ID: 12319C78 Page 22 of 23 il olor Depa en • P .Ii ` ealth and Environment •it Pollution Control Division Part 60: Standar. rfor° . e S ." •" . ourc 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 DOD 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.gov/pacific/cdphe/air-permit-self-certification AIRS ID: 123/9C78 Page 23 of 23 • Division Information Engineer: Carissa Money Control Engineer: NA Review Date: 12/23/2014 Application Date: 06/09/2014 Facility Identifiers Permit No. 14WE1084 AIRS County SS 123 Weld Facility 9078 Facility Type: exploration and production facility 0 Located in the 8-hour non-attainment area? 0 True Minor Q Synthetic Minor for: F VOC {✓NOx Rs CO Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: Pronghorn B-28 Production Facility Source Location: SWNW Section 28,Township 5N, Range 61W 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 'Requested Action Self Certification Required? Yes Issuance Number: 1 Source Description: Oil and gas exploration and production facility known as the Pronghorn B-28 Production Facility,located in the SWNW Section 28,Township 5N,Range 61W,Weld County,Colorado. Point Name Type Control Action 007 Condensate Condensate Tanks Flare New point Tanks 008 PW Tanks Water Tanks Flare New point 009 FL-2 Separator Venting Flare New point-emergency flare used when sales 010 Sep-1 Separator Venting Flare New point-low pressure separator routed to a 011 Sep-2 Separator Venting Flare New point-low pressure separator routed to a 012 Sep-3 Separator Venting Flare New point-low pressure separator routed to a 013 VRT-1 Separator Venting Flare New point-Vapor recovery tower routed to a fl 014 P-1 Pump Flare New point 015 Truck Loadout Flare New point Loadout 016 FUG Fugitives None New point *Points 001 -006 are engines covered by GP02 • 007 Eight(8)400 bbl above ground atmospheric condensate storage tanks controlled by three enc Requsted Throughput 262800 bbl Control Flare Efficiency 95.00961 • Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.4916 lb/bbl 64.6 tpy - 3.2 tpy Promax Benzene 0.0048 lb/bbl 1265 lb/yr 63 lb/yr Promax n-Hexane 0.0292 lb/bbl 7665 lb/yr 383 lb/yr Promax Toluene 0.0038 lb/bbl 1012 lb/yr 511b/yr Promax Ethylbenze 0.0005 lb/bbl 125 lb/yr 6 lb/yr Promax Xylenes 0.0012 lb/bbl 319 lb/yr 16 lb/yr Promax 2,2,4-TMP 0.0024 lb/bbl 632 lb/yr 32 lb/yr Promax Nox 0.068 lb/Mmbtu 0.1 tpy , 0.1 tpy AP-42 Table 1 CO 9.37 lb/Mmbtu 0.7 tpy 0.7 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. ulati n 2- r 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. Reaulation 6--New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. This source is not subject because each tank is less than 19,800 gallons(471 bbl) 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. R lati n fi—V nic Com " rids XII.VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS 14WE1084.CP1 123/9C78 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. 14WE1084.CP1 123/9C78 008 Two(2)400 bbl above ground produced water storage tank and one(1)60 bbl concr Emissions Calculations Requsted Throughput 146000 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.262 lb/bbl 19.1 tpy 1.0 tpy CDPHE Benzene 0.007 lb/bbl 1022 lb/yr 51 lb/yr CDPHE n-Hexane 0.022 lb/bbl 3212 lb/yr 161 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. lat'o 7—Volatile O nic Com' us XVII.C.1.b_ Applicant is subject since actual uncontrolled emissions are greater than 6 tpy. 14WE1084.CP1 123/9C78 One emergency flare with a minimum control efficiency of 95%. The flare is not enclosed.The emergency flare is used 009 during periods when the pipeline is not available or during emergencies. Equipment Description This source vents natural gas from: a well head separator when the sales gas pipeline is not available or during emergencies Emissions from this source are: routed to a flare INatural gas venting from a well head separator when the sales gas pipeline is not available or during emergencies.Emissions from this source are routed to 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/lb-mol)at 60F and 1 aim Throughput(0) 10 MMscf/yr 1141.552511 scf/hr MW 22.9 Ibnb-mot 0.02739726 MMscf/d mole% MW Ibwlbmol mass fraction lb/hr lb/yr tpy Helium 0.0100 4.0026 0.000 0.000 0.00 10.56 0.01 CO2 2.3800 44.01 1.047 0.046 3.15 27836.89 13.82 N2 0.9400 28.013 0.263 0.011 0.79 6947.82 3.47 methane 72.2320 18.041 11.587 0.506 34.90 305718.77 152.86 ethane 11.9095 30.083 3.580 0.156 10.78 94468.42 47.23 propane 8.0505 44.092 3.550 0.155 10.69 93657.69 46.83 isabutane 0.7430 58.118 0.432 0.019 1.30 11393.58 5.70 n-butane 2.3111 58.118 1.343 0.059 4.05 35439.71 17.72 isopentane 03941 72.114 0.284 0.012 0.86 7498.71 3.75 n-pentane 0.4825 72.114 0.348 0.015 1.05 9180.74 4.59 cydopentane 0.0375 70.13 0.026 0.001 0.08 693.90 0.35 n-Hexane 0.1003 88.18 0.086 0.0038 0.26 2280.70 1.14 cydohexane 0.0256 84.16 0.022 0.001 0.06 568.47 0.28 Other hexanes 0.1774 86.18 0.153 0.007 0.46 4033.88 2.02 heptanes 0.0887 100.21 0.089 0.004 027 2345.28 1.17 methylcyclohexane 00215 98.19 0.021 0.001 0.06 557.01 0.28 224-TMP 0.0001 114.23 0.000 0.00000 000 3.01 0.00 Benzene 0.0178 78.12 0.014 0.00061 0.04 366.90 0.18 Toluene 0.0109 92.15 0.010 0.00044 0.03 265.02 0.13 Ethylbenzene 0.0012 106.17 0.001 0.00006 0.00 33.62 0.02 Xylenes 0.0028 106.17 0.003 0.00013 0.01 76.44 0.04 08+Heavies 00532 114 0.061 0.00265 0.18 1600.21 0.80 VOC mass fret 0.281 Total VOC(Uncontrolled) 85.00 Notes Mole%,MW.and mass fractions are based on sales gas analysis collected 4/16/2014 from Pronghom 12-42-28 HNC Emissions are based on 8760 hours of operation per year. Typically I calculate the average MW of 08+based on the average MW on the analysis for the gas.This method resulted in slightly higher emissions Source used MW of 114 for 08+.Since there is minimal difference in emissions,I used the source's values. 14WE1o84.cv1 123/9078 Flaring Information Equipment Description Flare to combust produced gas when pipeline is available at this wellhead faoliy. MamAad seer TBD Model TBD Serial Number TBD Gas Heating Value 1311 Btu/scf Throughput 13110 MMBtu/yr VRU Information-NOT APPLICABLE Equipment Description Engine to recompress gas to sales One. Make Model Requested Control 100.00% Annual Bypass Tlrr 50.00% Backup Flare Overall Control 95.00% Combustion emission factor source: AP-42:Chili =r 13.5 0.07 Ilb NOX/MMBtu 0.37 )lb CO/MMBRTI Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 17000 lb/MMscf 849.98 lb/MMscf 85.0 tpy 4.2 tpy Gas Analysis Nrn 0.07 lb/MMBTU 0.07 lb/MMBTU 0.4 tpy 0.4 tpy AP-42 CO 0.37 lb/MMBTU 0.37 lb/MMBTU 2.4 tpy 2.4 tpy AP-42 Benzene 36.8898 lb/MMscf 1.8345 lb/MMscf 367 lb/yr 18 lb/yr Gas Analysis n-Hexane 228.0700 lb/MMscf 11.4035 lb/MMscf 2281 lb/yr 114 lb/yr Gas Analysis Toluene 28.5022 lb/MMscf 1.3251 lb/MMscf 265 lb/yr 13 lb/yr Gas Analysis Xylenes 7.8437 ib/MMscf 0.3922 lb/MMscf 78 lb/yr 4 lb/yr Gas Analysis Ethylbenzene 3.3618 lb/MMscf O.1681 lb/MMscf 34 lb/yr 2 lb/yr Gas Analysis Regulatory Applicability • AOCC Regulation 1 This source is subject to the opacity requirements for flares in Section IIA.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 al emission sources."Na person.wherever located,shall cause or allow the emission of odorous air contaminants from any single source suds as to result in detectable odors whirls am measured in excess of the following Omits: 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." 14WE1084.CP1 123/9078 One low-pressure separator controlled by three enclosed flares during VRU downtime.Each flare has a minimum 010 control 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 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 scf/lb-mol)at 60F and 1 atm Throughput(O) 0.88 MMsof/yr 100.128125 scf/hr MW 52.2 Ib/Ib-mol 0.002403075 MMscf/d mole% MW Ibx/1bmol mass fraction lb/hr lb/yr tpy Helium 0.00 4.0028 0.000 0.000 O00 000 0.00 CO2 0.12 44.01 0.317 0O06 0.08 733.34 0.37 N2 0.04 28,013 0.011 0.000 000 25.93 0.01 methane 4.11 16,041 0,660 0.013 0.17 152]42 0.76 ethane 12.98 30,063 3.902 0.075 1.03 9030.91 4.52 propane 33.98 44.092 14.984 0.287 3.96 34676.57 17.34 isobutane 5.77 58.118 3.356 0.064 0.89 7767.14 3.88 n-butane 22.18 58.118 12.892 0.247 3.41 29836.91 14,92 isopentane 5.07 72.114 3.654 0.070 0.97 8455.68 4,23 n-pentane 6.62 72.114 4.774 0.091 1.26 11049.21 5,52 cyclopentane 0.58 70.13 0.406 0.008 0.11 93941 0.47 n-Hexane 1.65 86.18 1.425 0.0273 0.38 3297.66 1.65 cydohexane 044 84.16 0.369 0.007 0.10 85447 0.43 Other hexanes 2.83 86.18 2.440 0.047 0.64 5646.74 2.82 hectares 1.54 100.21 1.543 0.030 0.41 3670.36 1,79 methylcyclohexane 0.37 98.19 0.364 0007 0.10 843.52 042 224-TMP 0,00 114.23 0.001 0.000 0.00 1.59 0.00 Benzene 0.28 78.12 0.221 0.0042 0.06 511.83 0.26 Toluene 0.17 92.15 0.155 00030 0.04 359.35 0.18 EBrylbenzene 0.01 108.17 0.012 0,0002 0.00 28.50 0.01 XNenes 0.03 106.17 0.027 0.0005 0.01 62.16 0.03 O3+Heavies 0.59 116 0.680 0.0130 0.18 1574.78 0.79 VOC mass frac 0.906 Total VOC(Uncontrolled) 54,74 Notes Mole%.MW,and mass fractions are based on LP separator gas analysis collected 4/16/2014 from Pronghorn 11-41-28HNB,12-42-28HNC,B-V28HNB. Flowrate is based on Promax results.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. 14WE1084.CP1 123/9O8 Flaring Information Equipment Description Flare to combust low-pressure separator gas when the VRU is down. Manufacturer Lead Model L30-00101 Serial Number 21615,21464,21735 Gas Heating Value 2987 Befsd Throughput 2619.964534 MMBN/yr VRU Information Equipment Description Engine to decompress tow-pressure se rotor gas to sales Ine.The VRU is considered part of the process and not included as an air pollution control devio • Make Cummins and GM Model GM Vortec,5.7 L Requested Control 100.00% Annual Bypass T 15.00% Backup Flare Overall Control 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.07 I6 NOX/MMBtu 0.37 Ilb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Facty Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 124813 lb/MMscf 6240.6 lb/MMscf 54.7 tpy 2.7 tpy Gas Analysis Nos 0.07 lb/MMBTU 0.07 lb/MMBTU 0.1 spy 0.1 spy AP-42 CO 0.37 Ib/MMBTU 0.37 lb/MMBTU 0.5 tpy 0.5 spy AP-42 Benzene 583.53 lb/MMscf 29.176 lb/MMscf 512 lb/yr 26 lb/yr Gas Analysis n-Hexane 3759.63 lb/MMscf 187.98 lb/MMscf 3298 lb/yr 165 lb/yr Gas Analysis Toluene 408.69 tb/MMscf 20.485 lb/MMscf 359 lb/yr 18 lb/yr Gas Analysis Xylenes 70.873 lb/MMscf 3.5437 lb/MMsef 62 lb/yr 3 lb/yr Gas Analysis Ethylbenzene 32.4951b/MMscf 1.6248 lb/MMscf 29 lb/yr 1 lb/yr Gas Analysis Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for Gams in Section IIA5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shal alow or cause emissions into the atmosphere of any air polutant which is in excess of 30%opacity.' AQCC Regulation 2 Section IA apples to all emission solaces.`No person,wherever bleated shal cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors whidi are measured In excess of the following (mils: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been dluted with seven(7)or mobs volumes of odor free air." 14WE1084.CP1 123/9C78 One low-pressure separator controlled by three enclosed flares during VRU downtime.Each flare has a minimum 011 control 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 Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=0'MW*Xx/C Ex=emissions of pollutant z 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 sef/lb-mot)at 60F and 1 atm Throughput(0) 0.88 MMscf/yr 100.128125 sct/hr MW 52.2 lb/b-mot 0.002403075 MMscf/d mole% MW Ibx/Ibmol mass fraction !Mr lb/yr tpY Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 0.72 44.01 0.317 0.006 0.08 733.34 0.37 N2 004 28.013 0.011 0.000 0.00 25.93 0.01 methane 4.11 16.041 0.660 0.013 0.17 1527.42 0.76 ethane 12.98 30.063 3.902 0.075 1.03 9030.91 4.52 propane 33.98 44.092 14.984 0.287 3.96 34876.57 17.34 isobutane 5.77 58.118 3.356 0.064 0.89 7767.14 3.88 n-butane 22.18 58.118 12.892 0.247, 3.41 29836.91 14.92 isopentane 5.07 72.114 3.654 0.070 0.97 8455.68 4.23 n-pentane 6.62 72.114 4.774 0.091 1.26 11049.21 5.52 cydopentane 0.58 70.13 0.406 0.008 0.11 939.41 0.47 n-Hexane 1.65 86.18 1.425 0.027 0.38 3297.66 1.65 cydohexane 0.44 84.16 0.369 0.007 0.10 854.47 0.43 Other hexanes 2.83 86.18 2.440 0.047 0.64 5646.74 2.82 heptanes 1.54 100.21 1.543 0.030 0.41 3570.36 1.79 medwlcyclohexane 0.37 98.19 0.364 0.007 0.10 843.52 0.42 224-TMP 0.00 114.23 0.001 0.000 0.00 1.59 0.00 Benzene 0.28 78.12 0.221 0.004 0.05 511.83 0.26 Toluene 0.17 92.15 0.155 0.003 0.04 359.35 0.18 EBrylbenzene 0.01 106.17 0.012 0.000 0.00 28.50 0.01 Xylenes 0.03 106.17 0.027 0.001 0.01 62.16 0.03 08+Heavies 059 116 0.680 0.013 0.18 1574.78 0.79 VOC mass frac 0.906 Total VOC(Uncontrolled) 54.74 Notes Mole%,MW.and mass fractions are based on LP separator gas analysis collected 4/16/2014 from Pronghorn 11-41-28HNB,12-42-28HNC,B-V28HNB. Flowrate is based on Promax results.Emissions are based on 8760 hours of operation per year. Typically t calculate the average MW of 08+based on the average MW an 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. • 14WE1084.CP1 123/9078 Flaring Information Equipment Description Flare to combust key-pressure separator gas when the VRU is down. Manufacturer Lead' Model 130-0010 Serial Number 21615,21464,21735 Gas Heating Value 2987IBu✓acf Throughput 2619.964534 MMBIWyr VRU Information Equipment Description Engine to recompress low-pressure separator gas to sales Ina.The VRU is considered part of the process and not included as an air polution control deyio Make Cummins and GM Model GM Vodec,5.7 L Requested Control 100.00% Annual Bypass Ti 15.00% Backup Flare Overal Control 95.00% Combustion emission factor source: AP-42:Char 13.5 0.07 Ito NOX/MMBtu 0.37 jib CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 124813 lb/MMscf 6240.63 lb/MMscf 54.7 tpy 2.7 IP/ Gas Analysis Nos 0.0716/MMBTU 0.07 Ib/MMB7U 0.1 tpy 0.1 tpy AP-42 CO 0.37 Ib/MMBTU 0.37 lb/MMBIU 0.5•tpy 0.5 tpy AP-42 Benzene 5133.53 lb/MMscf 29.17651b/MMscf 512 lb/yr 26 lb/yr Gas Analysis n-Hexane 3759.63 lb/MMscf 187.9815 lb/MMscf 3298 lb/yr 16S lb/yr Gas Analysis Toluene 409.89 lb/MMscf 20.4845 lb/MMsct 359 lb/yr 18 lb/yr Gas Analysis Xyienes 70.873 lb/MMscf 3.5437 lb/MMsct 62 lb/yr 3 lb/yr Gas Analysis Ethylbenzene 32.495 lb/MMSA 1.6248 lb/MMscf 29 lb/yr 1 lb/yr Gas Analysis Regulatory ApplIcabllity AOCC Regulation 1 This source Is subject to the opacity requirements for flares in Section IIA.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shal allow or cause emissions into the atmosphere of any air polutant which is in excess of 30%opacity? AOCC Regulation 2 Section IA apples to al emission sources.No person,wherever located.shal 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.* • • • 14WE1084.CP1 123/908 One low-pressure separator controlled by three enclosed flares during VRU downtime-Each flare has a minimum 012 control 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 pas 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/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 scf/Ib-mol)at 60F and 1 atm Throughput(0) 0.88 MMscf/yr 100.128125 scf/hr MW 52.2 Ib/lb-mol 0.002403075 MMscf/d mole% MW Ibx/Ibmol mass fraction .lb/hr lb/yr tpy Helium 0.00 4.0026 0.000 0.000. 0.00 0.00 0.00 CO2 0.72 44.01 0.317 0.006 0.08 733.34 0.37 N2 0.04 28.013 0.011 0.000 0.00 25.93 0.01 methane 4.11 16.041 0.660 0.013 0.17 1527.42 0.76 _ ethane 12.98 30.063 3.902 0.075 1.03 9030.91 4.52 propane 33.98 44.092 14.984 0.287 3.98 34676.57 17.34 isobutane 5.77 58.118 3.356 0.064 0.89 7767.14 3.88 n-butane 22.18 58.118 12.892 0.247 3.41 29836.91 14.92 isopentane 5.07 72.114 3.654 0.070 0.97 8455.68 4.23 n-pentane 6.62 72.114 4.774 0.091 1.28 11049.21 5.52 cydopentane 0.58 70.13 0.406 0.008 0.11 939.41 0.47 n-Hexane 1.65 86.18 1.425 0.027 0.38 3297.66 1.65 cydohexane 0.44 84.16 0.369 0.007 0.10 854.47 0.43 Other hexanes 2.83 86.18 2.440 0.047 0.64 5648.74 2.82 heptanes 1.54 100.21 1.543 0.030 0.41 3570.36 1.79 methylcyclohexane 0.37 98.19 0.364 0.007 0.10 843.52 0.42 224-TMP 0.00 114.23 0.001 0.000 0.00 1.59 0.00 Benzene 0.28 78.12 0.221 0004 0.06 511.83 0.26 Toluene 0.17 92.15 0.155 0.003 0.04 359.35 0.18 EBrylbenzene 0.01 106.17 0.012 0.000 0.00 28.50 0.01 Xylenes 0.03 106.17 0.027 0.001 0.01 62.16 0.03 08+Heavies 0.59 116 0.680 0.013 0.18 1574.78 0.79 VOC mass frac 0.906 Total VOC(Uncontrolled) 54.74 Notes Mole%.MW,and mass fractions are based on LP separator gas analysis collected 4/16/2014 from Pronghorn 11-41-28HNB,12-42-28HNC,B-V28HNB. Flowrate is based on Promax results.Emissions are based on 8760 hours of operation per year. Typically I calculate the average MW of 06+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. 14WE1084.091 123/908 Flaring Information Equipment Desolation Flare to combust km-pressure separator gas when the VRU is doom. Manufacturer Lead l Model L30-0010 Serial Number 21615,21464,21735 Gas Heating Value 2967 Btu/scf Throughput 2619.964534r MMBIWyr VRU Information Equipment Description Engine to recompress bar-presstre se rotor gas to sales Ina.The VRU is considered part of the process and not included as an air pollution control devio Make Cummins end GM Model GM Vartec,5.7 L Requested Control 100.00% Annual Bypass Ti 15.00% Backup Flare Overall Control 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.07 lib NOXtMMBtu 0.37 lb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source V0C 124813 lb/MMscf 6240.63 lb/MMscf 54.7 spy 2.7 tpy Gas Analysis Max 0.07 lb/MMBTU 0.07 lb/MMBTU Ql tpy 0.1 spy AP-42 CO 0.37 lb/MMBTU .0.37 lb/MMBTU 0.5 spy 0.5 tpy AP-42 Benzene 583.53 lb/MMscf 29.1765 lb/MMscf 512 lb/yr 26 lb/yr Gas Analysis n-Hexane 3759.63 lb/MMscf 187.9815 lb/MMscf 3298 lb/yr - 165 lb/yr Gas Analysis Toluene 409.69 lb/MMscf 20.4845 lb/MMscf 359 lb/yr la lb/yr Gas Analysis Xylenes 70.873 lb/MMscf 3.5437 lb/MMscf 62 lb/yr 3 lb/yr Gas Analysis Ethylbenzene 32.495 lb/MMscf 1.6248 lb/MMscf 29 lb/yr 1 lb/yr Gas Analysis Regulatory Applicability AOCC Regulation This source is subject to the opacity requirements for flame in Section IIA.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall aloes or cause emissions into the atmosphere of any air polutant which is in excess of 30%opacity.' AOCC Peculation 2 Section LA 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 resuk In detectable odors which are meastred in excess of the following limits: For areas used predominantly for residential or commercial ptaposes it is a violation if odors are detected after the odorous air has been aided with seven(7)or more volumes of odor free air? • 14WE1084.CP1 123/9[78 One vapor recovery tower(VRT)controlled by three enctosed flares during VRU downtime.Each flare has a minimum 013 control efficiency of 95%. Equipment Description This source vents natural gas from: a vapor recovery tower when the VRU is down Emissions from this source are: routed to a flare 'Natural 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 Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=CI•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 scf/Ib-mol)at 60F and 1 atm Throughput(0) 3.10 MMscf/yr. 354 4225 sct/hr MW 56.6 Ib/lb-mol 0.00850614 MMscf/d mole% MW Ibwtbmol mass fraction lb/hr lb/yr toy Helium 0.01 4.0026 0.000 0.000 0.00 3.28 0.00 CO2 1.10 44.01 0.486 0.009 0.45 3980.54 1.99 _ N2 0.01 28.013 0.003 0.000 0.00 25.27 0.01 methane 5.73 16.041 0.919 0.016 0.86 7527.61 3.76 ethane 12.27 30.063 3.689 0.065 3.45 30218.31 15.11 propane 27.00 44.092 11.905 0.210 11.13 97523.60 48.76 isobutane 4.13 58.118 2.397 0.042 2.24 19839.49 9.82 n-butane 14.93 58.118 8.679 0.153 8.12 71094.84 35.55 isopentane 3.23 72.114 2.330 0.041 2.18 19088.40 9.54 n-pentane 4.13 72.114 2.978 0.053 2.78 24392.65 1220 cydopentane 1.81 70.13 1.271 0.022 1.19 10408.96 5.20 n-Hexane 4.62 86.18 3.982 0.0703 3.72 32618.30 16.31 cydohexane 1.50 84.16 1.286 0.022 1.18 10367.83 5.18 Other hexanes 9.23 86.18 7.954 0.141 744 65161.08 32.58 heptanes 361 100.21 3.620 0.064 3.39 29655.90 14.83 metylcyclohexane 1.18 98.19 1.159 0.020 108 9493.44 4.75 224-TMP 0.25 114.23 0.280 0.00494 0.26 2292.62 1.15 Benzene 0.84 78.12 0.660 0.01166 0.62 540441 2.70 Toluene 0.57 92.15 0.521 0.00920 0.49 4265.11 2.13 Elhylbenzene 0.06 106.17 0.063 0.00112 0.06 518.36 0.26 Xylenes 0.15 106.17 0.159 0.002814 0.15 1304.61 0.65 C8+Heavies 1.95 116 2.262 0.040 2.12 18530.14 9.27 VOC mass frac 0.9096 Total VOC(Uncontrolled) 210.88 Notes Mole%,MW,and mass fractions are based on Promax results for the VRT stream Flowrate is based on Promax results.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. 14WE1084.CP1 123/9078 • Flaring Information Equipment Description Flare to combust VRT gas when be VRU is down. Manufacturer Lead' Model L30-0010 Serial Number 21615,21484,21735 Gas Heating Value 3115 Btu/sc Throughput 9671288527 MMBtu/yr VRU Information Equipment Description Engine to racompress low-pressure separator gas to sales lee.The VRU is considered part of the process and not Included as an air pollution control devlo Make Cummins and GM Model GM Vortec,5.7 L Requested Control 100.00% Annual Bypass Ti 15.00% Backup Flare Overall Control 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.07 IIb NOX/MMBtu 0.37 Ilb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 135843 lb/MMscf 6792.2 lb/MMscf 210.9 tpy 10.5 tpy Gas Analysis Nox 0.071b/MMBTU 0.071b/MMBTU 0.3 spy 03 tpy AP-42 CO 0.371b/MMBTU 0.371b/MMBTU 1.8 tpy La tpy AP-42 Benzene 1740.7 lb/MMscf 87.0351b/MMscf 5404 lb/yr 270 lb/yr Gas Analysis n-Hexane 10505.3 ib/MMscf 525.27 lb/MMscf 32616 lb/yr 1631 lb/yr Gas Analysis Toluene 1373.7 lb/MMscf 68.687 lb/MMscf 4265 lb/yr 213 lb/yr Gas Analysis Xylenes 42020 lb/MMscf 21.0101b/MMscf 1305 lb/yr 65 lb/yr Gas Analysis Ethylbenzene 166.96 lb/MMscf 8.3479 lb/MMscf 518 lb/yr 26 lb/yr Gas Analysis 2,2,4-TMP 738.43 lb/MMscf • 36.921 lb/MMscf 2293 lb/yr 113 lb/yr Gas Analysis Regulatory Applicability AOCC Reoulatlon 1 This source is subject to the opacity requirements for flares in Section IIA.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 Reoulatkm 2 Section LA applies to all emission sources.'No person,wherever located,shal cause or allow the emission of odorous ai contaminant from any single source such as to result in detectable odors which are measured in excess of the following knits: For areas used predominantly for residential or commercial purposes it is a violation if odors we detected after the odorous air has been(Muted with seven(7)or more volumes of odor free air.' 14WE1084.CP1 123/9C78 One(1)pneumatic water transfer pump,rated at 600 scf/hr(Sandpiper, Model G1 F,Serial number 2091566).The pneumatic pump is controlled by 014 three enclosed flares.Each flare has a minimum control efficiency of 95%. Pump Information Manufactur Sandpiper Model Number:G1F Serial Pump Number:2091566 Information Pump capacity 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/Ib-mol)at 60F and 1 atm Q 600 scf/hr MW 22.9 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 2.38 44 0.0457 CO2 1.658 14522.647 7.261 nitrogen o.94 28 0.0115 nitrogen 0.417 3650.077 1.825 methane 7223204 16.04 0.5059 methane 18.342 160675.770 80.338 ethane 11.9095 30.07 0.1564 ethane 5.669 49664.161 24.832 propane 8.0505 44.09 0.1550 propane 5.619 49224.249 24.612 isobutane 0.743 58.12 0.0189 isobutane 0.684 5988.673 2.994 n-butane 2.3111 58.12 0.0587 n-butane 2.126 18627.754 9.314 isopentane 03941 72.15 0.0124 isopentane 0.450 3943.292 1.972 n-pentane 04825 72.15 0.0152 n-pentane 0.551 4827.806 2.414 cyclopentane 0.0375 70.15 0.0011 cyclopentane 0.042 364.817 0.182 n-hexane 0.1003 86.18 0.0038 n-hexane 0.137 1198.736 0.599 cyclohexane 0.0256 84.18 0.0009 cyclohexane 0.034 298.858 0.149 Other hexanes 0.1774 86.18 0.0067 Other hexane 0.242 2120.197 1.060 heptanes 00887 100.21 0.0039 heptanes 0.141 1232.681 0.616 methylcyclohexa 0.0215 98.19 0.0009 methylcyclohi 0.033 292.767 0.146 224-TMP 0.0001 114.22 0.0000 224-TMP 0.000 1.584 0.001 Benzene 00178 78.11 0.0006 Benzene 0.022 192.816 0.096 Toluene 0.0109 92.14 0.0004 Toluene 0.016 139.281 0.070 Ethylbenzene 00012 106.17 0.0001 Ethylbenzene 0.002 17.668 0.009 Xylenes 0.0028 106.17 0.0001 Xylenes 0.005 41.226 0.021 C8+Heavies 00532 116 0.0027 C8+Heavies 0.098 855.827 0.428 Mass Fraction VOC: 0.2814 Total VOC 44.684 Heating Value I 1311 BTU/scf Combustion emission factor source: AP-42:Chapter 13.5 14WE1084.CP1 123/9C78 0.07 b NOXIMMBW 0.37 lb COA4MBtu Nan Mole%,MW,and mass fractions are based on sales gas analysis collected 4/16/2014 from Pronghom 12-42-28HNC Source used MW of 116 for C8+. Emissions Summary Table Pollutant Uncontrolled Emission Fa Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 17003 lb/MMscf 850.15 lb/MMscf 44.7 tpy 2.2 tpy Gas Analysis Nox 0.07 lb/MMBTU 0.07 lb/MMBTU 0.2 tpy 0.2 tpy AP-42 CO 0.37 lb/MMBTU 0.37 Ib/MMBTU 1.3 tpy 1.3 tpy AP-42 Benzene 36.685 lb/MMscf 1.8342 lb/MMscf 193 lb/yr 10 lb/N Gas Analysis n-Hexane 228.070 lb/MMscf 11.4035 lb/MMscf 1199 lb/yr 60 lb/yr Gas Analysis Toluene 26.499 lb/MMscf 1.3250 lb/MMscf 139 lb/yr 7 lb/yr Gas Analysis Xylenes 7.8437 lb/MMscf 0.3922 lb/MMscf 41 lb/yr 2 lb/yr Gas Analysis Ethylbenzene 3.3616 lb/MMscf 0.1681 lb/MMscf 18 lb/yr 1 lb/yr Gas Analysis 14WE1084.CP1 123/9078 015 Truck Condensate Loadout that is controlled by using dedicated vapor balance service and three 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 1 AP-42 P True Vapor Pressure 4.61 psia Sales Oil Analysis documenting RVP 6.7 and AP M Molecular Weight of Va 65.3 lb/lb-mole Sales oil analysis for RVP 6.7 and interpolating v T Liquid Temperature 523.67 deg. R EPA Tanks Met Data for Denver, CO L 7.16 lb/10^3 gal 3.01E-01 lb/bbl Annual requested Throughput 262800 BBL/yr 11037600 gal/yr Annual requested VOC emissions 79059 lb/yr 39.53 tpy Control: Flare Efficiency: 66.50% Source assumes 95%control efficiency and 70%collection efficiency NCRPs Component Mass Fraction Benzene 0.0096 n-hexane 0.0552 Toluene 0.0211 Ethylbenzen 0.0066 Xylenes 0.0191 2,2,4-TMP 0.0079 Source: Pressurized oil analysis Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.3008 lb/bbl 39.5 tpy 13.2 tpy AP-42 Benzene 0.0029 lb/bbl 757 lb/yr 254 lb/yr AP-42 n-Hexane 0.0166 lb/bbl 4360 lb/yr 1461 lb/yr AP-42 Toluene 0.0063 lb/bbl 1668 lb/yr 559 lb/yr AP-42 Ethylbenzen 0.0020 lb/bbl 522 lb/yr 175 lb/yr AP-42 Xylenes 0.0058 lb/bbl 1512 lb/yr 506 lb/yr AP-42 2,2,4-TMP 0.0024 lb/bbl 623 lb/yr 209 lb/yr AP-43 Regulatory Review 'Regulation 7-Volatile Organic Compounds 14WE1084.CP1 123/9C78 This facility is not considered a bulk plant(in Reg.7)because it does not distribute gasoline. 14WE1084.CP1 - 123/9C78 016 Fugitive equipment leaks Regulatlan 7 Intonation Operating Hours: 6760 hours/year Emission Factor Source Standard EFs-EPA-453/R-95-017 Table 2-4 Control Efficiency Source: None Calculations Emission Factor(kg/hr- Emission Service Component Type Count reel Control(%)Pollutant Mass Fraction Boy) Table 2.4 Table 2-0 Reg.3 Connectors 2313 2.WE04 1.00E-05 0.0% VOC 02611 98910653 Flanges 139 3.90E04 5.70E06 0.0% Benzene 0000606 0.0213383 Open-Ended Lines 17 2,00E-03 1.50E-05 0.0% Toluene 0.000438 0.0154213 Gas Pump Seals 12 240E-03 350E-0f 0 EthM»ozone 0.000055 0.0019365 Valves 335 4.50E-01 2.50E-05 0 Xylenes 0.000129 0.0045416 Other 162 8.&IE-03 1.20E-04 0.0% n-Hexane 000317 0.1321355 Connectors 0 7.50E06 7.50E06 0.0% VOC 1 0 Flanges 0 3.90E-0I 3.90E-01 0.0% Benzene 0 Open-Ended Lines 0 1.40E-04 120E-06 0.0% Toluene 0 Heavy Oil Pump Seals 0 000E+00 000E+00 0 ENNtienzene 0 Valves O 840E-06 8.40E-05 0.0% Xylenes 0 Other 0 3.20E-05 3.20E-05 0 n-Hexane 0 Connectors 954 2.10E-04 7.50E-05 0.0% VOC 09965 2000035 Flanges 32 1.10E-04 2.40E06 0 Benzene 0.0096 0.0614441 Open-Ended Lines 8 1.40E-03 1.40E-05 0 Toluene 00211 0.1482365 Light Oil Pump Seale 0 1.30E-02 510E-04 0 Elbylbenzene 0.0066 0.0463678 Valves 133 2.50E-03 190E-05 0 Xylenes 0.0191 0.1341851 Other 24 1.50E-03 1.10E-04 0.0% n-Hexane 00551 0362101 Connectors 1.10E-04 1.00E-05 0.0% VOC 1 0 Flanges 2.90E-06 290E-06 0 Benzene 0 Open-Ended Linea 2.50E-04 3.50E-06 00% Toluene 0 WaWrl011 Pump Seals 2.40E-05 240E-05 0 Elho4benzene 0 Valves 980E-05 9.20E-06 0.0% Xylenes 0 Other 1.40E-02 5.90E 05 0.0% n-Hexane 0 Emissions Summary Table Pollutant Uncontrolled Emissions Controlled Emissions Souse tpy VOC 16.9 rev 16.9 Wv Standard EFs-EPA-453/R-65O11 Table 2-4 Benzene 178 Ibbr 175 lb/yr Standard EFs-EPA-453/R-05011 Table 2-4 009 Toluene 327 lb/yr 321 lb/yr standard EFs-EPA453/R-9501I Table 2-4 016 Ethybommne 97 lb/yr 911bM Standard EFs-EPA453/R-9501I Table 24 005 Xylenes 211 lb/yr 211 Iblyr Standard EFs-EPA-453/R-95-017 Table 24 0.14 n-Hexane 1040 lb/yr 1040 lblyr Standard EFs-EPA453/R-95011 Table 2-4 0.52 Regulatory ApplIcability The date of interest for determining whether the source is new Sr modified is therefore November 20.2007(the date of Reg.3 the 8-hour ozone NA area designation).Sine the site was built after the date above(operation began 3/10/2014),this source is considered"new or modified'Operator has agreed on the Division's standard conditions. VOC and HAP concentrations for gas service am based on sales gas sample collected 4/16/2014 from Pronghorn 12- 42-28HNC.Since site-specific and within 1 year of application dale,no initial sampling required. 14WE1091CP1 123/9(78 AIRS(County/Plant)uncle Permit No.14WE1084 Date 12/232014 Controlled Controlled Actual Requested NCRP= Uncontrolled Emission Emissions Emissions CM. evadable Point 4 SCC Pollutant or CAS Facto. Eminent Fedor Source (tpyp (VW PTE(ipyr Efl% 7 VOC 11.704 lb/1000 gaib Prams 2.7 3.2 64.6 95% Yes NOx 0.068 bMmbtu AP-42 Table 13.5 0.1 0.1 0% No CO 0.37 b/Mmbtu AP-42 Table 13.5 0.7 0.7 0% No • 2,2,4-birne091aentene 0.057 Is/1000 gala Promo 13 32 832 95%:Yes 007 40400311 Benzene 0.115 lb/1000 gala Pmmex 53 83 1265 95% Yes n-Hexane 0.695 lb/1000 gaol Pmmax 319 383 7665 95% Yes Toluene 0.092 b1000galoPromax 42 51 1012 95% Yes E6Mbenzene 0.012 lb/1000 ggaeIIlIo(qPromos 5 6 125 95% No %Hanes 0.029 lb/1003 13 16 319 95% Mesa VOC ' 6.238 lb/1000 gala CDPHE 1 19.1 95% Yes 008 40400315 Beene 0.167 lb/1000 gala CDPHE 51 1022 95% Yes n-Hexane 0.524 Ml0009SIIgCDPHE 161 3212 95% Yes VOC 170001NMMed bee Mayas 0.2 85 95% Yes NOx 0.068 IIMMBTU AP-42 0.4 0.4 0% No CO 0.37 bMMBIU AP-42 2.4 2.4 0% Yes 009 31000205 Benzene 36.69 IbMMsot Gas Mayas 18 367 95% Yes n-Hexane 228.07 IbMMsd Gas Marti 110 2281 95% Yes Toluene 26.502 lb/MMed Gas Mayas 13 265 95% Yea EBgbenzene 3.362 lb/MMsof Gas Analysis 2 34 95% No XMenes 7.8441hMMed We Mah/si 4 78 95% No VOC 124813 bMMsd Gas Analysis 2.7 54.7 95% Yes NOx 0.088 bMMBTU AP-42 0.1 0.1 0% No CO 0.37 EMMBTU AP-02 0.5 0.5 0% No 010• 31000205 Benzene 583.53 lb/Miler, AnalysisGasAnalysis - 26 512 95% Yes n-Hexane 3759.8 NMMad Gas Melyss 165 3298 95% Yee Toluene 409.69 bMMad Gas Mayas 18 359 95% Yes Eu'/lbOmene 32.495 WMsct Gas Mayas 1 29 95% No =es 70.8731bMMed Gas Analysis 3 62 95% No VAC 120813 IMAMsd Gas Mayas 2.7 54.7 95% Yes NOx 0 lb/MMB111 AP-42 0.1 0.1 0% No CO 0 Ib1iMBTU AP42 0.5 0.5 0% No 011 31000205 Benzene 583.53 ItalMed Gas Analysis 26 512 95% Yee n-Hexane 3759.8 lb/MMsd Gas Mays 165 3298 95% Yes Toluene 409.69 lb/HM=1 Ges Analysis 18 359 95% Yee EMybnzene 32095 lb/MMsd Gas MaIyai 1 29 95% No %Hanes 70.873 IMAMed Gas Mayas 3 62 95% No AIRS(County/Plant)123/9C78 Permit No.14WE1084 Date 12/23/2014 Controlled Controlled Actual Requested NCRP9 Uncontrolled Emission Emissions Emissions Cld. reportable Point# SCC Pollutant or CAS Factor Emisison Factor Source (IOW* CPO* PTE(toy)* Elf% ? VOL 124813 lb/MMscf Gas Analysis 2.7 54.7 95% Yes NEW 0107MMBTU AP-42 0.1 0.1 0% No CO 01WMMBTU AP-42 0.5 0.5 0% No Benzene 583.53 lb/MMscf Gas Analysis 26 512 95% Yes 12 31000205 n-Hexane 3759.6 lb/MMscf Gas Analysis 165 3298 95% Yes Toluene 409.69 IWMMscf Gas Analysis 18 359 95% Yes Etbylbenzene 32.495 IWMMsd Gas Analysis 1 29 95% No Xylenes 70.873 lb/MMscf Gas Analysis 3 82 95% No VOC 1358431WMMscf Gas Analysis 10.5 210.9 95% Yes NOx 0068 IWMMBTU AP-42 0.3 0.3 0% No CO 0.37 Ib5MMBTU AP-42 1.8 1.8 0% Yea Benzene 1740.7 lb/MMscf Gas Analysis 270 5404 95% Yes 13 31000205 n-Hexane 10505 lb/MMscf Gas Analysis 1631 32616 95% Yes Toluene 1373.74 lb/MMscf Gas Analysis 213 4265 95% Yes Ethylbenzene 166.9591WMMsd Gas Analysis 26 518 95% Yes Xylenes 420.198 lb/MMscf Gas Analysis 65 1305 95% Yes 12,4-Mmetbyl entane 738.426 lb/MMscf Gas Analysis 115 _ 2293 95% Yes VOC 17005Ib/MMsd Gas Analysis 2.2 447 95% Yes NOx 0.068 lb/MMEITU AP-42 0.2 0.2 0% No CO 0.37 lb/MMBTU AP-42 1.3 13 0% Yes Benzene 36.6851WMMscf Gas Analysis 10 193 95% No 14 31000299 n-Hexane 228.07 lb/MMscf Gas Analysis 60 1199 95% Yes Toluene 26.499 lb/MMscf Gas Analysis 7 139 95% No Etbylbenzene 3.362 lb/MMscf Gas Analyse 1 18 95% No Xylenes 7.844 lb/MMscf Gas Analysis 2 41 95% No VOC 7.1627 lb/1000 gallo AP-42 13.2 395 67% Yes Benzene 00686 lb/1000 gallo AP-42 254 757 67% Yes p-Hexane 0.3950 lb/1000 gall°,AP-42 1461 4360 66% Yea 15 40600132 Toluene 0.1511 lb/1000 gallo AP-42 559 1668 66% Yes Elhylbenzene 0.0473 lb/1000 gall AP-42 175 522 67% Yes Xylenes OA 370 lb/1000 gallo AP-42 507 1512 66% Yes 2,2.4-Idmethybentxne 0.0564 lb/1000 gallo AP-42 209 623 66% Yes VOC Standard EFs-EPA-453/R-95-017 Table 2-4 169 16.9 0 Yes Benzene Standard EFs-EPA-453/R-95-017 Table 2-4 178 178 0 No n-Hexane Standard EFs-EPA-453/R-95-017 Table 2-4 1040 1040 0 Yes 16 31007220 Toluene Standard EFs-EPA-453/R-95-017 Table 2-4 327 327 0 Yes Etbylbenzene Standard EFs-EPA-453/R-95-017 Table 2-4 97 97 0 No MRS(CounlyiPlant)123/9C78 Pam*No.14WE1084 Date 12/23/2014 lAcCMWIle! Controlled a Requested NCRP= Uncontrolled Emission Emirates Embebna 9CU 1 Point# SCC Po4lenl or CRS Factor EnYebm Factor Source OPyr (tpyrEI%PTE reportable Xylas I I Sbaidaid EFa-EPA-453/R-95-017 Table 2.4 277 277 0 Yes 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) i. ‘t##'.9 AIRS ID#': I23/9C78/CO-3 O APEN update only° t� t), ® New or previously unreported battery ❑ Modification to existing source' ',"4::`' El Previously grandfathered battery' ❑ Registration for coverage under general permit no.GP01 ' ❑ Synthetic minor facility &cancellation request for individual permit': `-_ ® Located in the 8-hr Ozone Control Area' ® Application for or Modification of an individual permit ❑ Registered under general permit no.GPO] O Administrative permit amendment' ❑ Permitted under individual permit: ICI WF tO8H ❑ 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 Name9: Bonanza Creek Energy Operating Company LLC OGCC Operator#: 8960 Mailing Address°: 410 17°i Street,Suite 1500 pyoung@BonanzaCrk.co City: Denver State: CO Zip: 80202 E-mail: m Contact Name: Peg Young Phone: 720-440-6133 Fax: 720-279-2331 Tank Battery Name": Pronghorn B-28 Production Facility(COGCC#433478) Number of tanks: 8-400bb1 Location12(QQ Sec.Twp.Range.): SW/NW,Sec 28,T5N,R61W County: Weld Total tank capacity[bbl]: 3,200 Calendar year for which"Actual"data applies 3: NA Year(s)tank(s)were placed in service": 2014 Control Description's: Three(3)Leed L30-0010(SN:21615,21464,21735) Control Efficiency": 95% Condensate Throughput['[bbl/year] Requested": 262,800 Maximum for PTE calculation19: 262,800 Actual20: 219,000 While Controls Operational2' 219,000 Other equipment at facility2: Heated separators,produced water tanks,natural gas-fired engines,pneumatic pump Comments: 2-yr APEN update not required(uncontrolled VOC 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 Emissions" Actual Emissions20 Pollutant24 [lb/bbl] PTE25 Uncontrolled26 Controlled2' Uncontrolled26 Controlled27 VOC[tons/year] 0.49 J 64.60 64.60 V 3.23 / 53.83 ✓ 2.69 NOx[tons/year] 0.12 -/ 0.10 CO[tons/year] 0.65 -/ 0.56 Benzene[lbs/year] 0.005 .1 1,265.2 1,265.2 ,/ 63.3 i 1,054.4 ✓ 52.7 n-Hexane[lbs/year] 0.029 J 7,665.8 7,665.8 ✓ 383.3 ,/ 6,388.1 ✓ 319.4 ,/ Wells serviced by this tank or tank battery2s API#: 05-123-37655 Name: Pronghorn B-V-28HNB ®Newly Reported Well API#: 05-123-38633 Name: Pronghom 11-41-28HNB ®Newly Reported Well API#: 05-123-38634 Name: Pronghom 12-24-28HNC _ ®Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name ❑Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: ❑Newly Reported Well i The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of my knowledge and belief. If this is a registration for coverage under general permit GPOI,I further certify that this source is and will be operated in full ..m u fiance with each c ' 'o f general permit GPOI. Signature of Legally 1thorized Person(not a vendor or consultant) Date David I.Lillo Vice President,Rocky Mt.Asset Management 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-Bl rj rI p (303)692-3150 $250 General Permit fee for each new GP 4300 Cherry Creek Drive South J ! 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