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Home My WebLink About20151901.tiff coPHe COLORADO Co Department of Public Health Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County- Clerk to the Board RECEIVED 1150OSt PO Box 758 Greeley, CO 80632 JUN 2 6 2015 June 22, 2015 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On June 24, 2015, the Air Pollution Control Division will begin a 30-day public notice period for Bonanza Creek Energy Operating Company LLC - Pronghorn D-9 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, I a Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure RU-b 2015-1901 - 1 - 15 te-Rt:) PO; kLU(,24, 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe v, z uj John W. Hickenlooper, Governor Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer I.* ,,: A CDPHE Air Pollution Control Division co vf Notice of a Proposed Project or Activity Warranting Public '' Comment Website Title: Bonanza Creek Energy Operating Company LLC - Pronghorn D-9 Production Facility - Weld County Notice Period Begins: June 24, 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 D-9 Production Facility Oil and Gas Exploration and Production Facility SWSW of Section 9, Township 5N, Range 61W Weld County The proposed project or activity is as follows: The applicant proposes to permit equipment associated with an oil and gas exploration and production facility. The facility wide permit covers twelve (12) condensate storage tanks, two (2) produced water storage tanks, condensate loadout, seven (7) low pressure separators, one (1) vapor recovery tower, and one (1) emergency flare. 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 14WE1822 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: Harrison Slaughter Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us Vg. COLORADO 1 1 AaaT rapt mktina STATE OF COLORADO ��pF Coj COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION y TELEPHONE: (303)692-3150 * 1876 CONSTRUCTION PERMIT PERMIT NO: 14W E1822 822 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 facility, known as the Pronghorn D-9 Production Facility located in the SWSW of Section 9, Township 5N, Range 61W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Twelve (12) above ground 500 bbl atmospheric condensate CNDTK-1 009 storage tanks. Emissions from these tanks are controlled by four (4) enclosed flares. Each flare has a minimum control efficiency of 95%. Two (2) above ground 500 bbl atmospheric produced water PW 010 storage tanks. Emissions from the tank are controlled by four (4) enclosed flares. Each flare has a minimum control efficiency of 95% Truck loadout of condensate. Emissions from loadout are TLO 011 controlled by dedicated vapor balance service and four(4) enclosed flares. Collection system is 70% efficient and each flare has a minimum control efficiency of 95%. Sep-1 to 012 Seven (7) low-pressure separators controlled by four (4) enclosed Sep-7 flares. Each flare has a minimum control efficiency of 95%. One (1) vapor recovery tower (VRT) controlled by four (4) VRT-1 013 enclosed flares during vapor recovery unit (VRU) downtime. Each flare has a minimum control efficiency of 95%. One (1) emergency flare with a minimum control efficiency of FL-2 014 95%. Flare is not enclosed. This flare is used during periods when the gas gathering pipeline is not available or during emergencies. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: AIRS ID: 123/9D10 Page 1 of 18 Wellhead Version 2012-1 IF olol De ent f Public Health and Environment Air Pollution Control Division : • REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at https://www.colorado.gov/pacific/cdphe/other-air- permittinq-notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, I II.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. Point 012 and 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 flow rate of natural gas vented from the low pressure separators and the vapor recovery tower. The operator shall use the gas flow rate listed in the application for the actual flow rate until the flow meter is installed, not to exceed one hundred and eighty (180) days after issuance of this permit. 5. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 6. The following information for all permitted equipment except fugitive emissions from equipment leaks shall be provided to the Division within fifteen (15) days after the latter of commencement of operation or issuance of this permit,. • 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.) 7. The operator shall retain the permit final authorization letter issued by the Division, after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS AIRS ID: 123/9D10 Page 2 of 18 Colo De - ent f Public Health and Environment Air Pollution Control Division 8. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Equipment ID Point NOX VOC CO Emission Type CNDTK-1 009 0.3 5.8 1.2 Point PW 010 --- 3.9 --- Point TLO 011 0.1 13.5 0.4 Point Sep-1 to Sep-7 012 0.3 6.1 1.7 Point VRT-1 013 0.3 8.7 1.6 Point FL-2 014 0.5 4.7 2.5 Point See "Notes to Permit Holder #4" 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. 9. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) Facility AIRS Pollutants Equipment Point Control Device Controlled ID CNDTK-1 009 Four(4) Enclosed Flares VOC, HAPs PW 010 Four(4) Enclosed Flares VOC, HAPs TLO 011 Vapor balance and four(4) enclosed flares VOC, HAPs Sep-1 to 012 Four(4) Enclosed Flares VOC, HAPs Sep-7 VRT-1 013 Four(4) Enclosed Flares VOC, HAPs FL-2 014 Open Flare VOC, HAPs PROCESS LIMITATIONS AND RECORDS AIRS ID: 123/9D10 Page 3 of 18 olo De ent f Public Health and Environment Air Pollution Control Division 10. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the throughput shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point CNDTK-1 009 Condensate throughput 578,160 BBL PW 010 Produced water throughput 591,300 BBL TLO 011 Condensate Loading 578,160 BBL Sep-1 to Sep-7 012 Total Gas vented from Low-Pressure 4.6 MMscf/yr Separators during VRU Downtime Total Gas Vented from Vapor VRT-1 013 Recovery Tower during VRU 2.8 MMscf/yr Downtime FL-2 014 Total Gas Vented from All Separators 10.0 MMscf/yr to emergency flare The owner or operator shall calculate monthly process rates based on the calendar month. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 11. Point 011: Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 12. Point 012 and 013: Upon installation of the flow meter required in Condition 4, the owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from the low pressure separators and VRT during VRU downtime using a flow meter. The flow meter shall continuously monitor flow rate and record total volumetric flow vented to the enclosed flares from the low pressure separators and VRT during VRU downtime. The owner or operator shall use monthly throughput records and p calculation methods detailed in the O&M Plan to demonstrate compliance with the limits specified in Condition 10 and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 13. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 14. These sources are subject to the odor requirements of Regulation No. 2. (State only enforceable) 15. Point 009: 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 AIRS ID: 123/9D10 Page 4 of 18 0. De entf Public Health and Environment Air Pollution Control Division 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. 16. Point 009: 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. 17. Point 009 and 010: The flare 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. 18. Point 009 and 010: The storage tanks covered by this permit are subject to Regulation 7, Section XVII.C emission control requirements. These requirements include, but are not limited to: Section XVII.C.1. Control and monitoring requirements for storage tanks XVII.C.1.b. Owners or operators of storage tanks with uncontrolled actual emissions of VOCs equal to or greater than six (6) tons per year based on a rolling twelve- month total must operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. XVII.C.1.b.(i)(a) A storage tank constructed on or after May 1, 2014, must be in compliance within 90 days of the date that the storage tank commences operation. XVII.C.1.b.(i)(b) A storage tank constructed before May 1, 2014, must be in compliance 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: AIRS ID: 123/9D10 Page 5 of 18 • i olo � De .� entcublic Health and Environment Air Pollution Control Division XVII.C.1.d.(i) Visual inspection of any thief hatch, pressure relief valve, or other access point to ensure that they are closed and properly sealed; XVII.C.1.d.(ii) Visual inspection or monitoring of the air pollution control equipment to ensure that it is operating, including that the pilot light is lit on combustion devices used as air pollution control equipment; XVII.C.1.d.(iii) If a combustion device is used, visual inspection of the auto-igniter and valves for piping of gas to the pilot light to ensure they are functioning properly; XVII.C.1.d.(iv) Visual inspection of the air pollution control equipment to ensure that the valves for the piping from the storage tank to the air pollution control equipment are open; and XVII.C.1.d.(v) If a combustion device is used, inspection of the device for the presence or absence of smoke. If smoke is observed, either the equipment must be immediately shut-in to investigate the potential cause for smoke and perform repairs, as necessary, or EPA Method 22 must be conducted to determine whether visible emissions are present for a period of at least one (1) minute in fifteen (15) minutes. XVII.C.1.e. If storage tanks or associated equipment is unsafe, difficult, or inaccessible to monitor, the owner or operator is not required to monitor such equipment until it becomes feasible to do so. XVII.C.2. Capture and monitoring requirements for storage tanks that are fitted with air pollution control equipment as required by Sections XII.D. or XVII.C.1. XVII.C.2.a. Owners or operators of storage tanks must route all hydrocarbon emissions to air pollution control equipment, and must operate without venting hydrocarbon emissions from the thief hatch (or other access point to the tank) or pressure relief device during normal operation, unless venting is reasonably required for maintenance, gauging, or safety of personnel and equipment. Compliance must be achieved in accordance with the schedule in Section XVII.C.2.b.(ii). XVII.C.2.b. Owners or operators of storage tanks subject to the control requirements of Sections XII.D.2., XVII.C.1.a, or XVII.C.1.b. must develop, certify, and implement a documented Storage Tank Emission Management System ("STEM") plan to identify, evaluate, and employ appropriate control technologies, monitoring practices, operational practices, and/or other strategies designed to meet the requirements set forth in Section XVII.C.2.a. Owners or operators must update the STEM plan as necessary to achieve or maintain compliance. Owners or operators are not required to develop and implement STEM for storage tanks containing only stabilized liquids. The minimum elements of STEM are listed below. XVII.C.2.b.(i) STEM must include selected control technologies, monitoring practices, operational practices, and/or other strategies; procedures for evaluating ongoing storage tank emission capture performance; and monitoring in accordance with approved instrument monitoring methods following the applicable schedule in Section XVII.C.2.b.(ii) and Inspection Frequency in Table 1. AIRS ID: 123/9D10 Page 6 of 18 A AA'IAA.., r Colo De - rent' f Public Health and Environment Air Pollution Control Division mato 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 Schedule Uncontrolled Actual VOC Monitoring Method Emissions (tpy) Inspection Frequency > 6 and < 12 Annually January 1, 2016 > 12 and < 50 Quarterly July 1, 2015 > 50 Monthly January 1, 2015 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, AIRS ID: 123/9D10 Page 7 of 18 olo,�- . 1 Dew ent f Public Health and Environment a _ Air Pollution Control Division 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. 19. Point 011: 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) 20. Point 011: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations onsite at the time of inspections to monitor compliance with Condition 20 (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. 21. Point 011: 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. 22. Point 012 and 013: The flare covered by this permit is subject to Regulation No. 7, Section XVII.B.2 General Provisions (State only enforceable). All air pollution control equipment shall be operated and maintained pursuant to the manufacturing specifications or equivalent to the extent practicable, and consistent with technological limitations and good engineering and maintenance practices. The owner or operator shall keep manufacturer specifications or equivalent on file. In addition, all such air pollution control equipment shall be adequately designed and sized to achieve the control efficiency rates and to handle reasonably foreseeable fluctuations in emissions of VOCs and other hydrocarbons during normal operations. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable. AIRS ID: 123/9D10 Page 8 of 18 7,99v..9, oI) De f r- rent f Public Health and Environment Air Pollution Control Division 23. Point 012 and 013: Per Regulation no. 7, Section XVII.B.2.d, all combustion devices used to control emissions of hydrocarbons must be equipped with and operate an auto- igniter. 24. Point 012 and 013: The separator covered by this permit is subject to Regulation 7, Section XVII.G. (State Only). On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the date of first production by air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. 25. Point 014: The open flare covered by this permit has been approved as an alternative emissions control device under Regulation No. 7, Section XVII.B.2.e. The open flare shall 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 open flare, 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, except the enclosed flare requirement. This flare must be equipped with an operational auto-igniter according to the following schedule: • If installed after May 1, 2014, upon installation of the combustion device. • If installed before May 1, 2014, by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. OPERATING & MAINTENANCE REQUIREMENTS 26. Upon startup of these points, the applicant shall follow the 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.) 27. Point 011: 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. AIRS ID: 123/9D10 Page 9 of 18 R}-h II �. olo . De ent f Public Health and Environment Air Pollution Control Division f. Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. g. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 28. Point 009, 010, 012, 013: The owner or operator shall demonstrate compliance with opacity standards, using EPA Method 22 to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one (1) minute in any fifteen (15) minute period during normal operation. (Reference: Regulation No. 7 Section XVII.All) 29. 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. ADDITIONAL REQUIREMENTS 30. A revised it Pollutant Emission Notice shall e filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or AIRS ID: 123/9D10 Page 10 of 18 A olo; "- De rent f Public Health and Environment A Air Pollution Control Division daft ftd-ft.Z 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. 31. 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 32. 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. 33. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 34. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant 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 applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 35. 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. 36. 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 applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. AIRS ID: 123/9D10 Page 11 of 18 olo=° De ent f Public Health and Environment Air Pollution Control Division S 37. 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. 38. 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: Harrison Slaughter Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bonanza Creek Energy Operating Company LLC for Points 009-014. AIRS ID: 123/9D10 Page 12 of 18 . �:, , olo De[ �nent?f Public Health and Environment 3 '4 Air Pollution Control Division .:n , Notes to Permit Holder: 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 permittee 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 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 permittee shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/agcc-reqs 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS# BIN (lb/yr) reportable? Rate(Ib/yr) Benzene 71432 A 946 Yes 48 Toluene 108883 C 844 Yes 43 Ethylbenzene 100414 C 130 No 7 009 Xylenes 1130207 C 340 Yes 17 n-Hexane 110543 C 6,245 Yes 313 2,2,4- 540841 C 864 Yes 43 Trimethylpentane Benzene 71432 A 4,140 Yes 207 010 n-Hexane 110543 C 13,009 Yes 651 Benzene 71432 A 298 Yes 100 Toluene 108883 C 207 No 69 Ethylbenzene 100414 C 23 No 8 011 Xylenes 1130207 C 50 No 17 n-Hexane 110543 C 3,042 Yes 1,019 2,2,4- 540841 C 284 Yes 95 Trimethylpentane Benzene 71432 A 726 Yes 37 012 Toluene 108883 C 674 Yes 34 AIRS ID: 123/9D10 Page 13 of 18 --t. ,6 olo a DeL ent:,. f Public Health and Environment 4 Air Pollution Control Division Ethylbenzene 100414 C 200 No 10 2,2,4- 540841 C 742 Yes 38 Trimethylpentane Xylenes 1130207 C 310 Yes 16 n-Hexane 110543 C 4,968 Yes 249 Benzene 71432 A 2,342 Yes 118 n-Hexane 110543 C 15,296 Yes 765 Toluene 108883 C 2,048 Yes 103 013 Ethylbenzene 100414 C 308 Yes 16 2,2,4- 540841 C 1,610 Yes 81 Trimethylpentane Xylenes 1130207 C 794 Yes 40 Benzene 71432 A 410 Yes 21 Toluene 108883 C 384 Yes 20 Ethylbenzene 100414 C 134 No 7 014 Xylenes 1130207 C 236 No 12 n-Hexane 110543 C 2,944 Yes 148 2,2,4- 540841 C 415 Yes 21 Trimethylpentane 5) The emission levels contained in this permit are based on the following emission factors: Point 009: Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source NOx 0.068 lb/MMBtu 0.068 lb/MMBtu AP-42, Table 13.5-1 CO 0.37 lb/MMBtu 0.37 lb/MMBtu AP-42, Table 13.5-1 VOC 9.5 lb/1000 gal 0.48 lb/1000 gal ProMax 71432 Benzene 0.039 lb/1000 gal 0.0020 lb/1000 gal ProMax 108883 Toluene 0.035 lb/1000 gal 0.0018 lb/1000 gal ProMax 100414 Ethylbenzene 0.0054 lb/1000 gal 0.0003 lb/1000 gal ProMax 1330207 Xylenes 0.014 lb/1000 gal 0.0007 lb/1000 gal ProMax 110543 n-hexane 0.257 lb/1000 gal 0.013 lb/1000 gal ProMax 540841 2,2,4-TMP 0.035 lb/1000 gal 0.0018 lb/1000 gal ProMax Note: The controlled emissions factors for point 009 are based on the flare control efficiency of 95%. A HHV of 2,822 BTU/scf was used for combustion calculations. These emission factors were developed using a pressurized liquids analysis from the 13-43-9HNB, State Pronghorn A-E-16HNB, Pronghorn C-W-9HNB, Pronghorn D-X-9HNB wells at the Pronghorn D-9 facility. Point 010: Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source lb/BBL Produced Ib/BBL Produced Water Throughput Water Throughput AIRS ID: 123/9D10 Page 14 of 18 yam. '1.1 g t,zu olcYac, De, ent, f Public Health and Environment \ Air Pollution Control Division Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source Ib/BBL Produced Ib/BBL Produced Water Throughput Water Throughput VOC 0.262 0.0131 PS Memo 09-02 110543 n-Hexane 0.022 0.0011 PS Memo 09-02 71432 Benzene 0.007 0.0004 PS Memo 09-02 Note: The controlled emissions factors for point 010 are based on the flare control efficiency of 95%. Point 011: Emission Factors CAS Pollutant Uncontrolled Controlled Source lb/BBL loaded lb/BBL Loaded NOx 0.068 lb/MMBtu 0.068 lb/MMBtu AP-42 CO 0.370 lb/MMBtu 0.370 lb/MMBtu AP-42 VOC 0.139 0.0466 AP-42 71432 Benzene 0.00052 0.00017 Mass Balance 110543 n-hexane 0.00526 0.00176 Mass Balance 108883 Toluene 0.00036 0.00012 Mass Balance 100414 Ethylbenzene 0.000038 0.000013 Mass Balance 1330207 Xylenes 0.000084 0.000028 Mass Balance 540841 2,2,4 TMP 0.000491 0.000165 Mass Balance The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: S = 1.0 (Submerged loading: dedicated vapor balance service) P (true vapor pressure) = 2.66 psia M (vapor molecular weight) = 55.86 Ib/Ib-mol T (temperature of liquid loaded) = 524 °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the calculated truck loading vapors by the VOC emission factor. The mole fractions used to determine the composition of the truck loading vapors were obtained from the extended natural gas liquid analysis of a Pronghorn D-9 sales oil sample. Controlled emission factors are based on a combined control efficiency of 66.5%. This combined efficiency takes into account the collection system efficiency of 70% and the minimum flare control efficiency of 95%. The determination of the combined control efficiency is as follows: combined efficiency = (0.70) * (0.95) = 0.665 A HHV of 3,196 BTU/scf was used for combustion calculations. Point 012: Weight Emission Emission CAS# Pollutant Fraction of Factors Factors Source Gas (°/u) Uncontrolled Controlled 0.068 0.068 NOx -- lb/MMBtu lb/MMBtu AP-42 AIRS ID: 123/9D10 Page 15 of 18 olo De ent f Public Health and Environment Air Pollution Control Division Weight Emission Emission CAS# Pollutant Fraction of Factors Factors Source Gas(%) Uncontrolled Controlled CO --- 0.37 lb/MMBtu 0'37 AP-42 lb/MMBtu VOC 58.74 52,272.4 2613.62 Gas Analysis Ib/MMscf lb/MMscf 157. 7.89 71432 Benzene 0.1772 lb/MMscf lb/MMscf Gas Analysis 146.7 7.34 108883 Toluene 0.1648 lb/MMscf Ib/MMscf43.42 2.17 Gas Analysis 100414 Ethylbenzene 0.0487 lb/MMscf lb/MMscf67.4 3.37 Gas Analysis 1330207 Xylenes 0.0757 lb/MMscf lb/MMscf Gas Analysis 110543 n-hexane 1.2126 1079.5 53.98 Gas Analysis lb/MMscf lb/MMscf 161.2 8.06 540841 2,2,4-TMP 0.1810 lb/MMscf lb/MMscf Gas Analysis Note: The uncontrolled VOC and HAP emissions for this point were calculated using the October 7, 2014 analysis of a gas sample collected from the VRU inlet at the Pronghorn D-9 facility. The controlled VOC and HAP emissions factors for point 012 are based on the flare control efficiency of 95%. A HHV of 1,895 BTU/scf was used for combustion calculations. Point 013: Weight Emission Emission CAS# Pollutant Fraction of Factors Factors Source Gas (%) Uncontrolled Controlled 0.068 0.068 NOx --- lb/MMBtu lb/MMBtu AP-42 CO --- 0.37 lb/MMBtu 0.37 AP-42 Ib/MMBtu VOC 89.09 122,757.6 6137.88 Gas Analysis lb/MMscf lb/MMscf 71432 Benzene 0.6025 830.3 41.515 Gas Analysis lb/MMscf lb/MMscf 725. 36.29 108883 Toluene 0.5267 lb/MMs8 cf lb/MMscfGas Analysis 100414 Ethylbenzene 0.0795 109.5 5.475 Gas Analysis lb/MMscf lb/MMscf 1330207 Xylenes 0.2044 281.7 14.085 Gas Analysis lb/MMscf lb/MMscf 110543 n-hexane 3.9339 5,420.7 271.035 Gas Analysis Ib/MMscf lb/MMscf 540841 2,2,4-TMP 0.4140 570.5 28.525 Gas Analysis lb/MMscf Ib/MMscf Note: The uncontrolled VOC and HAP emissions were calculated based on a ProMax model that was used to estimate the VOC and HAP content of the stream and the flow rate of AIRS ID: 123/9D10 Page 16 of 18 *CAA De anent- f Public Health and Environment Air Pollution Control Division Lekt2 the stream. The controlled VOC and HAP emissions factors for point 013 are based on the flare control efficiency of 95%. A HHV of 2,915 BTU/scf was used for combustion calculations. Point 014: Weight Emission Emission CAS# Pollutant Fraction of Factors Factors Source Gas (%) Uncontrolled Controlled 0.068 0.068 NOx --- lb/MMBtu lb/MMBtu AP-42 CO --- 0.37 lb/MMBtu 0.37 AP-42 lb/MMBtu VOC 30.1017 18,661 933.05 Gas Analysis lb/MMscf lb/MMscf 41.02 2.051 71432 Benzene 0.0661 lb/MMscf lb/MMscf 38.5 1.925 Gas Analysis 108883 Toluene 0.0621 lb/MMscf lb/MMscf13.4 0.67 Gas Analysis 100414 Ethylbenzene 0.0217 lb/MMscf lb/MMscf23.6 1.18 Gas Analysis 1330207 Xylenes 0.0380 lb/MMscf lb/MMscf 294.4 14.72 Gas Analysis 110543 n-hexane 0.380 lb/MMscf lb/MMscf41.4 2.07 Gas Analysis 540841 2,2,4-TMP 0.0668 lb/MMscf lb/MMscf Gas Analysis Note: These emission factors were developed using a weighted average of the extended gas analysis from the Pronghorn 13-43-9HNB, State Pronghorn A-E-16HNB, Pronghorn C-W- 9HNB, Pronghorn D-X-9HNB wells at the Pronghorn D-9 facility. The controlled VOC and HAP emissions factors for point 012 are based on the flare control efficiency of 95%. A HHV of 1,340 BTU/scf was used for combustion calculations. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, NOx, CO, n-Hexane, Total HAPs NANSR Synthetic Minor Source of: VOC, NOx, n-Hexane, Total HAPs MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Not Applicable 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: AIRS ID: 123/9D10 Page 17 of 18 -, - .. -,16 olo De entf Public Health and Environment Air Pollution Control Division http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXX)O(X 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: 123/9D10 Page 18 of 18 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Bonanza Creek Energy Operating Company LLC Permit Number: 14WE1822 Source Location: SWSW Section 9, Township 5N, Range 61W Point 009: Twelve (12) 500 BBL above ground atmospheric condensate storage tanks Point 010: Two (2) 500 BBL above ground atmospheric produced water storage tanks. Point 011: Condensate truck loadout Equipment Description: Point 012: Seven (7) low pressure gas/oil separators. Separators are controlled by four(4)enclosed flares when the gas compressors are down. Point 013: One(1)VRT controlled by four(4) enclosed flares during gas compressor downtime. Point 014: Flare to be used in case of emergency. AIRS ID: 123-9010 Date: 04/06/2015 Review Engineer: Harrison Slaughter Control Engineer: Chris Laplante Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt *If tank is a true minor source at a true minor facility, it shall be granted "Final Approval" Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no"to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? November 17, 2014 Section 4—Source Description AIRS Point Equipment Description Twelve(12) above ground 500 bbl atmospheric condensate storage tanks. 009 Emissions from these tanks are controlled by four(4) Leed enclosed flares with 95% control efficiency. 010 Two(2)500 BBL above ground atmospheric produced water storage tanks. 011 Truck loadout of condensate. Emissions from the loadout are controlled by vapor balance (process 01) and an enclosed flare(process 02) Page 1 012 Seven (7) low pressure separators controlled by four(4)enclosed flares during gas compressor downtime. Flares have a minimum combustion efficiency of 95%. 013 One(1)VRT controlled by(4) enclosed flares during gas compressor downtime. Flares have a minimum combustion efficiency of 95% 014 Flare to be used in case of emergency. Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria Yes No pollutant? If"yes", for what pollutant? PM10 CO X Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source N/A PM10 N/A CO N/A Ozone RACT per Regulation 3, Part B, Section III.D.2) Is this source located in the 8-hour ozone non- attainment region?(Note: If"yes" the provisions of X Yes No Regulation 7, Sections XII and XVII.C may apply) Loadout: Is this source located at an oil and gas X Yes No exploration site? Loadout: If yes, does this source load less than 10,000 gallons of crude oil per day on an annual average, splash fill less than 6750 bbl of condensate Yes X No (hydrocarbons that have an API gravity of 40 degrees or greater) per year or submerged fill less than 16,308 bbl of condensate per year? Loadout: Is this source located at a facility that is considered a major source of hazardous air pollutant Yes X No (HAP)emissions? Loadout: Will this equipment be operated in any X Yes No NAAQS nonattainment area? Loadout: Does this source load gasoline into Yes X No transport vehicles? Produced water: Is this source claiming exempt See notes in status for this source based on the fraction of oil in the Yes X No section 14 for stored water(less than 10/0 by volume crude oil on an explanation. average annual basis)? Produced water: Are these produced water tanks located at a commercial facility that accepts oil Yes X No production wastewater for processing? Produced water: Are these produced water tanks subject to Colorado Oil and Gas Conservation Yes X No Commission (COGCC) 805 Rule? If so, submit Form APCD-105 Section 5—Emission Estimate Information AIRS Point Emission Factor Source 009 Site-specific using Pro-Max(Refer to Section 14 for calculations) 010 CDPHE Emission Factors (PS Memo 09-02) AP-42: Chapter 5.2, Equation 1 L= (12.46*S*P*M/T)*(VOC wt%) 011 L= loading losses in lb per 1000 gallons loaded S = Saturation Factor P=true vapor pressure of liquid loaded [psia] M = molecular weight of vapors [lb/lb-mole] T=temperature of bulk liquid loaded [deg. R] Page 2 012 Site-specific using VOC weight fraction (Refer to Section 14 for calculations) 013 Site-specific using VOC weight fraction (Refer to Section 14 for calculations) 014 Site-specific using VOC weight fraction (Refer to Section 14 for calculations) Did the applicant provide actual process data for the emission inventory? X Yes No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/Throughput/Production 009 578,160 BBL per year(481,800 x 1.2) 010 591,300 BBL per year 011 578,160 BBL per year condensate loaded 012 3,502 scf/hr=4,601,628 scf/yr=4.60 MMscf/yr 013 2,147 scf/hr= 2,821,158 scf/yr= 2.8 MMscf/yr 014 1,142 scf/hr= 10,003,920 scf/yr= 10.0 MMscf/yr Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 009 481,800 BBL per year 2014 010 591,300 BBL per year N/A 011 578,160 BBL per year condensate loaded N/A 012 3,502 scf/hr=4,601,628 scf/yr=4.60 MMscf/yr N/A 013 2,147 scf/hr= 2,821,158 scf/yr=2.8 MMscf/yr N/A 014 1,142 scf/hr= 10,003,920 scf/yr= 10.0 MMscf/yr N/A Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 009 578,160 BBL per year 010 591,300 BBL per year 011 578,160 BBL per year condensate loaded 012 3,502 scf/hr=4,601,628 scf/yr=4.60 MMscf/yr 013 2,147 scf/hr=2,821,158 scf/yr= 2.8 MMscf/yr 014 1,142 scf/hr= 10,003,920 scf/yr= 10.0 MMscf/yr Does this facility use control devices? X Yes No AIRS Point Process Control Device Description % Reduction Granted 009 01 Four(4)—48" Leed Enclosed Flares 95 010 01 Four(4)—48" Leed Enclosed Flares 95 011 01 Vapor Balance 70 011 02 Four(4)—48" Leed Enclosed Flares 95 012 01 Four(4)—48" Leed Enclosed Flares 95 013 01 Four(4)—48" Leed Enclosed Flares 95 014 01 Candlestick Open Flare 95 Page 3 Section 6—Emission Summary(tons per year) Point NO. VOC CO SOx PM10 Single Total HAP HAP 009 0.3 115.4 1.2 "' 3.2 (n-hexane) 4.7 6.5 010 --- 77.5 --- --- --- (n-hexane) 8.6 1.6 011 0.1 40.2 0.4 --- "' (n-Hexane) 2.0 PTE: 012 0.3 120.3 1.7 --- 2.5 (n-hexane) 3.9 013 0.3 173.2 1.6 --- (n-Hexane) 11.2 1.5 014 0.5 93.3 2.5 --- --- (n-Hexane) 2.3 3.2 009 0.3 115.4 1.2 - --- (n-hexane) 4.7 010 --- 77.5 --- --- 6.5 8.6 Uncontrolled point (n-hexane) 1.6 source emission rate: 011 0.1 40.2 0.4 --- --- (n-Hexane) 2.0 2.5 012 0.3 120.3 1.7 --- --- (n-hexane) 3.9 7.7 013 0.3 173.2 1.6 (n-Hexane) 11.2 014 0.5 93.3 2.5 "' 1.5 (n-Hexane) 2.3 TOTAL(TPY) 1.5 619.9 7.4 --- --- 23.2 32.7 (n-hexane) 009 0.3 5.8 1.2 --- ' ' 0.2 (n hexane) 0.3 010 --- 3.9 --- (n-hexane) 0.43 1.6 Controlled point 011 0.1 13.5 0.4 --- (n-Hexane) 0.7 source emission rate: 012 0.3 6.1 1.7 --- 0.2 0.2 (n-hexane) 013 0.3 8.7 1.6 --- 0.4 (n-Hexane) 0.6 0.1 014 0.5 4.7 2.5 "' (n Hexane) 0.2 INSIGNIFICANTS 17.23 19.43 18.81 ___ 0.4 (TPY) (n-Hexane) TOTAL PERMITTED 1.5 42.7 7.4 --- --- 2.9 2.5 (TPY) (n-hexane) Section 7—Non-Criteria/Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS# BIN Emission Rate emissions (lb/yr) reportable? Rate(lb/yr) Point 009 Benzene 71432 A 946 Yes 48 Toluene 108883 C 844 Yes 43 Ethylbenzene 100414 C 130 No 7 Xylenes 1130207 C 340 Yes 17 n-Hexane 110543 C 6,245 Yes 313 Page 4 2,2,4-Trimethylpentane 540841 C 864 Yes 43 Point 010 Benzene 71432 A 4,140 Yes 207 n-Hexane 110543 C 13,009 Yes 651 Point 011 Benzene 71432 A 298 Yes 100 Toluene 108883 C 207 No 69 Ethylbenzene 100414 C 23 No 8 Xylenes 1130207 C 50 No 17 n-Hexane 110543 C 3,042 Yes 1,019 2,2,4-Trimethylpentane 540841 C 284 Yes 95 Point 012 Benzene 71432 A 726 Yes 37 Toluene 108883 C 674 Yes 34 Ethylbenzene 100414 C 200 No 10 2,2,4-Trimethylpentane 540841 C 742 Yes 38 Xylenes 1130207 C 310 Yes 16 n-Hexane 110543 C 4968 Yes 249 Point 013 Benzene 71432 A 2,342 Yes 118 n-Hexane 110543 C 15,296 Yes 765 Toluene 108883 C 2,048 Yes 103 Ethylbenzene 100414 C 308 Yes 16 2,2,4-Trimethylpentane 540841 C 1,610 Yes 81 Xylenes 1130207 C 794 Yes 40 Point 014 Benzene 71432 A 410 Yes 21 Toluene 108883 C 384 Yes 20 Ethylbenzene 100414 C 134 No 7 Xylenes 1130207 C 236 No 12 n-Hexane 110543 C 2,944 Yes 148 2,2,4-Trimethylpentane 1130207 C 415 Yes 21 Note: Regulation 3, Part A, Section II.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory X Yes No standard? If"yes", complete the information listed below Page 5 AIRS Point Process Pollutant Regulatory Basis Test Method 012 0r VOC, State only requirement Site-specific gas HAPS analysis(annual) Site-specific gas 013 0r HAPs State only requirement analysis (initial and annual) Section 9—Source Classification What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what X Title V PSD X NA NSR MACT programs? Is this a modification to an existing permit? Yes X No If"yes"what kind of modification? N/A Minor N/A Synthetic N/A Major Minor Section 10—Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes",for which pollutants?Why? VOC For Reg. 3, Part B, III.C.1.a (emissions increase>25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 —Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards (NAAQS)? If"yes", for which pollutants?Why? NOx emissions are less than 40 TPY. AIRS Point Section 12—Regulatory Review Regulation 1 ->Particulate, Smoke, Carbon Monoxide and Sulfur Dioxide Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60,Appendix 009-014 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 009-014 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. Page 6 Regulation 3-APENs Construction Permits O.erating Permits''PSD Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: 009-014 each individual emission point in a non-attainment area with uncontrolled actual emissions of one tons per year or more of any individual criteria pollutant(pollutants are not summed)for which the area is non-attainment. (Applicant is required to file an APEN since emissions exceed 1 tons per year VOC) Part B—Construction Permit Exemptions 009-014 Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold(Reg. 3, Part B, Section II.D.2.a) Part B, III.D.2 - RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is located in the 8-hour ozone nonattainment area, but not the 1-hour ozone area. 011 The date of interest for determining whether the source is new or modified is therefore November 20, 2007 (the date of the 8-hour ozone NA area designation). Since the tank battery from which loadout is occurring came into service after the date above (tank battery operation began 09/18/2014), this source is considered "new or modified." Operator is using submerged fill (1.0 saturation factor), therefore, RACT requirements are satisfied. Regulation 6-New Source Performance Standards 011-014 None NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. Is this source greater than 19,800 gallons (471 bbl)? Yes Is this source subject to NSPS Kb? No 009 WHY? The storage vessels are each 500 bbls which is greater than the capacity threshold of-471 bbls. However, the tanks store condensate prior to custody transfer (located at an E&P site). As a result, this subpart does not apply to vessels with a design capacity less than or equal to-10,000 bbls (1589.874 cubic meters)—NSPS Kb 60.110b(d)(4). NSPS OOOO: Tanks with the potential to emission equal to or greater than 6 TPY. Point 010 Are uncontrolled VOC emissions greater than 6 TPY? Yes Are controlled emissions greater than 6 TPY? No Source is not subject to NSPS OOOO requirements. Point 009: 009-010 Are uncontrolled VOC emissions greater than 6 TPY? Yes Are controlled emissions greater than 6 TPY? Yes • Is the operator requesting a permitted limit less than 6 TPY? Yes If yes, the source is not subject to the requirements of NSPS OOOO for permitting purposes. **To clarify this conclusion, it should be noted that although the controlled emissions are 18.2 tpy, each vessel emits less than 6 tpy (i.e. 18.2tpy/12 vessels = 1.52 tpy< 6 tpy) Page 7 Regulation 7,—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS This facility is located in the 8-hr ozone control area;therefore, this facility is 009 and 010 subject to Section XII of this regulation. XVII STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS (Applicant is currently subject to this since actual uncontrolled emissions are greater than 6 tpy of VOC and actual uncontrolled emissions are greater than 20 tpy.) No sections apply. Per Regulation 7, Section VI.C, a terminal is defined as a petroleum liquid storage and distribution facility that has a daily average throughput of more than 011 76,000 liters of gasoline(20,000 gallons), which is loaded directly into transport vehicles. This facility is neither a terminal, nor a bulk plant per definitions in Reg 7, Section VI.C. Section XVII.G: Was the well newly constructed, hydraulically fractured, or recompleted on or after August 012, 013 1, 2014? Yes(first day of production reported as 09/2014) -The separator and VRT are subject to Regulation 7, Section XVII.G and control requirements of Regulation 7, Section XVII.B.2 Regulation 8—Hazardous Air Pollutants 010, 012, 013, and None 014 MACT EEEE: 011 Not subject because synthetic minor source of HAPs MACT HH 009 • This source is not subject to MACT HH because it is not located at a major source of HAP. Section 13—Aerometric Information Retrieval System Coding Information Point Process Process Description Emission Pollutant/ Fugitive Emission Factor Control Factor CAS# (Y/N) Source (%) 9.5 VOC No ProMax 95 lb/1000 gal 0.068 AP-42, lb/MMBtu NOx No _ Table 13.5-1 NA 0.37 AP-42, lb/MMBtu CO No Table 13.5-1 NA 0.039 Benzene/ No ProMax 95 lb/1000 gal 71432 01 Condensate Storage 0.035 Toluene/ No ProMax 95 009 Tanks lb/1000 gal 108883 0.0054 Ethylbenzene No ProMax 95 lb/1000 gal /100414 0.014 Xylenes/ No ProMax 95 lb/1000 gal 1130207 0.257 n-hexane/ No ProMax 95 lb/1000 gal 110543 0.035 2,2,4-TMP/ No ProMax 95 lb/1000 gal 540841 SCC 40400311 —Fixed Roof Tank, Condensate,working+breathing+flashing losses 6.2381 CDPHE PS lb/1000 gal VOC No 95 Produced Water throughput Memo 09-02 010 01 Storage Tank 0.1667 lb/1000 gal Benzene/ No CDPHE PS 95 throughput 71432 Memo 09-02 Page 8 0.5238 n-hexane/ CDPHE PS lb/1000 gal 110543 No 95 Memo 09-02 throughput SCC 40400315—Fixed Roof Tank, Produced Water,working+breathing+flashing losses 3.31 VOC No AP-42 66.5 I lb/1000 gal 0.0123 Benzene/ Engineering lb/1000 gal 71432 No Calculation 66.5 0.0085 Toluene/ Engineering lb/1000 gal 108883 No Calculation 66.5 0.0009 Ethylbenzene Engineering lb/1000 gal /100414 No Calculation 66.5 01 Truck Condensate 0.002 Xylenes/ No Engineering 66.5 011 Loadout lb/1000 gal 1130207 Calculation 0.1252 n-hexane/ No Engineering 66.5 lb/1000 gal 110543 Calculation 0.0117 2,2,4-TMP/ No Engineering 66.5 lb/1000 gal 540841 Calculation 0.068 NOx No AP-42 N/A lb/MMBtu 0.37 CO No AP-42 N/A lb/MMBtu SCC 40600142: Crude Oil: Submerged Loading (balanced Service) 52,272.4 VOC No Engineering 95 Ib/MMscf Calculation 0.068 NOx No AP-42, NA lb/MMBtu Table 13.5-1 0.37 CO No AP-42, NA lb/MMBtu Table 13.5-1 157.8 Benzene/ No Engineering 95 lb/MMscf 71432 Calculation Seven (7)low pressure 01 separators controlled by 146.7 Toluene/ No Engineering 95 012 four(4)enclosed flares. lb/MMscf 108883 Calculation 43.4 Ethlybenzene No Engineering 95 lb/MMscf /100414 Calculation 67.4 Xylenes/ No Engineering 95 lb/MMscf 1130207 Calculation 1,079.5 n-hexane/ No Engineering 95 lb/MMscf 110543 Calculation 161.2 2,2,4-TMP/ No Engineering 95 lb/MMscf 540841 Calculation SCC 31000205-Flares 122,757.6 VOC No Engineering 95 lb/MMscf Calculation 0.068 AP-42, lb/MMBtu NOx No Table 13.5-1 NA 0.37 CO No AP-42, NA lb/MMBtu Table 13.5-1 830.3 Benzene/ No Engineering 95 lb/MMscf 71432 Calculation One(1)VRT controlled 01 by four(4)enclosed 725.8 Toluene/ No Engineering 95 013 flares. lb/MMscf 108883 Calculation 109.5 Ethlybenzene No Engineering 95 lb/MMscf /100414 Calculation ' 281.7 Xylenes/ No Engineering 95 lb/MMscf 1130207 Calculation 5,420.7 n-hexane/ No Engineering 95 lb/MMscf 110543 Calculation 570.5 2,2,4-TMP/ No Engineering 95 lb/MMscf 540841 Calculation SCC 31000205-Flares 014 01 Emergency Flare 18,660.5 VOC No Engineering 95 lb/MMscf Calculation Page 9 0.068 NOx No AP-42, NA lb/MMBtu Table 13.5-1 0.37 CO No AP-42, NA lb/MMBtu Table 13.5-1 41.0 Benzene/ Engineering lb/MMscf 71432 No Calculation 95 38.5 Toluene/ Engineering Ib/MMscf 108883 No Calculation 95 13.4 Ethlybenzene No Engineering 95 Ib/MMscf /100414 Calculation 23.6 Xylenes/ Engineering lb/MMscf 1130207 No Calculation 95 294.4 n-hexane/ Engineering lb/MMscf 110543 No Calculation 95 41.4 2,2,4-TMP/ Engineering lb/MMscf 540841 No Calculation 95 SCC 31000205-Flares . Page 10 Section 14—Miscellaneous Application Notes AIRS Point 009 Condensate Storage Tanks Site-specific emission factor using ProMax: A ProMax simulation was run in order to determine the site specific emission factors for the condensate tanks. The output from ProMax that was used as a basis for the development of the site specific emission factors was the mass flow rate of the "Tank Losses" stream. This stream was a combination of the working, breathing and flashing losses. The working and breathing losses were determined and put into the simulation using a ProMax stencil. The tank loss mass flow rates for the ProMax simulation are as follow: Pollutant Tank Emissions w/VRT in 8760 hour year(tpy) VOC 96.17 Benzene 0.39429 Toluene 0.35164 Ethylbenzene 0.054324 Xylenes 0.14204 n-Hexane 2.5925 2,2,4 TMP 0.35969 The following calculation was conducted to determine the emission factors: uncontrolled emissions,tons) /20001bs\ (\d 1 year EF = (uncontrolled / * \ ton / * esign throughput,bbls/ Example Calculation: lbs (96.17 tons (20001bs1 ( 1 year l _ 0.3991b VOC EF, _ bbl = \ year ) * l ton ) * \481,800 bbls/ bbl The above calculation was repeated for each pollutant to determine the emission factor associated. Permit Notes: 1. The condition stating that "The flare covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XVII." was removed from the permit as the information is contained in condition 20,which remains in the permit. 2. Initial compliance testing requirement was removed since the extended natural gas liquid analysis provided was dated 10/7/2014. 3. The draft permit was submitted to the operator for comment. The operator did not have any comments on the draft permit. Page 11 APEN Notes: ***It should be noted that the following calculation was conducted in order to accurately reflect the emissions during the startup phase of the facility. Initially,the VRT could not fully operate during the first few months of production due to high oil volumes. This information is reflected on the APEN in order to accurately reflect the first year emissions; however, it is not reflected in the permit. This is due to the fact that the VRT is operational all the time at this point and going forward. This was discussed with the operator and they agreed to submit an APEN update in the future to accurately reflect the yearly emissions. A modification to the permit would not be required as the correct emissions and emission factors would already be reflected in that document. Two separate ProMax simulations were run in order to determine the site specific emission factors for the condensate tanks. The first simulation included a VRT, while the second simulation did not. The second simulation was used to account for the downtime of the VRT at the facility. It was assumed that the VRT was down for 20% of the time during the year(1,176 hrs/year). The output from ProMax that was used as a basis for the development of the site specific emission factors was the mass flow rate of the"Tank Losses" stream. This stream was a combination of the working, breathing and flashing losses. The working and breathing losses were determined and put into the simulation using a ProMax stencil. The tank loss mass flow rates for the ProMax simulation with and without the VRT are as follow: Pollutant Tank Emissions w/VRT in Tank Emissions without VRT in 8760 hour year(tpy) 8760 hour year(tpy) VOC 96.17 1,131 Benzene 0.39429 7.6926 Toluene 0.35164 6.7529 Ethylbenzene 0.054324 1.0198 Xylenes 0.14204 2.6253 n-Hexane 2.5925 50.227 2,2,4 TMP 0.35969 5.3877 With the above information, a weighted average is used to determine the overall emissions from the condensate tanks at the site. The following calculation was used to determine the total tank emissions: Emissions with VRT,tons 1 ( Emissions without VRT,tonsTotal emissions = (0.80) * I ) + (0.20) * I ) Iyear year Example Calculation: 96.17 tons 1,131 tons l VOC,tpy = (0.80) * ( ) + (0.20) * ( ) I = 303.14tpy year year The above calculation was repeated for each pollutant to determine the uncontrolled emissions. The result of the above calculation were then converted to emission factors (lb/bbl) using the design throughput of the tanks. The following calculation was used to determine the emission factors: uncontrolled emissions,tons) * (20001bs ( 1 year EF = (uncontrolled \ ton ) * \design throughput,bbls) Example Calculation: lbs (303.14 tons) (20001bs r 1 year l 1.261b VOC EF,bbl = \ year * \ ton ) * \481,800 bbls) bbl The above calculation was repeated for each pollutant to determine the emission factor associated. Page 12 AIRS Point 010 Produced Water Storage Tanks A permit will be issued because the uncontrolled VOC emissions are greater than 1 TPY(APEN threshold) and greater than 2 TPY(permit threshold). State-Developed Emission factors are: Produced Water Tank Default County Emission Factors (lb/bbl) VOC Benzene n-Hexane Adams, Arapahoe, Boulder, Broomfield, Denver, 0.262 0.007 0.022 Douglas, Jefferson, Larimer and Weld Garfield, Mesa, Rio Blanco and Moffat 0.178 0.004 0.010 Remainder of Colorado 0.262 0.007 0.022 State-Developed Emission factors in lb/1000 gal are: Produced Water Tank Default County Emission Factors (lb/1000 gal) VOC Benzene n-Hexane Adams, Arapahoe, Boulder, Broomfield, Denver, 6.2381 0.1667 0.5238 Douglas, Jefferson, Larimer and Weld Garfield, Mesa, Rio Blanco and Moffat 4.2381 0.0952 0.2381 Remainder of Colorado 6.2381 0.1667 0.5238 This source is located in the 8-hour ozone non-attainment area. Notes: 1. Source is claiming less than 1% by volume crude oil on an average annual basis as a means of supporting that the produced water loadout is insignificant. They want to keep the produced water tanks as a permitted source. This is due to the fact that the tanks are being controlled in order to stay below NSPS OOOO thresholds. They are also controlled due to Reg 7 requirements. 2. No testing is required for the water tanks since state approved emission factors are used for this point. APEN Redlines: 1. Original APEN submitted contained information regarding two(2) 60bb1 uncontrolled produced water vaults. It was discussed with the operator that since the produced water vaults are uncontrolled, the division's stance is that they would not meet the APEN grouping criteria contained in Regulation 3, Part A, Section II.B.4. As a result,they should be removed from the APEN and evaluated separately using appropriate emission factors. If they are APEN exempt based on this evaluation, as you indicated you would expect, then no further action would be necessary. If the evaluation indicates they are APEN required, a separate APEN would need to be submitted for the uncontrolled 60 bbl tanks. The operator agreed that the produced water vaults could be removed from the APEN. Permit Notes/Updates: 1. The draft permit was submitted to the operator for comment. The operator did not have any comments on the draft permit. Page 13 AIRS Point 011 Truck Condensate Loadout Units Basis S 1.0 Submerged loading: balanced service based on source's description. P 2.66 Psia Based on the following equation: TVP = >(Constituent TVP)*(Constituent mole fraction in stable oil) *Mole fraction in stable oil taken from sales oil sample from Pronghorn D-9 on 10/7/14) **TVP for each constituent based on Antoine's Equation. M 55.86 Lb/lb-mole Based on equation 1-22 of AP-42 chapter 7.1 T 524 Deg R Based on EPA TANKS meteorological database for Denver, CO L 3.31 Lb/10^3 gal This value isi multiplied by the weight% of VOC in the truck loading vapor. This effectively removes methane and ethane so the value represents VOC rather than TOC. See calculation below. 0.139 Lb/bbl AP-42: Chapter 5.2 Equation 1 L = (12.46*S*P*M/T)*C L= loading losses in lb per 1000 gallons loaded S = Saturation Factor P =true vapor pressure of liquid loaded [psia] M = molecular weight of vapors [lb/lb-mole] T=temperature of bulk liquid loaded [deg. R] C=Weight%of VOC in truck loading vapor The value for C used in the analysis was 0.9364. L 3.31lb/10^3 gal 0.139E-01 lb/bbl Annual requested Throughput 24,282,720ga1/yr Annual requested VOC emissions 80,3391b/yr 40.2tpy Page 14 The HAP emissions were determined through the following equation: lb iVOC Emissions,lbs) (HAP wt%in truck loading vapor) HAP emissions,—yr = l year * \ 100 The HAP weight%'s used in the equation above are as follow: HAP WT% in Truck Loading Vapor Benzene 0.3703% Toluene 0.2574% Ethylbenzene 0.0286% Xylenes 0.0612% n-Hexane 3.7801% 2,2,4 TMP 0.3527% Example Calculation: lb 80,339lbsl (0.3703 lbs Benzene yr = (80,339 year I * \ 100 ) = 298 year This calculation was repeated for each of the HAPs listed above. Emission factors for HAPS are calculated as follow: lbs (HAP emissions,lbs) ( year r 1bb1 l HAP EF,1000gal — \ year I * \throughput,bbls) * \42gallonsl * (1000) Example Calculation: 2981bs year )bbl 0.1231bs Benzene EF= ( l * r *( * (1000) = \ year ) \578,160 bbls) \42gallons 1000ga1 The calculation was repeated for the remaining HAPs. Notes: • It should be noted that a combined control efficiency is utilized to calculate the controlled emissions resulting from the loadout. This control efficiency takes into account both the vapor return line and the enclosed combustor. It is assumed that the collection efficiency of the vapor return line is 70%. This is based on AP-42 Chapter 5 for trucks that are not certified through an annual leak test. Further, the enclosed combustor has a control efficiency of 95%. The combined efficiency of these two processes is calculated as follows: Combined efficiency = (0.95) * (0.70) = 0.665 Permit Notes/Updates: 1. It should be noted that the four enclosed flares utilized to control the hydrocarbon loadout are common control devices for the other process units at the facility. In other words, points 009-013 are all controlled by the same four enclosed combustors. As a result, the flares are subject to the most stringent opacity standard which is in this case no visible emissions. This is a result of the storage tanks and separators subject to Regulation 7 Section XVII. 2. The draft permit was submitted to the operator for comment. The operator did not have any comments on the draft permit. Page 15 Seven (7) low pressure separators controlled by four(4) enclosed flares AIRS Point 012 during gas compressor downtime. Flares have a minimum combustion efficiency of 95%. Operator provided an extended gas analysis and emissions were calculated using EPA Emission Inventory Improvement Program Publication, Volume II, Chapter 10-Displacement equation (10.4-3) where: Ex=Q * MW*Xx/C Ex= emissions of pollutant x Q =Volumetric flow rate/volume of gas processed MW= Molecular weight of gas= SG of gas * MW of air Xx= mass fraction of x in gas C = molar volume of ideal gas (379 scf/lb-mol)at 60F and 1 atm Emissions generated from the flare are: Uncontrolled Total (lb/yr) Controlled Total (Ib/yr) NOx 600 600 VOC 240,600 12,200 CO 3,220 3,220 Benzene 726 37 Toluene 674 34 Ethylbenzene 200 10 Xylenes 310 16 n-hexane 4,968 249 224-TMP 742 38 An extended gas analysis was provided in the application for the Pronghorn D-9 VRU inlet gas dated 10/08/14. The gas analysis was performed less than a year of submittal.An updated extended gas analysis will not be required because: -an extended gas analysis was performed within a year of this submittal and included with this package Emission factors for VOC and HAPS were calculated as follows: lbs _ (Emissions,lbs\ ( year EF,MMscf — l year ) * \f low rate,MMscf) An example calculation is as follows: 726 lbs year 157.8 lbs Benzene EF = year 4.6MMscf MMscf This calculation was repeated for VOC and the remaining HAPs to determine the emission factors. Additional Notes: • EF for NOx and CO were from AP-42, Chapter 13, Table 13.5-1 (NOx= 0.068 Ib/mmbtu; CO = 0.37 Ib/mmbtu) • SO2 emissions are based on the complete conversion of H2s to SO2 • PM10 and PM2.5 based on AP-42 Table 13.5-2 (PM10 and PM2.5=40 ug/I) • It should be noted that the emissions resulting from SO2, PM10 and PM2.5 are below APEN reporting thresholds. The emissions resulting from NOx and CO were calculated using the following equation: / EF,lb \*(Gas Heating Value,Btu) / 1MMBtu \ (1,000,000 scf) (flow rate,MMscf` / lton Emissions,tPy MMBtu l scf )*11,000,000BTU)#l 1MMscf )*l year )*12000lbs) Example Calcuation: N0x= (0.068 lb`*(1895 *Btu) ( 1MMBtu 1*(1,000,000 sq.\*(4.6 MMscf)* )ton \ IMMBtuJ ll scf ) (1,000,000BTUJ l 1MMscf ) l year ) (20001bs)— 0.3 tpy Page 16 This calculation was repeated for the CO emissions. ***Additional information regarding calculations may be found in Excel worksheet named 14WE1822-012.CP1 Permit Notes: 1. Initial site specific extended gas analysis condition was removed from the permit because the gas analysis provided in the application was obtained on 10/08/14 which is within one year of the application. 2. The draft permit was submitted to the operator for comment. The operator did not have any comments on the draft permit. Page 17 AIRS Point 013 One (1)VRT controlled by(4)enclosed flares during gas compressor downtime. Flares have a minimum combustion efficiency of 95% The operator utilized site specific emission factors that were determined using ProMax. Site specific extended natural gas liquid analysis, from four of the wells at the facility, was used as inputs for the ProMax simulation (i.e. the inputs were the mole% of each component of the liquid streams). The analysis for the following wells at the Pronghorn D-9 facility was provided and used for the ProMax simulation: • 13-43-9HNB (Sample Date 10/7/14) • State Pronghorn A-E-16HNB (Sample Date 10/07/14) • Pronghorn C-W-9HNB (Sample Date 10/07/14) • Pronghorn D-X-9HNB (Sample Date 10/07/14) The ProMax simulation was then designed in order to calculate the emissions resulting from the VRT gas stream. The mass fractions calculated for this stream in ProMax were used to determine the emissions and emission factors for VOC and NCRP. The mass fractions taken from ProMax are as follow: Pollutant Pro-Max VRT Gas Stream Mass Fractions VOC 89.0871% Benzene 0.6025% n-Hexane 3.9339% Toluene 0.5267% Xylenes 0.2044% Ethylbenzene 0.0795% 2,2,4-Trimethylpentane 0.4140% With the above provided information the emissions were calculated using EPA Emission Inventory Improvement Program Publication,Volume II, Chapter 10-Displacement equation (10.4-3)where: Ex=Q * MW*Xx/C Ex=emissions of pollutant x Q =Volumetric flow rate/volume of gas processed (obtained from ProMax simulation plus 20% safety factor) MW= Molecular weight of gas (Obtained from ProMax simulation) Xx= mass fraction of x in gas C = molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm Emissions generated from the flare are: Uncontrolled Total (lb/yr) Controlled Total (Ib/yr) NOx 600 600 VOC 346,380 17,320 CO 3,200 3,200 Benzene 2,342 118 Toluene 2,048 103 Ethylbenzene 308 16 Xylenes 794 40 n-hexane 15,296 765 224-TMP 1,610 81 Emission factors for VOC and HAPS were calculated as follows: lbs _ (Emissions,lbs\ r year EF,MMscf — \ year )* l f low rate,MMscf) An example calculation is as follows: VOC EF = (346,380 lbs * ( year l 122,757.6 lbs \ year ) (2.8212MMscf/ MMscf This calculation was repeated for the HAPs to determine the emission factors. Page 18 Additional Notes: • EF for NOx and CO were from AP-42, Chapter 13, Table 13.5-1 (NOx= 0.068 lb/mmbtu; CO = 0.37 lb/mmbtu) • SO2 emissions are based on the complete conversion of H2s to SO2 • PM10 and PM2.5 based on AP-42 Table 13.5-2 (PM10 and PM2.5=40 ug/I) • It should be noted that the emissions resulting from SO2, PM10 and PM2.5 are below APEN reporting thresholds. The emissions resulting from NOx and CO were calculated using the following equation: EF,lb \*/Gas Heating alue,Btu\*/ 1MMBtu `*(1,000,000 s year */flow rate,MMscf\*/ 1ton ) Emissions,tpy= IMMBtu) l scf ) 11,000,000BTU) l 1MMsc ) ` ) 12000lbs) Example Calcuation: /0.068 lb\ (2,91tu\ / 1MMBtu \ (1,000,000 cf\ (2. Mscf\ / lton \ NOx = MMBtu *ll scf )*(1,000,000BTU)*ll 1MMscf ))*ll year )*(200016s) — 0.3 tpy This calculation was repeated for the CO emissions. APEN Redlines: 1. During the analysis of this point, it was observed that the weight%taken from ProMax were obtained from the incorrect outlet stream for the calculations. The weight% values were initially taken from the W&B gas column when they should have been taken from the VRT gas stream. This information was expressed to the operator. The operator agreed that the initial values used were incorrect. The APEN was updated to reflect the weight% values from the VRT gas stream generated by ProMax. The resulting emissions and emission factors were updated as well. 2. When the operator submitted an updated calculation sheet, they also updated the waste gas heat content value to reflect the ProMax value for the VRT gas stream. This value is 2,915 BTU/scf. This value is slightly more conservative than the originally reported value of 2,822 BTU/scf. As a result, the change was accepted. Permit Updates/Notes: 1. The draft permit was submitted to the operator for comment. The operator did not have any comments on the draft permit. AIRS Point 014 Emergency Flare **Please see excel workbook named 14WE1822-014.CP1 for calculations and notes regarding this point. Permit Notes/Updates: 1. The draft permit was submitted to the operator for comment. The operator did not have any comments on the draft permit. Page 19 Seven(7)low-pressure gas/oil separators controlled by four(4)enclosed flares when gas compressors are down.Flare has a minimum control efficiency of 95%. Equipment Description This source vents natural gas from: a well head separator Emissions from this source are: routed to a flare Natural gas venting from a well head separator.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 Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas*MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm Throughput(Q) 4.6 MMscf/yr 3500.761035 scf/hr MW 33.7 Ib/Ib-mol 0.084018265 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 3.01 44.01 1.323 0.039 12.22 16054.13 8.03 N2 0.23 28.013 0.063 0.002 0.59 769.76 0.38 methane 37.84 16.041 6.070 0.180 56.07 73670.62 36.84 ethane 21.45 30.063 6.449 0.191 59.57 78277.14 39.14 propane 21.73 44.092 9.580 0.284 88.49 116271.74 58.14 isobutane 2.44 58.118 1.417 0.042 13.09 17203.76 8.60 n-butane 7.86 58.118 4.567 0.136 42.19 55436.60 27.72 isopentane 1.47 72.114 1.058 0.031 9.78 12846.22 6.42 n-pentane 1.89 72.114 1.364 0.040 12.60 16552.96 8.28 cyclopentane 0.21 70.13 0.147 0.004 1.36 1787.48 0.89 n-Hexane 0.47 86.18 0.409 0.012 3.78 4962.15 2.48 cyclohexane 0.20 84.16 0.172 0.005 1.59 2091.96 1.05 Other hexanes 0.63 86.18 0.539 0.016 4.98 6538.45 3.27 heptanes 0.14 100.21 0.141 0.004 1.30 1707.64 0.85 methylcyclohexane 0.12 98.19 0.116 0.003 1.07 1408.65 0.70 224-TMP 0.05 114.23 0.061 0.002 0.56 740.36 0.37 Benzene 0.08 78.12 0.060 0.002 0.55 725.34 0.36 Toluene 0.06 92.15 0.056 0.002 0.51 674.42 0.34 Ethylbenzene 0.02 106.17 0.016 0.000 0.15 199.73 0.10 Xylenes 0.02 106.17 0.025 0.001 0.24 309.27 0.15 C8+Heavies 0.06 117.4406022 0.066 0.002 0.61 795.37 0.40 VOC mass fraci 0.587 Total VOC(Uncontrolled) 120.13 MW 33.700 Notes Mole%,MW,and mass fractions from Pronghorn D-9 VRU Inlet gas analysis collected 10/08/14. Emissions are based on 1,314 hours of operation per year. I calculated the average MW of C8+based on the average MW on the analysis for the gas. 14WE1822-012.CP1.xlsm Seven(7)low-pressure gas/oil separators controlled by four(4)enclosed flares when gas compressors are down.Flare has a minimum control efficiency of 95%. Flaring Information Equipment Description Four(4)Flares to combust low-pressure separator gas when gas compressors are down. Manufacturer Leed Model L30-0011 Serial Number 24156;24515;24518;24277 Gas Heating Value 1895 Btu/scf Throughput 8717 MMBtu/yr VRU Information Equipment Description N/A Make _ N/A Model N/A Requested Control N/A Annual Bypass Tim N/A Backup Flare Overall Control 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.07 IIb NOX/MMBtu 0.37 lib CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 52229 lb/MMscf 2611.44 lb/MMscf 120.1 tpy 6.0 tpy Gas Analysis Nox 0.07 lb/MMBTU 0.07 Ib/MMBTU 0.3 tpy 0.3 tpy AP-42 CO 0.37 lb/MMBTU 0.37 lb/MMBTU 1.6 tpy 1.6 tpy AP-42 Benzene 157.68 lb/MMscf 7.88 lb/MMscf 725 lb/yr 36 lb/yr Gas Analysis n-Hexane 1078.73 lb/MMscf 53.9364 lb/MMscf 4962 lb/yr 248 lb/yr Gas Analysis Toluene 146.613 lb/MMscf 7.3307 lb/MMscf 674 lb/yr 34 lb/yr Gas Analysis Xylenes 67.232 lb/MMscf 3.3616 lb/MMscf 309 lb/yr 15 lb/yr Gas Analysis Ethylbenzene 43.420 lb/MMscf 2.1710 lb/MMscf 200 lb/yr 10 lb/yr Gas Analysis 2,2,4 TMP 160.947 lb/MMscf 8.0473 lb/MMscf 740 lb/yr 37 lb/yr Gas Analysis Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' AQCC Regulation 2 Section I.A applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air." AQCC Regulation 7 Was the well newly constructed,hydraulically fractured,or recompleted on or after August 1,2014? yes This separator is subject to Reg 7,Section XVII.G.and control requirements of Reg 7,Section XVII.B.2 14W E1822-012.CP1.xlsm One emergency flare with a minimum combustion efficiency of 95%. The flare is not enclosed.The 014 emergency flare is used during periods when the pipeline is not available.Flare has not yet been installed 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 Natural 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 a fl. 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 Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas*MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm Throughput(Q) 10 MMscf/yr 1141.552511 scf/hr MW 23.5 lb/lb-mol 0.02739726 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 2.45 44.01 1.077 0.046 3.24 28414.90 14.21 N2 0.80 28.013 0.224 0.010 0.67 5901.95 2.95 methane 70.44 16.041 11.300 0.481 34.03 298144.21 149.07 ethane 12.66 30.063 3.807 0.162 11.47 100436.60 50.22 propane 8.47 44.092 3.733 0.159 11.24 98497.34 49.25 isobutane 0.85 58.118 0.495 0.021 1.49 13052.78 6.53 n-butane 2.68 58.118 1.556 0.066 4.69 41044.50 20.52 isopentane 0.48 72.114 0.347 0.015 1.05 9161.71 4.58 n-pentane 0.61 72.114 0.439 0.019 1.32 11576.29 5.79 cyclopentane 0.06 70.13 0.042 0.002 0.13 1100.99 0.55 n-Hexane 0.13 86.18 0.112 0.005 0.34 2942.40 1.47 cyclohexane 0.05 84.16 0.042 0.002 0.13 1103.63 0.55 Other hexanes 0.18 86.18 0.158 0.007 0.47 4156.65 2.08 heptanes 0.04 100.21 0.035 0.001 0.11 928.07 0.46 methylcyclohexane 0.03 98.19 0.030 0.001 0.09 795.36 0.40 224-TMP 0.01 114.23 0.016 0.001 0.05 412.92 0.21 Benzene 0.02 78.12 0.016 0.001 0.05 410.18 0.21 Toluene 0.02 92.15 0.015 0.001 0.04 384.16 0.19 Ethylbenzene 0.00 106.17 0.005 0.000 0.02 134.46 0.07 Xylenes 0.01 106.17 0.009 0.000 0.03 235.31 0.12 C8+Heavies 0.02 114.23 0.019 0.001 0.06 494.29 0.25 VOC mass fraci 0.301 Total VOC(Uncontrolled) 93.22 Notes Mole%,MW,and mass fractions based on weighted average of gas analysis collected 10/07/14 from four separate wells at the Pronghorn D-9 Facility. The wells included in the analysis are as follow:Pronghorn 13-43-9HNB,Pronghorn C-W-9HNB,Pronghorn D-X-9HNB,and Pronghorn A-E-16HNB Emissions are based on 8760 hours of operation per year. The average MW of C8+heavies is based on the value provided by the operator based on the weighted average of the fuel/sales gas. 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 Therefore,the value provided by the operator was used. 14WE1822-014.CP1.xlsm E1822-014.CP1.xlsm One emergency flare with a minimum combustion efficiency of 95%. The flare is not enclosed.The 014 emergency flare is used during periods when the pipeline is not available.Flare has not yet been installed Flaring Information Equipment Description Flare to combust produced gas when pipeline is not available or during emergencies at this wellhead facility. Manufacturer TBD Model TBD Serial Number TBD Gas Heating Value 1340 Btu/scf Throughput 13400 MMBtu/yr VRU Information Equipment Description N/A Make N/A Model N/A Requested Control N/A Annual Bypass Tim N/A Backup Flare Overall Control 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.07 IIb NOX/MMBtu 0.37 Ill)CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 18643 lb/MMscf 932.16 lb/MMscf 93.2 tpy 4.7 tpy Gas Analysis Nox 0.07 Ib/MMBTU 0.07 lb/MMBTU 0.5 tpy 0.5 tpy AP-42 CO 0.37 lb/MMBTU 0.37 Ib/MMBTU 2.5 tpy 2.5 tpy AP-42 Benzene 41.02 lb/MMscf 2.05 lb/MMscf 410 lb/yr 21 lb/yr Gas Analysis n-Hexane 294.24 lb/MMscf 14.7120 lb/MMscf 2942 lb/yr 147 lb/yr Gas Analysis Toluene 38.416 lb/MMscf 1.9208 lb/MMscf 384 lb/yr 19 lb/yr Gas Analysis Xylenes 23.531 lb/MMscf 1.1766 lb/MMscf 235 lb/yr 12 lb/yr Gas Analysis Ethylbenzene 13.446 lb/MMscf 0.6723 lb/MMscf 134 lb/yr 7 lb/yr Gas Analysis 2,2,4-TMP 41.292 lb/MMscf 2.0646 lb/MMscf 413 lb/yr 21 lb/yr Gas Analysis Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' 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Oa F W X F -- c o�°' a o � � z > �n cC U A o o o � >- � �'a C - I E&P Storage Tank Air Pollutant Emissions Notice(APEN)Addendum Form' NAG Company Name: Bonanza Creek Energy Operating Company LLC Source Name: Pronghorn D-9 Production Facility(COGCC#436843) Emissions Source AIRS ID2: 123/9D10/d 1O Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05-123-39288 Pronghorn 13-43-9HNB' 05-123-39289 Pronghorn 14-44-9HNB 05-123-39287 Pronghorn C-W-9HNB' 05-123-39286 Pronghorn D-X-9HNB 05-123-39064 State Pronghorn 11-14-16HNB 05-123 39066 State Pronghorn A-E-16HNB. 05-123-36470 State Pronghorn F-J-16HNB ❑ - ❑ - - ❑ Footnotes: Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 Form APCD-212-EP-StorageTank-APEN-Addendum.docx o •� a?1 x R L. h 33 Q3 p3 ❑❑3 p3 ° E z c0 00° a W .�C .�E .X EE Z p U M M M v +•' N C Wp., 00 E •a O 3 0 0 0 0 0 i.. - m cON ON 07 eSy C k. a A a A A A d p ° a+ cl- Jam..,` E M M M .1- C 0 0 0 y V ., aTo R ❑ ❑ ❑ ❑ ❑❑ 7 Cry > cOC U N L E N Oi a c +I. i.+ d N R Q I. 4�U. ,, ...ii •> C y p��.., y d a y :� in C R •C C W w oh "� G7 a E a ;x4 a o 0 0 0 0 ° o = en Z •• o CQ rn o y -0 o H E y Z Z Z Z Z R .� E •ct ,,o, ea °t W < py 14 \ y u L O a' O y 1 1 1 x A a C S" V y y .. 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