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Home My WebLink About20160537.tiff 4 CDPHE COLORADO LI CO , Department of Public r• , Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150OSt RECEIVED PO Box 758 Greeley, CO 80632 FEB 0 4 2016 January 29, 2016 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On February 3, 2016, the Air Pollution Control Division will begin a 30-day public notice period for Bonanza Creek Energy Operating Company LLC - Pronghorn B-24. 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, tf /4 Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure c--41:41-C.) _.V1-el,J CC"--CI,4JL */ 2016-0537 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe I mar n John W. Hickenlooper, Governor i Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer ', „', « x. CD`PHE Air Pollution Control Division s CO Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Bonanza Creek Energy Operating Company LLC - Pronghorn B-24 - Weld County Notice Period Begins: February 3, 2016 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Bonanza Creek Energy Operating Company LLC Facility: Pronghorn B-24 Oil and gas exploration and production facility SWNW Sec 24 T5N R61W Weld County The proposed project or activity is as follows: Source proposes to operate an oil and gas exploration and production facility. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 15WE0715 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Carissa Money Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us 1 I o® COLORADO .�.n,� ;a.xsn u e.m;,n,.rwr ArN CDPHE Construction Permit z CO • Air Pollution Control Division Permit number: 1 5WE071 5 Issuance: 1 Date issued: Issued to: Bonanza Creek Energy Operating Company LLC Facility Name: Pronghorn B-24 Production Facility Plant AIRS ID: 123/9D48 Physical Location: SWNW Section 24, Township 5N, Range 61W County: Weld County General Description: Well Production Facility Equipment or activity subject to this permit: Facility AIRS Equipment Point Equipment Description ID Six (6) 500 bbl above ground atmospheric condensate storage tanks CNDTK-1 005 controlled by four enclosed flares. Each flare has a minimum control efficiency of 95%. One (1) 500 bbl above ground produced water storage tank PW 006 controlled by four enclosed flares. Each flare has a minimum control efficiency of 95%. Hydrocarbon Loadout to Tanker Trucks. Loadout is controlled by TLO 007 using dedicated vapor balance service and four enclosed flares. Collection system is 70% efficient and each flare has a minimum control efficiency of 95%. Overall control efficiency is 66.5% SEP-1 to Two low-pressure separators controlled by four enclosed flares SEP-2 008 during VRU downtime. Each flare has a minimum control efficiency of 95%. One vapor recovery tower (VRT) controlled by four enclosed flares VRT-1 009 during VRU downtime. Each flare has a minimum control efficiency of 95%. One emergency flare used to combust separator gas during FL-2 011 emergencies or when the pipeline is not available. Flare has a minimum control efficiency of 95%. The flare is not enclosed. 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 this Storage Tank Version Syn Minor 2015-1 Page 1 of 16 specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 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. A self certification form and guidance on how to self-certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Regulation Number 3, Part B, Section III.E.) 5. 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 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility AIRS Tons per Year Emission Equipment ID Point PM2.5 NO. VOC CO Type CNDTK-1 005 --- --- 1.3 --- Point PW 006 --- --- 0.7 --- Point TLO 007 --- --- 2.0 --- Point SEP-1 to SEP-2 008 --- --- 1.3 --- Point VRT-1 009 --- --- 1.6 --- Point CDZHE COLORADO CO C Au Pollution Control Division Depot: of A ,c 1 eaItfi it Environment 123/9D48 Page 2 of 16 FL-2 011 --- --- 4.1 2.4 Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Compliance with the annual 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 actual 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. 7. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility AIRS Control Device Pollutants Equipment ID Point Controlled CNDTK-1 005 Enclosed Flare VOC and HAP PW 006 Enclosed Flare VOC and HAP TLO 007 Vapor Balance and Enclosed Flare VOC and HAP SEP-1 to SEP-2 008 Enclosed Flare VOC and HAP VRT-1 009 Enclosed Flare VOC and HAP FL-2 011 Open Flare VOC and HAP PROCESS LIMITATIONS AND RECORDS 8. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point CNDTK-1 005 Condensate throughput 105,120 BBL PW 006 Produced Water Throughput 100,740 BBL TLO 007 Hydrocarbon Loaded 105,120 BBL SEP 1 to SEP-2 008 Total Gas Vented from Both Low-Pressure 1.1 MMSCF Separators during VRU Downtime VRT-1 009 Total Gas Vented from the Vapor Recovery 0.5 MMSCF Tower (VRT) during VRU Downtime FL-2 011 Total Gas Vented from All Separators to Flare 10.0 MMSCF The owner or operator shall monitor monthly process rates based on the calendar month. CDPHE COLORADO CO Au Pollution Control Division E?enar:ne-rt of Piblic l+eatilr ft ImAroninent 123/9D48 Page 3 of 16 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. 9. AIRS Points 008 and 009: The owner or operator shall continuously monitor and record the volumetric flowrate of natural gas vented from all low pressure separators and VRTs during VRU downtime using a flow meter. The flow meter shall continuously measure flowrate and record total volumetric flow vented to the enclosed flares from all low-pressure separators and VRTs during VRU downtime. The owner or operator shall use monthly throughput records and calculation methods detailed in the O&M Plan to demonstrate compliance with the limits specified in Condition 8 and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 11. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. R.4.) 12. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 13. AIRS Point 005: This source is subject to Regulation Number 7, Section XII. The operator shall comply with all applicable requirements of Section XII and, specifically, shall: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for condensate storage tanks; and • Ensure that the combustion device controlling emissions from this storage tank be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. (Regulation Number 7, Section XII.C.) (State only enforceable) 14. AIRS Point 005, 006, 008 and 009: The flare(s) covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). These requirements include, but are not limited to: XVII.B.2.b If a combustion device is used to control emissions of volatile organic compounds to comply with Section VII, it shall be enclosed, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. XVII.B.2.d Auto-igniters: All combustion devices used to control emissions of hydrocarbons must be equipped with and operate an auto-igniter as follows: XVII.B.2.d.(i) All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto-igniter upon installation of the combustion device. C PHE COLORADO CO G Mr Pollution Control Division " DedaOment of f bttc Heait,&Environment 123/9D48 Page 4 of 16 15. AIRS Point 005 and 006: 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) Control requirements of Section XVII.C.1.b. must be achieved within ninety (90) days of the date that the storage tank commences operation. XVII.C.1.d.1 V .C. .d. Beginning May 1, 2014, or the applicable compliance date in Section XVII.C.1.b.(i), whichever comes later, owners or operators of storage tanks subject to Section XVII.C.1. must conduct audio, visual, olfactory ("AVO") and additional visual inspections of the storage tank and any associated equipment (e.g. separator, air pollution control equipment, or other pressure reducing equipment) at the same frequency as liquids are loaded out from the storage tank. These inspections are not required more frequently than every seven (7) days but must be conducted at least every thirty one (31) days. Monitoring is not required for storage tanks or associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section XVII.C.1.e. The additional visual inspections must include, at a minimum: XVII.C.1.d.(i) Visual inspection of any thief hatch, pressure relief valve, or other access point to ensure that they are closed and properly sealed; XVII.C.1.d.(ii) Visual inspection or monitoring of the air pollution control equipment to ensure that it is operating, including that the pilot light is lit on combustion devices used as air pollution control equipment; XVII.C.1.d.(iii) If a combustion device is used, visual inspection of the auto-igniter and valves for piping of gas to the pilot light to ensure they are functioning properly; XVII.C.1.d.(iv) Visual inspection of the air pollution control equipment to ensure that the valves for the piping from the storage tank to the air pollution control equipment are open; and XVII.C.1.d.(v) If a combustion device is used, inspection of the device for the presence or absence of smoke. If smoke is observed, either the equipment must be immediately shut-in to investigate the potential cause for smoke and perform repairs, as necessary, or EPA Method 22 must be conducted to determine whether visible emissions are present for a period of at least one (1) minute in fifteen (15) minutes. XVII.C.1.e. If storage tanks or associated equipment is unsafe, difficult, or inaccessible to monitor, the owner or operator is not required to monitor such equipment until it becomes feasible to do so. XVII.C.2. Capture and monitoring requirements for storage tanks that are fitted with air pollution control equipment as required by Sections XII.D. or XVII.C.1. XVII.C.2.a. Owners or operators of storage tanks must route all hydrocarbon emissions to air pollution control equipment, and must operate without venting hydrocarbon 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 CDPHE COLORADO CO .. Air Pollution Control Division ' C:eoartmentof6* '_wironment 123/9D48 Page 5 of 16 safety of personnel and equipment. Compliance must be achieved in accordance with the schedule in Section XVII.C.2.b.(ii). XVII.C.2.b. Owners or operators of storage tanks subject to the control requirements of Sections XII.D.2., XVII.C.1.a, or XVII.C.1.b. must develop, certify, and implement a documented Storage Tank Emission Management System ("STEM") plan to identify, evaluate, and employ appropriate control technologies, monitoring practices, operational practices, and/or other strategies designed to meet the requirements set forth in Section XVII.C.2.a. Owners or operators must update the STEM plan as necessary to achieve or maintain compliance. Owners or operators are not required to develop and implement STEM for storage tanks containing only stabilized liquids. The minimum elements of STEM are listed below. XVII.C.2.b.(i) STEM must include selected control technologies, monitoring practices, operational practices, and/or other strategies; procedures for evaluating ongoing storage tank emission capture performance; and monitoring in accordance with approved instrument monitoring methods following the applicable schedule in Section XVII.C.2.b.(ii) and Inspection Frequency in Table 1. XVII.C.2.b.(ii) Owners or operators must achieve the requirements of Sections XVII.C.2.a. and XVII.C.2.b. and begin implementing the required approved instrument monitoring method in accordance with the following schedule: XVII.C.2.b.(ii)(a) A storage tank constructed on or after May 1, 2014, must comply with the requirements of Section XVII.C.2.a. by the date the storage tank commences operation. The storage tank must comply with Section XVII.C.2.b. and implement the approved instrument monitoring method inspections within ninety (90) days of the date that the storage tank commences operation. XVII.C.2.b.(ii)(d) Following the first approved instrument monitoring method inspection, owners or operators must continue conducting approved instrument monitoring method inspections in accordance with the Inspection Frequency in Table 1. Table 1 - Storage Tank Inspections Threshold: Storage Tank Approved Instrument Phase-In Schedule Uncontrolled Actual VOC Monitoring Method Emissions (tpy) Inspection Frequency > 6 and < 12 Annually January 1, 2016 > 12 and < 50 Quarterly July 1, 2015 > 50 Monthly January 1, 2015 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 4, CD E COLORADO CO Air Pollution Control Division Department of a.,Wic Health&'Environment 123/9D48 Page 6 of 16 tanks and associated equipment at the facility(ies), including thief hatches and pressure relief devices. XVII.C.3. Recordkeeping XVII.C.3. The owner or operator of each storage tank subject to Sections XII.D. or XVII.C. must maintain records of STEM, if applicable, including the plan, any updates, and the certification, and make them available to the Division upon request. In addition, for a period of two (2) years, the owner or operator must maintain records of any required monitoring and make them available to the Division upon request, including: XVII.C.3.a. The AIRS ID for the storage tank. XVII.C.3.b. The date and duration of any period where the thief hatch, pressure relief device, or other access point are found to be venting hydrocarbon emissions, except for venting that is reasonably required for maintenance, gauging, or safety of personnel and equipment. XVII.C.3.c. The date and duration of any period where the air pollution control equipment is not operating. XVII.C.3.d. Where a combustion device is being used, the date and result of any EPA Method 22 test or investigation pursuant to Section XVII.C.1.d.(v). XVII.C.3.e. The timing of and efforts made to eliminate venting, restore operation of air pollution control equipment, and mitigate visible emissions. XVII.C.3.f. A list of equipment associated with the storage tank that is designated as unsafe, difficult, or inaccessible to monitor, as described in Section XVII.C.1.e., an explanation stating why the equipment is so designated, and the plan for monitoring such equipment. 16. AIRS Point 007: 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) 17. AIRS Point 007: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations on site at the time of the inspection to ensure compliance with the conditions (a) and (b) above. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 18. AIRS Point 007: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 19. AIRS Point 008, 009 and 011: 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 CDPHE COLORADO CO e Air Pollution Control Division Dooartme^t of fa.ibiici+.rsf'z r.'_,ironrvfot 123/9D48 Page 7 of 16 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. 20. AIRS Point 011: The emergency flare, which receives gas from the separators during emergencies, is an approved alternative emissions control equipment per Regulation No. 7, Section XVII.B.2.e. The emergency flare shall comply with all applicable requirements in Regulation No. 7, Section XVII.B General Provisions (State only enforceable), except the flare is not required to be enclosed. OPERATING£t MAINTENANCE REQUIREMENTS 21. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEM) 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 the O£tM plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) 22. AIRS Point 007: 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 shalt be weighted and properly seated. f. Inspectpressure relief devices (PRD) annually for proper operation and replace as P� P P P P 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 23. AIRS Points 005, 006, 008, and 009: The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, 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 minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.16) 24. AIRS Point 009: The operator shall complete an initial site specific extended gas analysis of the gas vented from the VRT in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream. Results of testing shall be used to calculate site-specific emission factors for the pollutants referenced above (in units of lb/MMSCF gas vented) using Division approved methods. Results of site-specific sampling and emissions factor analysis shall be submitted to the Division as part CDPHE COLORADO Co 4 Air Pollution Control Division Department of a_ibtic Health&Ewronment 123/9D48 Page 8 of 16 of the self-certification and demonstrate the emissions factors established through this initial testing are less than or equal to, the emissions factors established in the permit application and "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this sampling and analysis is greater than the emissions factors established in the permit application and "Notes to Permit Holder", the operator shall submit to the Division within 60 days a request for permit modification to update emissions factors and emissions limits specified in this permit. 25. AIRS Point 011: The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions when the flare is receiving gas from the separator. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.16) ADDITIONAL REQUIREMENTS 26. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOx) in ozone nonattainment areas emitting less than 100 tons of VOC or NOx 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. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 27. 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 Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS COPHE COLORADO CO ex Air Pollution Control Division nacr,enta,1.,bhc,,. <<:nr.Pnvron,nent 123/9D48 Page 9 of 16 28. 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 Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 29. 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 Number 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. 30. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 31. 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. 32. 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 ob initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 33. 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. 34. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Carissa Money Permit Engineer Permit History 4 cote COLORADO CO • Air Pollution Control Division Denartmem of Pink' £.Enviro ment 123/9D48 Page 10 of 16 Issuance Date Description Issuance 1 This Issuance Issued to Bonanza Creek Energy Operating Company LLC CDPHE COLORADO co .0 Air Pollution Control Division Of•oaf.ment of P.Ibi,.-:,,,�-,Fr'_rtv,roro>,mn, 123/9D48 Page 11 of 16 Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-reps 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Rate Point Pollutant CAS# (lb/yr) reportable? (lb/yr) Benzene 71432 353 Yes 18 n-Hexane 110543 2,934 Yes 147 005 Toluene 108883 302 Yes 15 Ethylbenzene 100414 24 No 1 Xylenes 1330207 123 No 6 Benzene 71432 705 Yes 35 006 n-Hexane 110543 2,216 Yes 111 Benzene 71432 70 No 24 n-Hexane 110543 630 ' Yes 211 007 Toluene 108883 47 No 16 Ethylbenzene 100414 4 No 1 Xylenes 1330207 15 No 5 Benzene 71432 96 No 5 n-Hexane 110543 408 Yes 20 008 Toluene 108883 68 No 3 Ethylbenzene 100414 12 No 1 Xylenes 1330207 52 No 3 A C��e COLORADO CO G Air Pollution Control Division Deoartntent of P'Mc Health&Environment 123/9D48 Page 12 of 16 Benzene 71432 677 Yes 34 n-Hexane 110543 5,591 Yes 280 Toluene 108883 567 Yes 28 009 Ethylbenzene 100414 44 No 2 Xylenes 1330207 221 No 11 2,2,4- 540841 348 Yes 17 Trimethylpentane Benzene 71432 435 Yes 22 n-Hexane 110543 2,413 Yes 121 011 Toluene 108883 406 Yes 20 Ethylbenzene 100414 64 No 3 Xylenes 1330207 148 No 7 Note: All non-criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 005: Uncontrolled Controlled CAS# Pollutant Emission Factors Emission Factors Source lb/bbl lb/bbl N0x 0.0011 0.0011 AP-42, Table 13.5-1 CO 0.0059 0.0059 AP-42, Table 13.5-1 V0C 0.4865 0.0243 Promax 110543 n-Hexane 0.0279 0.0014 Promax 71432 Benzene 0.0034 0.0002 Promax 108883 Toluene 0.0029 0.0001 Promax 100414 Ethylbenzene 0.0002 0.00001 Promax 1330207 Xylenes 0.0012 0.00006 Promax Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Point 006: Uncontrolled Controlled CAS# Pollutant Emission Factors Emission Factors Source lb/bbl lb/bbl V0C 0.262 0.0131 CDPHE 110543 n-Hexane 0.022 0.0011 CDPHE 71432 Benzene 0.007 0.0004 CDPHE Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Point 007: Uncontrolled Controlled CAS# Pollutant Emission Factors Emission Factors Source lb/bbl lb/bbl V0C 0.1153 0.0386 Promax 110543 n-Hexane 0.0060 0.0020 Promax * COPHE COLORADO CO � Air Pollution Control Division i 123/9D48 Page 13 of 16 Uncontrolled Controlled CAS# Pollutant Emission Factors Emission Factors Source lb/bbl lb/bbl 71432 Benzene 0.0007 0.0002 Promax 108883 Toluene 0.0004 0.0002 Promax 100414 Ethylbenzene 0.00003 0.00001 Promax • 1330207 Xylenes 0.0001 0.00005 Promax Note: The controlled emissions factors for this point are based on a collection efficiency of 70% and flare control efficiency of 95%for an overall control efficiency of 66.5%. The uncontrolled V0C emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L= 12.46*S*P*M/T S = 1 (Submerged loading: dedicated vapor balance service) P (true vapor pressure) = 3.47 psia M (vapor molecular weight) =42.03 lb/lb-mol T (temperature of liquid loaded) = 524 °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the stable condensate by the V0C emission factor. Point 008: Weight Uncontrolled Controlled Fraction of Emission CAS# Pollutant Gas (%) Factors Emission Source lb/bbl Factors lb/bbl N0x 0.068 0.068 AP-42 CO 0.37 0.37 AP-42 V0C 53.8 45,003 2,250.1 Gas Analysis 71432 Benzene 0.10 83.891 4.1946 Gas Analysis 108883 Toluene 0.07 59.569 2.9785 Gas Analysis 100414 Ethylbenzene 0.01 10.925 0.5463 Gas Analysis 1330207 Xylenes 0.05 45.942 2.2971 Gas Analysis 110543 n-Hexane 0.43 357.68 17.884 Gas Analysis Note: The uncontrolled V0C and HAP emissions were calculated using a site-specific low pressure separator gas sample collected 3/16/2015 from VRU at Pronghorn 11/41/24HN to estimate the V0C and HAP content of the stream and a Promax model to estimate stream flow. Emission factors for CO and N0x are based on AP-42 Table 13.5-1. A HHV of 1,766 BTU/scf was used for calculations. The controlled emissions factors for this point are based on the flare control efficiency of 95%. Point 009: Weight Uncontrolled Controlled CAS# Pollutant Fraction of Emission Emission Source Gas (%) Factors Factors lb/bbl lb/bbl N0x 0.068 0.068 AP-42 CO 0.37 0.37 AP-42 V0C 88.9 132,857 6,642.8 Gas Analysis 71432 Benzene 0.93 1,393.8 69.690 Gas Analysis 108883 Toluene 0.78 1,167.5 58.377 Gas Analysis COPHE COLORADO CO C Air Pollution Control Division '.. Dea mwm of P,bic Hea!lh&E' roninene 123/9D48 Page 14 of 16 Weight Uncontrolled Controlled CAS# Pollutant Fraction of Emission Emission Source Gas (%) Factors Factors lb/bbl lb/bbl 100414 Ethylbenzene 0.06 91.059 4.5529 Gas Analysis 1330207 Xylenes 0.31 455.84 22.792 Gas Analysis 110543 n-Hexane 7.71 11,515 575.77 Gas Analysis 540841 2'2'4 0.48 715.88 35.794 Gas Analysis trimethylpentane Note: The uncontrolled VOC and HAP emissions were calculated based on a Promax model to estimate the VOC and HAP content of the stream and stream flow. Emission factors for CO and NOx are based on AP-42 Table 13.5-1. A HHV 3,120 BTU/scf was used for calculations. The controlled emissions factors for this point are based on the flare control efficiency of 95%. Point 011: Weight Uncontrolled Controlled CAS# Pollutant Fraction of Emission Emission Source Gas (h) Factors Factors lb/bbl lb/bbl NOx 0.068 0.068 AP-42 CO 0.37 0.37 AP-42 VOC 27.4 16,389 819.46 Gas Analysis 71432 Benzene 0.07 43.492 2.1746 Gas Analysis 108883 Toluene 0.07 40.604 2.0302 Gas Analysis 100414 Ethylbenzene 0.01 6.4430 0.3222 Gas Analysis 1330207 Xylenes 0.02 14.847 0.7423 Gas Analysis 110543 n-Hexane 0.40 241.26 12.063 Gas Analysis Note: Emission factors for CO and NOx are based on AP-42 Table 13.5-1. A HHV of 1,295 BTU/scf was used for calculations. The controlled emissions factors for this point are based on the flare control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC NANSR Synthetic Minor Source of: VOC 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ CDPHE COLORADO CO If Air Pollution Control Division ' 1 23/9D48 Page 15 of 16 Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A- Subpart KKKK NSPS Part 60, Appendixes Appendix A-Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories- MACT 63.1-63.599 Subpart A- Subpart Z MACT 63.600-63.1199 Subpart AA- Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ- Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ -Subpart MMMMM MACT 63.8980-End Subpart NNNNN - Subpart XXXXXX C e COLORADO CO e Air Pollution Control Division De arment of Public Health&Environment - 123/9D48 Page 16 of 16 Division Information Engineer: Carissa Money Control Engineer: NA Review Date: 12/31/2015 Application Date: 09/23/2015 Facility Identifiers Permit No. 15WE0715 Potentially located in ozone nonattainment area AIRS County# 123 'Weld Facility# 9D48 Facility Type: exploration and production facility ❑� Located in the 8-hour non-attainment area? 0 True Minor 0 Synthetic Minor for: VOC r NOx r CO Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: Pronghorn B-24 Production Facility Source Location: SWNW Section 24, Township 5N, Range 61W SIC: 1311 Address 1: Bonanza Creek Energy Operating Company LLC Mailing Address 2: 410 17th Street, Suite 1400 Address ty,State Zip: Denver,CO 80202 Name: Jerry Dismukes Person To Phone: 303-803-1724 Contact Fax: 720-279-2331 Email: idismukes@bonanzacrk.com 'Requested Action Self Certification Required? Yes Issuance Number: 1 Source Description: Oil and gas exploration and production facility known as the Pronghorn B-24 Production Facility, located in the SWNW Section 24,Township 5N, Range 61W,Weld County, Colorado. Point Name Type - Control Action 005 CNDTK-1 Condensate Tanks Flare Newly reported source 006 PW Water Tanks _ Flare Newly reported source 007 TLO Loadout Flare Newly reported source 008 SEP-1 to Separator Venting Flare Newly reported source-Venting of Low SEP-2 Pressure Separators to Flare during VRU 009 VRT-1 Separator Venting Flare Newly reported source-Venting of VRT to flare during VRU downtime 011 FL-2 Separator Venting Flare Newly reported source-emergency flare to route sales gas when pipeline not available *Pt 001 and 002 are engines covered by GP02. *Pts 003 and 004 are categorically permit-exempt engines *Note that Pt 010 was for a temporary flare that was removed 1/28/2015. Six(6)500 bbl above ground atmospheric condensate storage tanks controlled by four 005 enclosed flares.Each flare has a minimum control efficiency of 95%. Requsted Throughput 105120 bbl Control Flare Efficiency 95.00%I Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.4865 lb/bbl 25.6 tpy 1.3 tpy Promax Benzene 0.0034 lb/bbl 353 lb/yr 18 lb/yr Promax n-Hexane 0.0279 lb/bbl 2,934 lb/yr 147 lb/yr Promax Toluene 0.0029 lb/bbl 302 lb/yr 15 lb/yr Promax Ethylbenze 0.0002 lb/bbl 24 lb/yr 1 lb/yr Promax Xylenes 0.0012 lb/bbl 123 lb/yr 6 lb/yr Promax 224-TMP 0.0023 lb/bbl 238 lb/yr 12 lb/yr Promax Nox 0.068 lb/Mmbtu 0.06 tpy 0.1 tpy AP-42 Table 1 CO 0.37 lb/Mmbtu 0.31 tpy 0.3 tpy AP-42 Table 1 Regulatory Review Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20%opacity.This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes.The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR, Part 60, Appendix A(July, 1992))in all subsections of Section II.A and B of this regulation. Re ulation 2-Odor Section I.A-No person,wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air. Regulation 6-`'`New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. The 500 bbl tanks are above the minimum capacity threshold of-471 bbl. However,the tanks are located at the wellhead site, store condensate,and are prior to custody transfer;thus,the tanks are exempt from NSPS Kb (60.110b(d)(4)) . NSPS OOOO:for storage vessels in the natural gas production,transmission,and processing segments. This source is not subject because each tank emits less than 6 tpy VOC. Regulation 7 Volatile Organic Compounds XII.VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS Applicant is subject to the emission control requirements for condensate tanks since it is located in the nonattainment area. XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... Applicant is currently subject to this requirement since actual uncontrolled emissions are greater than 6 tpy. Tanks were constructed after 5/1/2014. 15WE0715.CP1.xlsm One(1)500 bbl above ground produced water storage tank controlled by four 006 enclosed flares. Each flare has a minimum control efficiency of 95%. Emissions Calculations Requsted Throughput 100740 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source V0C 0.262 lb/bbl 13.2 tpy 0.7 tpy CDPHE Benzene 0.007 lb/bbl 705 lb/yr 35 lb/yr CDPHE n-Hexane 0.022 lb/bbl 2216 lb/yr 111 lb/yr CDPHE Regulatory Review Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR, Part 60, Appendix A(July, 1992)) in all subsections of Section II. A and B of this regulation. Regulation 2—Odor Section I.A-No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 7-Volatile Organic Compounds XVII.C.1.b Applicant is subject since actual uncontrolled emissions are greater than 6 tpy. The storage tank was constructed after 5/1/2014. 15WE0715.CP1.xlsm Hydrocarbon Loadout to Tanker Trucks.Loadout is controlled by using dedicated vapor balance service and four enclosed flares.Collection system is 70%efficient and each flare has a 007 minimum control efficiency of 95%.Overall control efficiency is 66.5% Calculations L=12.46*S*P*M/T(AP-42:Chapter 5.2,Equation 1) L=loading losses in lb per 1000 gallons loaded Factor Meaning Value Units Source 5 Saturation Factor 1 AP-42 factor for submerged loading,dedicated va P True Vapor Pressure 3.47 psia Calculated TVP of liquid based on oil analysis and M Molecular Weight of Var 42.03 lb/lb-mole Calculated MW of liquid based on oil analysis and T Liquid Temperature 523.67 deg.R EPA Tanks Met Data for Denver,CO L 2.75 lb/10^3 gal 1.15E-01 lb/bbl Annual requested Throughput 105120 BBL/yr 4415040 gal/yr Annual requested VOC emissions 12125 lb/yr 6.06 tpy Control: Flare Efficiency: 66.50% Source assumes 95%control efficiency and 70%collection efficiency NCRPs Component Mass Fraction VOC 0.791403 Benzene 0.0058 n-hexane 0.0519 Toluene 0.0039 Ethylbenzeni 0.0003 Xylenes 0.0012 Source: Sales oil composition and Eq 1-22 of AP-42 Ch 7 Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.1153 lb/bbl 6.1 tpy 2.0 tpy AP-42 Benzene 0.0007 lb/bbl 70.3 lb/yr 23.6 lb/yr AP-42 n-Hexane 0.0060 lb/bbl 630 lb/yr 211 lb/yr AP-42 Toluene 0.0004 lb/bbl 47 lb/yr 16 lb/yr AP-42 Ethylbenzeni 0.00003 lb/bbl 4 lb/yr 1 lb/yr AP-42 Xylenes 0.0001 lb/bbl 15 lb/yr 5 lb/yr AP-42 Regulatory Review Reaulatton 3-APEN and Permitting Requirements Is this site considered an exploration and production location(e.g.well pad)? Yes If yes,review the following two exemptions for applicability: • Does the operator unload has than 10,000 gallons(238 BBLs)per day of crude oil on an annual average basis? No If yes,this emissions point is categorically exempt from permit requirements per Regulation 3,Part B,Section II.D.1.1 Does this operator unload less than 6,750 bbls per year of condensate via splash fill or 16,308 bbls per year of condensate via submerged fill procedure? No If yes,this emissions point is categorically exempt from permit requirements per Regulation 3,Part B,Section 11.0.1.1 15WE0715.CP1.xlsm Two low-pressure separators controlled by four enclosed flares during VRU downtime.Each flare has a 008 minimum control efficiency of 95%. Equipment Description This source vents natural gas from: low-pressure separators during VRU downtime Emissions from this source are: routed to a flare I Natural gas venting from low-pressure separators during VRU downtime.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 0.000723958 Throughput(Q) 1.141540128 MMscf/yr 130.3128 scf/hr MW 31.7 Ib/Ib-mol 0.003127507 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 3.88 44.01 1.708 0.054 0.59 5143.22 2.57 N2 0.18 28.013 0.050 0.002 0.02 151.87 0.08 methane 43.11 16.041 6.916 0.218 2.38 20829.97 10.41 ethane 19.81 30.063 5.955 0.188 2.05 17936.52 8.97 propane 20.45 44.092 9.018 0.284 3.10 27161.91 13.58 isobutane 2.14 58.118 1.246 0.039 0.43 3752.55 1.88 n-butane 6.97 58.118 4.053 0.128 1.39 12208.53 6.10 isopentane 1.07 72.114 0.774 0.024 0.27 2331.05 1.17 n-pentane 1.22 72.114 0.883 0.028 0.30 2659.47 1.33 cyclopentane 0.10 70.13 0.068 0.002 0.02 203.41 0.10 n-Hexane 0.16 86.18 0.136 0.0043 0.05 408.31 0.20 cyclohexane 0.04 84.16 0.034 0.001 0.01 102.66 0.05 Other hexanes 0.31 86.18 0.270 0.009 0.09 813.50 0.41 heptanes 0.12 100.21 0.122 0.004 0.04 366.12 0.18 methylcyclohexane 0.03 98.19 0.033 0.001 0.01 99.67 0.05 224-TMP 0.00 114.23 0.001 0.0000 0.00 4.47 0.00 Benzene 0.04 78.12 0.032 0.0010 0.01 95.77 0.05 Toluene 0.02 92.15 0.023 0.0007 0.01 68.00 0.03 Ethylbenzene 0.00 106.17 0.004 0.0001 0.00 12.47 0.01 Xylenes 0.02 106.17 0.017 0.0005 0.01 52.44 0.03 C8+Heavies 0.28 122 0.343 0.011 0.12 1031.83 0.52 VOC mass fracl 0.538 Total VOC(Uncontrolled) 25.69 Notes Mole%,MW,and mass fractions are based on site-specific sample of LP gas collected 3/16/2015 at VRU at Pronghorn 11-41-24HNC Emissions are based on 1,314 hours of VRU downtime. Flowrate of LP gas is based on Promax model plus 20%safety factor. 15WE0715.CP1.xlsm • Two low-pressure separators controlled by four enclosed flares during VRU downtime. Each flare has a 008 minimum control efficiency of 95%. Flaring Information Equipment Description Flare to combust low-pressure separator gas during VRU downtime. Manufacturer Leed Model L30-0011 Serial Number 23392, 24519, 24028, 24027 Gas Heating Value 1766 Btu/scf Throughput 2015.959866 MMBtu/yr VRU Information-NOT APPLICABLE Equipment Description Engine to recompress low-pressure separator gas to sales line. The VRU is considered part of the process and not included a: Make Model Requested Control Efficiency Annual Bypass Time Backup I Flare Overall Control 95.00% Combustion emission factor source: AP-42: Chapter 13.5 0.07 Ilb NOX/MMBtu 0.37 Ilb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Er VOC 45003 lb/MMscf 2250.1 Ib/MMscf 25.7 tpy 1 Nox 0.07 lb/MMBTU 0.07 lb/MMBTU 0.1 tpy C CO 0.37 lb/MMBTU 0.37 lb/MMBTU 0.4 tpy C Benzene 83.891 lb/MMscf 4.1946 lb/MMscf 96 lb/yr n-Hexane 357.68 lb/MMscf 17.884 lb/MMscf 408 lb/yr Toluene 59.569 lb/MMscf 2.9785 lb/MMscf 68 lb/yr Ethylbenzene 10.925 Ib/MMscf 0.5463 lb/MMscf 12 lb/yr Xylenes 45.942 lb/MMscf 2.2971 lb/MMscf 52 lb/yr 224-TMP 3.9182 lb/MMscf 0.1959 lb/MMscf 4 lb/yr 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 othe 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 One vapor recovery tower(VRT) controlled by four enclosed flares during VRU downtime. Each flare has 009 control efficiency of 95%. Equipment Description This source vents natural gas from: vapor recovery tower when the VRU is down Emissions from this source are: routed to a flare I Natural gas venting from vapor recovery tower when the VRU is down. Emissions from this source are routed to a flare. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10- Displacement Equation (10.4-3) Ex=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) 0.48555585 MMscf/yr 55.42875 scf/hr MW 56.6319 Ib/Ib-mol 0.00133029 MMscf/d mole% MW lbx/Ibmol mass fraction lb/hr lb/yr tpy Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0. CO2 1.59 44.01 0.699 0.012 0.10 895.94 0. N2 0.30 28.013 0.085 0.002 0.01 109.09 0. methane 7.18 16.041 1.152 0.020 0.17 1475.91 0. ethane 14.44 30.063 4.343 0.077 0.64 5563.41 2. propane 26.31 44.092 11.599 0.205 1.70 14860.03 7. isobutane 3.45 58.118 2.005 0.035 0.29 2568.31 1. n-butane 13.20 58.118 7.670 0.135 1.12 9826.95 4. isopentane 2.74 72.114 1.975 0.035 0.29 2530.34 1. n-pentane 3.51 72.114 2.531 0.045 0.37 3242.34 1. cyclopentane 1.77 70.13 1.240 0.022 0.18 1588.92 0. n-Hexane 5.06 86.18 4.364 0.0771 0.64 5591.41 2. cyclohexane 1.65 84.16 1.388 0.025 0.20 1777.61 0. Other hexanes 10.08 86.18 8.686 0.153 1.27 11127.62 5. heptanes 4.02 100.21 4.030 0.071 0.59 5162.89 2. methylcyclohexane 1.50 98.19 1.468 0.026 0.21 1881.29 0. 224-TMP 0.24 114.23 0.271 0.0048 0.04 347.60 0. Benzene 0.68 78.12 0.528 0.0093 0.08 676.77 0. Toluene 0.48 92.15 0.442 0.0078 0.06 566.90 0. Ethylbenzene 0.03 106.17 0.035 0.0006 0.01 44.21 0. Xylenes 0.16 106.17 0.173 0.0031 0.03 221.34 0. C8+Heavies 1.61 120.7645766 1.948 0.034 0.28 2495.09 1. VOC mass fracl 0.889 Total VOC(Uncontrolled) 32. Notes Mole%, MW, and mass fractions are based on a Promax model Emissions are based on 1,314 hours of VRU downtime. Flowrate of VRT gas is based on Promax model plus 20% safety factor. One vapor recovery tower(VRT)controlled by four enclosed flares during VRU downtime. Each flare has 009 control efficiency of 95%. Flaring Information Equipment Description Flare to combust VRT gas during VRU downtime. Manufacturer Leed Model L30-0011 Serial Number 23392, 24519, 24028, 24027 Gas Heating Value 3120 Btu/scf Throughput 1514.934252 MMBtu/yr VRU Information-NOT APPLICABLE Equipment Description Engine to recompress low-pressure separator gas to sales line. The VRU is considered part of the process and not included a: Make Model Requested Control Efficiency Annual Bypass Time Backup I Flare Overall Control 95.00% Combustion emission factor source: AP-42: Chapter 13.5 0.07 llb NOX/MMBtu 0.37 Ilb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Er VOC 132857 lb/MMscf 6642.9 Ib/MMscf 32.3 tpy 1 Nox 0.07 lb/MMBTU 0.07 lb/MMBTU 0.1 tpy CO 0.37 Ib/MMBTU 0.37 lb/MMBTU 0.3 tpy Benzene 1393.80 lb/MMscf 69.690 lb/MMscf 677 lb/yr n-Hexane 11515 lb/MMscf 575.77 Ib/MMscf 5591 lb/yr 2 Toluene 1167.5 lb/MMscf 58.377 lb/MMscf 567 lb/yr Ethylbenzene 91.059Ib/MMscf 4.5529 lb/MMscf 44 lb/yr Xylenes 455.84 lb/MMscf 22.792 lb/MMscf 221 lb/yr 224-TMP 715.88 lb/MMscf 35.794 lb/MMscf 348 lb/yr 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 othe 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 One emergency flare used to combust separator gas during emergencies or when the pipeline is not 011 available. Flare has a minimum control efficiency of 95%. The flare is not enclosed. Equipment Description This source vents natural gas from: a well head separator when the sales gas pipeline is not available or during emergenci Emissions from this source are: routed to a flare I Natural gas venting from a well head separator when the sales gas pipeline is not available or during emergencies. Emissions Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10- Displacement Equation (10.4-3) Ex= Q* MW*Xx/C Ex= emissions of pollutant x Q =Volumetric flow rate/volume of gas processed MW= Molecular weight of gas= SG of gas* MW of air Xx= mass fraction of x in gas C = molar volume of ideal gas (379 scf/Ib-mol) at 60F and 1 atm Throughput(Q) 10 MMscf/yr 1141.552511 scf/hr MW 22.7 Ib/Ib-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. CO2 2.48 44.01 1.092 0.048 3.29 28810.87 14. N2 0.90 28.013 0.251 0.011 0.76 6634.42 3. methane 73.78 16.041 11.835 0.521 35.65 312260.29 156. ethane 10.98 30.063 3.300 0.145 9.94 87077.20 43. propane 7.41 44.092 3.265 0.144 9.83 86152.74 43. isobutane 0.70 58.118 0.406 0.018 1.22 10718.86 5. n-butane 2.22 58.118 1.291 0.057 3.89 34070.34 17. isopentane 0.40 72.114 0.287 0.013 0.86 7565.31 3. n-pentane 0.50 72.114 0.358 0.016 1.08 9449.03 4. cyclopentane 0.04 70.13 0.030 0.001 0.09 784.57 0. n-Hexane 0.11 86.18 0.091 0.0040 0.28 2412.59 1. cyclohexane 0.03 84.16 0.024 0.001 0.07 626.20 0. Other hexanes 0.19 86.18 0.162 0.007 0.49 4272.62 2. heptanes 0.10 100.21 0.101 0.004 0.30 2667.86 1. methylcyclohexane 0.03 98.19 0.026 0.001 0.08 676.19 0. 224-TM P 0.00 114.23 0.001 0.0000 0.00 15.07 0. Benzene 0.02 78.12 0.016 0.0007 0.05 434.92 0. Toluene 0.02 92.15 0.015 0.0007 0.05 406.04 0. Ethylbenzene 0.00 106.17 0.002 0.0001 0.01 64.43 0. Xylenes 0.01 106.17 0.006 0.0002 0.02 148.47 0. C8+Heavies 0.11 120 0.130 0.006 0.39 3425.86 1. VOC mass fracl 0.2736 Total VOC(Uncontrolled) 81. Notes Mole%, MW, and mass fractions are based on a weighted average of site-specific sales gas samples collected 3/16/2015 fror One emergency flare used to combust separator gas during emergencies or when the pipeline is not 011 available. Flare has a minimum control efficiency of 95%. The flare is not enclosed. Flaring Information Equipment Description Flare to combust separator gas during emergencies or when the pipeline is not available. Manufacturer TBD Model TBD Serial Number TBD Gas Heating Value 1295 Btu/scf Throughput 12950 MMBtu/yr VRU Information-NOT APPLICABLE Equipment Description Make Model Requested Control Efficiency Annual Bypass Time Backup I Flare Overall Control 95.00% Combustion emission factor source: AP-42: Chapter 13.5 0.07 llb NOX/MMBtu 0.37 llb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Er VOC 16389 lb/MMscf 819.46 lb/MMscf 81.9 tpy z Nox 0.07 lb/MMBTU 0.07 Ib/MMBTU 0.4 tpy CO 0.37 Ib/MMBTU 0.37 lb/MMBTU 2.4 tpy Benzene 43.492 lb/MMscf 2.1746 lb/MMscf 435 lb/yr n-Hexane 241.26 lb/MMscf 12.063 lb/MMscf 2413 lb/yr 1 Toluene 40.604 lb/MMscf 2.0302 lb/MMscf 406 lb/yr Ethylbenzene 6.4430 lb/MMscf 0.3222 lb/MMscf 64 lb/yr Xylenes 14.847 lb/MMscf 0.7423 Ib/MMscf 148 lb/yr 224-TMP 1.5070 lb/MMscf 0.0753 lb/MMscf 15 lb/yr Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section I I.A.5:'No owner or operator of a smokeless flare or oth( 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 However, since this flare is used for emergency purposes, not used routinely, and must control high pressure, high volume flo% flare will be aooroved as an alternative control device oer Rea 7. Sec XVII.B.2.e. The flare will have to meet Rea 7. Sec XVII.B AIRS(County/Plant)123/9D48 Permit No. 15WE0715 Date 12/31/2015 Controlled Controlled Actual Requested NCRP= Emissions Emissions Ctrl. reportable Point# SCC Pollutant or CAS Uncontrolled Emission Factor Emisison Factor Source (tpy)` (tpy)• PTE(tpy)" Eff% ? VOC 11.5840 lb/1000 gallons Promax 1.3 25.6 95% Yes NOx 0.068 lb/Mmbtu AP-42 Table 13.5 0.1 0.1 0% No CO 0.37 lb/Mmbtu AP-42 Table 13.5 0.3 0.3 0% No 005 40400311 Benzene 0.0800 lb/1000 gallons Promax 18 353 95% Yes n-Hexane 0.6646 lb/1000 gallons Promax 147 2,934 95% Yes Toluene 0.0684 lb/1000 gallons Promax 15 302 95% Yes Ethylbenzene 0.0055 lb/1000 gallons Promax 1 24 95% No Xylenes 0.0279 lb/1000 gallons Promax 6 123 95% No VOC 6.238 lb/1000 gallons CDPHE 0.7 13.2 95% Yes 006 40400315 Benzene 0.167 lb/1000 gallons CDPHE 35 705 95% Yes n-Hexane 0.524 lb/1000 gallons CDPHE 111 2216 95% Yes VOC 2.7463 lb/1000 gallons AP-42 2.0 6.1 67% Yes Benzene 0.0159 lb/1000 gallons AP-42 24 70 66% No 007 40600132 n-Hexane 0.1426 lb/1000 gallons AP-42 211 630 67% Yes Toluene 0.0107 lb/1000 gallons AP-42 16 47 67% No Ethylbenzene 0.0008 lb/1000 gallons AP-42 1 4 68% No Xylenes 0.0033 lb/1000 gallons AP-42 5 15 66% No VOC 45003 lb/MMscf Gas Analysis 1.3 25.7 95% Yes NOx 0.068 Ib/MMBTU AP-42 0.1 0.1 0% No CO 0.37 Ib/MMBTU AP-42 0.4 0.4 0% No 008 31000205 Benzene 83.891 Ib/MMscf Gas Analysis 5 96 95% No n-Hexane 357.68 lb/MMscf Gas Analysis 20 408 95% Yes Toluene 59.569 lb/MMscf Gas Analysis 3 68 95% No Ethylbenzene 10.925 lb/MMscf Gas Analysis 1 12 95% No Xylenes 45.942 lb/MMscf Gas Analysis 3 52 95% No VOC 132857 lb/MMscf Gas Analysis 1.6 32.3 95% Yes NOx 0.068 lb/MMBTU AP-42 0.1 0.1 0% No CO 0.37 Ib/MMBTU AP-42 0.3 0.3 0% No Benzene 1393.8 Ib/MMscf Gas Analysis 34 677 95% Yes 009 31000205 n-Hexane 11515 lb/MMscf Gas Analysis 280 5591 95% Yes Toluene 1167.5 lb/MMscf Gas Analysis 28 567 95% Yes Ethylbenzene 91.059 lb/MMscf Gas Analysis 2 44 95% No Xylenes 455.84 lb/MMscf Gas Analysis 11 221 95% No 224-TMP 715.88 lb/MMscf Gas Analysis 17 348 95% Yes AIRS(County/Plant)123/9D48 Permit No.15WE0715 Date 12/31/2015 Controlled Controlled Actual Requested NCRP= Emissions Emissions Ctrl. reportable Point# SCC Pollutant or CAS Uncontrolled Emission Factor Emisison Factor Source (tpy)" (tpv)' PTE(tpy)* Eff% ? VOC 16389 lb/MMscf Gas Analysis 4.1 81.9 95% Yes NOx 0.068Ib/MMBTU AP-42 0.4 0.4 0% No CO 9.37 Ib/MMBTU AP-42 2.4 2.4 0% Yes 011 31000205 Benzene 43.492 lb/MMsd Gas Analysis 22 435 95% Yes n-Hexane 241.26 lb/MMscf Gas Analysis 121 2413 95% Yes Toluene • 40.604 lb/MMsd Gas Analysis 20 406 95% Yes Ethylbenzene 6.4430 lb/MMsd Gas Analysis 3 64 95% No Xylenes 14.847 lb/MMsd Gas Analysis 7 148 95% No f � 3 "c v o > co 0 o 0 0 > o c E o _ Q ° O awL 3 > Z ZZ c« cco e ° cc, 000 v) u >a t. W >,,O 0 7 L' G, r.C GJ N ❑ ®❑ �"• 'S7 V 4• L V c+l- M M L ❑ u > C 0 d > c Z �° u .+ oNrnoNZ 4p y a a 6. c°, `i' - > w o pW, o ac, ac, o 0 0 WCL 'C OD U N e r. - .Y '" ',"' .1" 0 •- C a Q •N y. e O O O Q N an 11 ad .0 8Ccrk k - 0 w o � � a 3 an W G •a � oo, � o C L. o b . 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