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Home My WebLink About20151249.tiff A 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 11500 St PO Box 758 RECEl Greeley, CO 80632 1/RD April 28, 2015 MAY ) 1 2075 Cfl�U��cY �J Dear Sir or Madam: On April 29, 2015. the Air Pollution Control Division will begin a 30-day public notice period for Bonanza Creek Energy Operating Company LLC - Pronghorn F-17 Production Facility. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, , , Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure rum Q 'j -CP 'l J� CC�U1,� •► s 1+ 2015-1249 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.govicdphe — - John W. Hickenlooper, Governor ! Larry Wolk, MD,MSPH, Executive Director and Chief Medical Officer 'i a h t CDPHE Air Pollution Control Division co vtir Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Bonanza Creek Energy Operating Company LLC - Pronghorn F-17 Production Facility - Weld County Notice Period Begins: April 29, 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 F-17 Production Facility Oil and Gas Exploration and Production Facility NWNW SEC 17 T5N R61W Weld County The proposed project or activity is as follows: Applicant proposes to construct 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 15WE0022 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: Christopher Kester 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 mV co aN oc 40 1 '' � 0 STATE OF COLORADO .,Y fii Y� I i ..i ,450454 050 Pi`, i! is5 v e7561Co�pR �i'5LORAbb DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENTb AIR POLLUTION CONTROL DIVISION ° TELEPHONE: (303) 692-3150 *.w `. {lai6. CONSTRUCTION PERMIT PERMIT NO: 15WE0022 Issuance 1 DATE ISSUED: ISSUED TO: Bonanza Creek Energy Operating Company THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas exploration and production facility known as the Pronghorn F-17 Production Facility , located in the NWNW SEC 17 T5N R 61W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Sep-1 to Three low-pressure separators controlled by four enclosed flare 006 during gas compressor downtime. The flares have a minimum Sep-3 destruction efficiency of 95%. One vapor recovery tower controlled by four enclosed flares during VRT-1 007 gas compressor downtime. The flares have a minimum destruction efficiency of 95%. FL-2 009 One candlestick flare to be used in case of emergency. Flare has a minimum destruction efficiency of 95%. Six (6) 500 bbl above ground atmospheric condensate storage CNDTK-1 011 tanks. Emissions from the tanks are routed to four enclosed combustors that achieve a minimum destruction efficiency of 95%. Two (2) above ground 500 bbl produced water storage tanks. PW 012 Emissions from the tanks are routed to four enclosed combustors that achieve a minimum destruction efficiency of 95%. Hydrocarbon Loadout to Tanker Trucks. Emissions from the tanks TLO 013 are routed to four enclosed combustors that achieve a minimum destruction efficiency of 95%. 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: 123/9CFA Page 1 of 15 olor-_ .Depa en • ' di Health and Environment A •it Pollution Control Division REQUIREMENTS • - . I , " i ' TH• =' •TION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) after issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 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. 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.) 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. 6. Points 006: Within one-hundred 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 separators. The operator shall used the gas flow rate listed in the application for actual flow rate until the flow meter is installed, not to exceed one hundred eighty (180) days after issuance of this permit. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) AIRS ID: 123/9CFA Page 2 of 15 ill or y4 olor %Depart enPaf Ptli Health and Environment • $ 4 .m .0-1t FAir Pollution Control Division ti gi iiI i t AlIA P PI Annual Limit =; ram. F9 Facility AIRS Tons per Year Equipment ID Point NO VOC CO Emission Type Sep-1 to Sep-3 006 0.3 4.5 1.2 Point VRT-1 007 0.2 4.5 0.8 Point FL-2 009 0.5 3.5 2.3 Point CNDTK-1 011 0.1 2.8 0.6 Point PW 012 --- 1.7 --- Point TLO 013 --- 6.4 0.3 Point See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 8. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) Facility AIRS Pollutants Equipment Point Control Device Controlled ID Sep-1 to 006 Enclosed Flare VOC Sep-3 VRT-1 007 Enclosed Flare VOC FL-2 009 Candlestick Emergency Flare VOC CNDTK-1 011 Enclosed Flare VOC PW 012 Enclosed Flare VOC TLO 013 Enclosed Flare VOC AIRS ID: 123/9CFA Page 3 of 15 Ill olor.i Depa en • 'Ii 'Health and Environment •it Pollution Control Division PROCESS LIMITA N a• • . 9. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Process Parameter Annual Limit _ Equipment ID Point Sep-1 to Sep-3 006 Gas Vented from Separators 3.5 MMscf VRT-1 007 Condensate Throughput 214,620 bbl FL-2 009 Gas Vented from Separators 10 MMscf CNDTK-1 011 Condensate Throughput 214,620 bbl PW 012 Produced Water Throughput 258,420 bbl TLO 013 Oil Loaded 214,620 bbl 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. Point 006: The operator shall continuously monitor and record the volumetric flowrate of natural gas vented from the separators using a flow meter. The flow meter shall continuously measure flowrate and record total volumetric flow vented from the separators. The operator shall use monthly throughput records to demonstrate compliance with the process limits and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. 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) 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. (Reference: Regulation No. 1, Section II.A.1. &4.) 12. No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.5.) 13. These sources are subject to the odor requirements of Regulation No. 2. (State only enforceable) 14. Points 006, 011, and 012: The flares covered by this permit are subject to Regulation No. 7, Section XVII.B.2. 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 AIRS ID: 123/9CFA Page 4 of 15 ;':;.olor � DeparlmenTaf P'blic°�Health and Environment 1 B P` , A 1 it Pollution Control Division tiiiic t. �''-= 4 :1 A from the outsid pta e s state o lion date, 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. This flare must be equipped with an operational auto-igniter according to the following schedule: o If the combustion device was installed on/after May 1, 2014, upon installation of the combustion device; o If the combustion device was installed before May 1, 2014, by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 15. Point 006: The separators covered by this permit are 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. 16. Point 011: The flares covered by this permit are subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). If a combustion device is used to control emissions of volatile organic compounds to comply with Section XII.D, it shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XII. 17. Point 011: 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. 18. Points 011 and 012: The storage tanks covered by this permit are subject to the emission control requirements in Regulation No. 7, Section XVII.C.1.b. The owner/operator must install and 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. The source shall follow the inspection requirements of Regulation No. 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control must be achieved according to the following schedule: o If storage tank was constructed on/after May 1, 2014, within 90 days of the date that the storage tank commences operation; 19. Points 011 and 012: If storage tank was constructed before May 1, 2014, by May 1, 2015. The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation No. 7, Section XVII.C.2. This storage tank shall be operated 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. The owner/operator must develop, certify, and implement a documented STEM plan to identify, evaluate, and employ appropriate control technologies, monitoring practices, operational practices, and/or AIRS ID: 123/9CFA Page 5 of 15 olor jk Depa en •Ii Health and Environment it Pollution Control Division other strategic F=.- i e• .. .. -e - -nts. --'Hance is required on the following schedule: o A storage tank constructed on/after May 1, 2014 must comply and implement a STEM Plan within 90 days of the storage tank commencing operation; o A storage tank constructed before May 1, 2014, must comply and implement a STEM Plan 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. Following the first approved instrument monitoring method inspection, owners or operators must continue conducting approved instrument monitoring method inspections in accordance with the Inspection Frequency in Table 1. Table 1 — Storage Tank Inspections Threshold: Storage Tank Approved Instrument Phase-In Uncontrolled Actual VOC Monitoring Method ("AIMM") Schedule Emissions (tpy) Inspection Frequency >6 and < 12 Annually January 1, 2016 > 12 and < 50 Quarterly July 1, 2015 > 50 Monthly January 1, 2015 The owner/operator shall maintain records in accordance with Regulation No. 7, Section XVII.C.3. and make them available to the Division upon request. The owner or operator shall maintain records of STEM, including the plan, any updates, and the certification, for the life of the storage tank. The owner/operator will maintain records of all required inspections and monitoring for a period of two years. 20. Point 013: 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) 21. Point 013: 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 21 (a) and (b) AIRS ID: 123/9CFA Page 6 of 15 D .,olorap D r. epar'�nenrof P7blicllHealth and Environment TA to .OlEkkkke 11ir Pollution Control Division 00:04, 1'014 - r I above., erM pe ss` cc at, �`" t monttb Each inspection shall be documented in a log available to the Division on request. 22. Point 013: 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. OPERATING & MAINTENANCE REQUIREMENTS 23. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 24. Points 006 and 009: The operator shall complete an initial site specific extended gas analysis of the natural gas produced 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. 25. Points 006, 011, and 012: 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.B.2) 26. Point 009: The owner or operator shall demonstrate compliance with opacity standards using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section II.A.5). 27. Point 011: The operator shall complete site specific sampling including a compositional analysis of the pre-flash pressurized crude oil routed to these storage tanks and a sales oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site-specific emissions factor using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. Periodic Testing Requirements 28. Points 006 and 009: On an annual basis, the operator shall complete a site specific extended gas analysis of the natural gas produced at this site that is routed to the flare in order to verify the VOC 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. AIRS ID: 123/9CFA Page 7 of 15 � olor-. .� Depa en • P •Ii Health' and Environment ' •it Pollution Control Division ADDITIONAL REQ . N ° .. . 29. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, I I.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (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. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 30. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). 31. MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this stationary source at any such time that this stationary source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of Subpart HH. (Reference: Regulation No. 8, Part E) 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. AIRS ID: 123/9CFA Page 8 of 15 �: n k= olora ° ;Depa err fa, Tra 4141 of Prtli cillealth and Environment �frauk RI it Pollution Control Division 33. If this permit. allyn to`w Tina rat�tk Eizatio 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 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. 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 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. 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: Christopher Kester Permit Engineer AIRS ID: 123/9CFA Page 9 of 15 r °loll Depa en 'Ii Health and Environment •it Pollution Control Division b Slei � i ras" 't Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bonanza Creek Energy Operating Company AIRS ID: 123/9CFA Page 10 of 15 marnm `g i A( Color `' Depar�nenTf PEblicdHealth and Environment Gh' it Pollution Control Division 21; ilk los Nor.`- i 9 6 AN Notes to Permit Holder aftlttSe ortfitilaeTiffiline"'"'""' " s ' 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: http://www.colorado.gov/cs/Satellite?c=Document C&childpagename=CDPHE- Main%2FDocument C%2FCBONAddLinkView&cid=1251599389641&pagename=CBONWrapper 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS ID: 123/9CFA Page 11 of 15 II olor Depa en .li ' t PollutionHealth ControlandEnvironment Division Emission Are the Controlled AIRS Rate emissions Emission Rate Point Pollutant CAS # (Ib/yr) reportable? (Ib/yr) 006 Benzene 71432 380 Yes 19 006 n-Hexane 110543 2157 Yes 108 006 Toluene 108883 228 No 11 006 Ethylbenzene 100414 22 No 1 006 Xylenes 1330207 50 No 3 007 Benzene 71432 1822 Yes 91 007 n-Hexane 110543 12073 Yes 604 007 Toluene 108883 1655 Yes 83 007 Ethylbenzene 100414 232 No 12 007 Xylenes 1330207 484 Yes 24 009 Benzene 71432 227 No 11 009 n-Hexane 110543 1653 Yes 83 009 Toluene 108883 199 No 10 009 Ethylbenzene 100414 53 No 3 009 Xylenes 1330207 90 No 5 011 Benzene 71432 766 Yes 38 011 n-Hexane 110543 5121 Yes 256 __ 011 Toluene 108883 708 Yes 35 012 Benzene 71432 1809 Yes 90 012 n-Hexane 110543 5685 Yes 284 013 Benzene 71432 68 No 23 013 n-Hexane 110543 856 Yes 287 013 Toluene 108883 44 No 15 013 Xylenes 1330207 10 No 3 AIRS ID: 123/9CFA Page 12 of 15 ._ii olor it Depa nen� a P`�,pllc�Health and Environment alz al 1� T Air Pollution Control Division i N 3 ' 5) The emission level rried in leApe g baagebift follow $mission factors: Point 006: Emission Factors Emission Factors Pollutant Uncontrolled Controlled Source lb/MMscf lb/MMscf NOx (lb/MMBTU) 0.068 0.068 AP-42 CO (lb/MMBTU) 0.37 0.37 AP-42 VOC 50476.8 2523.8 Gas Analysis Benzene 108.6 5.4 Gas Analysis Toluene 65.2 3.3 Gas Analysis Ethylbenzene 6.2 0.3 Gas Analysis Xylenes 14.3 0.7 Gas Analysis n-hexane 616.2 30.8 Gas Analysis Point 007: Emission Factors Emission Factors Pollutant Uncontrolled Controlled Source lb/MMscf lb/MMscf NOx (lb/MMBTU) 0.068 0.068 AP-42 CO (lb/MMBTU) 0.37 0.37 AP-42 VOC 144379.8 7219.0 Benzene 1490.0 74.5 Promax with Toluene 1353.5 67.7 pressurized Ethylbenzene 190.0 9.5 liquids analyses Xylenes 395.6 19.8 input upstream of VRT n-hexane 9871.5 493.6 Point 009: Emission Factors Emission Factors Pollutant Uncontrolled Controlled Source lb/MMscf lb/MMscf NOx (lb/MMBTU) 0.068 0.068 AP-42 CO (lb/MMBTU) 0.37 0.37 AP-42 VOC 13899.1 695.0 Gas Analysis Benzene 22.7 1.1 Gas Analysis Toluene 19.9 1.0 Gas Analysis Ethylbenzene 5.3 0.3 Gas Analysis Xylenes 9.0 0.4 Gas Analysis n-hexane 165.3 8.3 Gas Analysis Point 011: Emission Factors Uncontrolled Pollutant Source lb/BBL Condensate Throughput VOC 0.5169 Promax n-Hexane 0.0239 Promax Benzene 0.0036 Promax Toluene 0.0033 Promax AIRS ID: 123/9CFA Page 13 of 15 olor r Depa en . .Ii Health and Environment it Pollution Control Division Note: The co , :. is fo.' nt '_ •n the, -:::control efficiency of 95%. Point 012: Emission Factors Pollutant Uncontrolled Source lb/BBL Produced Water Throughput VOC 0.262 CDPHE n-Hexane 0.022 CDPHE Benzene 0.007 CDPHE Note: The controlled emissions for this point are based on the flare control efficiency of 95%. Point 013: Emission Factors - Uncontrolled Pollutant lb/BBL loaded Source VOC 0.1764 AP-42 Benzene 0.0003 AP-42 n-Hexane 0.004 AP-42 Toluene 0.0002 AP-42 Xylenes 0.0001 AP-42 The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L= 12.46*S*P*M/T S = 1 (Submerged loading: dedicated normal service) P (true vapor pressure) = 11.34 psia M (vapor molecular weight) = 28.9 Ib/Ib-mol T(temperature of liquid loaded) = 523.67°R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. 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 and HAP NANSR Synthetic Minor Source of: VOC and HAP MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Applicable AIRS ID: 123/9CFA Page 14 of 15 Nt., 211'; �! u olorai `-Depar eneuf P 'bli&Health and Environment IT !trio? r` ` 0 -Air Pollution Control Division r `2 8) Full text of the TitlsrMigattect4Alpf lapykinmentWknic Codes :Federal Regulations can be found at the website listed below: http://ecfr.qpoaccess.qov/ 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 PA—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 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: 123/9CFA Page 15 of 15 Division Information Engineer: Christopher Kester Control Engineer: Stefanie Rucker Review Date: 03/05/2015 Application Date: 10/17/2014. Facility Identifiers Permit No. 15WE0022 Potentially located in ozone nonattainment area AIRS County# 123 Weld Facility# 9CFA Facility Type: exploration and production facility ❑' Located in the B-hour non-attainment area? 0 True Minor 0 Synthetic Minor for: P VOC (" NOx F CO Administrative Information Company Name: Bonanza Creek Energy Operating Company Source Name: Pronghorn F-17 Production Facility Source Location: NWNW SEC 17 T5N R 61W SIC: 1311 Address 1: Bonanza Creek Energy Operating Company Mailing Address 2: 410 17th Street, Suite 1500 Address 'ty,State Zip: Denver,CO 80202 Name: Peg Young Person To Phone: 720-440-6133 Contact Fax: Email: pyoung@bonanzacrk.com IRequested Action Self Certification Required? Yes Issuance Number: 1 • Source Description: Oil and gas exploration and production facility known as the Pronghorn F-17 Production Facility, located in the NWNW SEC 17 T5N R 61W,Weld County,Colorado. Point Name Type Control Action Sep-1 to Newly 006 Se p3 Separator Venting Flare reported source Newly 007 VRT-1 Separator Venting Flare reported source Newly 009 FL-2 Separator Venting Flare reported source Newly 011 CNDTK-1 Condensate Tanks Flare reported source Newly 012 PW Water Tanks Flare reported source Newly 013 TLO Loadout Flare reported source Three low-pressure gas/oil separators controlled by four enclosed flare during gas compressor downtime. 006 The flares have a minimum destruction efficiency of 95%. Equipment Description This source vents natural gas from: well head separators Emissions from this source are: routed to a flare Natural gas venting from well head separators.Emissions from this source are routed to a flare(when gas compressors are down) Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q*MW*Xx 1C 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 The flowrate off the separator is 23.45 MMscf/yr.This stream is normally routed to a VRU.The VRU has 15% Throughput(Q) 3.5 MMscf/yr 399.5433]9 scf/hr downtime.(0.15'23.45 MMscf/yr=3.5 MMscf/yr) MW 33.29 lb/lb-mol 0.009589041 MMscf/d mole% MW Ibxnbmol mass fraction lb/hr lb/yr tpy Helium 0.0000 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 2.7600 44.01 1.215 0.0365 1.28 11217.32 5.61 N2 0.1300 28.013 0.036 0.0011 0.04 336.30 0.17 methane 36.9272 16.041 5.923 0.1779 6.24 54702.43 27.35 ethane 23.2336 30.063 6.985 0.2098 7.36 6450267 32.25 propane 22.9676 44.092 10.127 0.3042 10.68 93519.95 46.76 isobutane 2.4169 58.118 1.405 0.0422 1.48 12971.74 6.49 n-butane 7.4975 58.118 4.357 0.1309 4.59 40239.81 20.12 isopentane 1.2072 72.114 0.871 0.0262 0.92 8039.47 4.02 n-pentane 1.4680 72.114 1.059 0.0318 1.12 9776.30 4.89 cyclopentane 0.0988 70.13 0.069 0.0021 0.07 639.87 0.32 n-Hexane 0.2710 86.18 0.234 0.00702 0.25 2156.77 1.08 cyclohexane 0.0697 84.16 0.059 0.0018 0.06 541.71 0.27 Other hexanes 0.4925 86.18 0.424 0.0127 0.45 3919.60 1.96 heptanes 0.2077 100.21 0.208 0.0063 0.22 1922.10 0.96 methylcyclohexane 0.0506 98.19 0.050 0.0015 0.05 458.82 0.23 224-TMP 0.0002 114.23 0.000 0.000007 0.00 2.11 0.00 Benzene 0.0527 78.12 0.041 0.00124 0.04 380.19 0.19 Toluene 00288 92.15 0.025 0.00074 0.03 228.07 0.11 Ethylbenzene 0.0022 106.17 0.002 0.00007 0.00 21.57 0.01 Xylenes 0.0051 106.17 0.005 0.00016 0.01 50.00 0.03 C8.Heavies 0.0940 207.4276468 0.195 0.00586 0.21 1800.63 0.90 99.9793 VOC mass fracl 0.575 Total VOC(Uncontrolled) 88.33 33.290 1.000 Notes Mole%,MW,and mass fractions from State Seventy Holes F11-J14-3HNC gas analysis collected 07/11/2014 Initial site specific sampling will be required This is not based on a site specific gas sample and sampling will be required. Emissions are based on VRU downtime of 15%. I calculated the average MW of C8+based on the average MW on the analysis for the gas. 15WE0022.CP1.xlsm Three low-pressure gas/oil separators controlled by four enclosed flare during gas compressor downtime. 006 The flares have a minimum destruction efficiency of 95%. Flaring Information Equipment Description Flare to combust low-pressure separator gas during estimated 15°/VRU downtime. Gas Heating Value 1721 Btu/scf Throughput 6023.5 MMBtu/yr Overall Control 95.00% Combustion emission factor source. AP-42:Chapter 13.5 0.068 Ilb NOX/MMBtu 0.37 Ilb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 50477 lb/MMscf 2523.84 lb/MMscf 88.33 tpy 4.42 tpy Gas Analysis Nox 007 Ib/MMBTU 0.07 Ib/MMBTU 0.20 tpy 0.20 tpy AP-42 CO 0.37 Ib/MMBTU 0.37 Ib/MMBTU 1.11 tpy 1.11 tpy AP-42 Benzene 108.63 lb/MMscf 5.43 lb/MMscf 380 lb/yr 19 lb/yr Gas Analysis n-Hexane 616.22 lb/MMscf 30.8111 lb/MMscf 2157 lb/yr 108 lb/yr Gas Analysis Toluene 65.161 lb/MMscf 3.2581 lb/MMscf 228 lb/yr 11 lb/yr Gas Analysis Xylenes 14.2871b/MMscf 0.7143 lb/MMscf 50 lb/yr 3 lb/yr Gas Analysis Ethylbenzene 6.163 lb/MMscf 0.3081 lb/MMscf 22 lb/yr 1 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 15WE0022.CPl.xlsm One vapor recovery tower controlled by four enclosed flares during gas compressor downtime.The flares 007 have a minimum destruction efficiency of 95%. Equipment Description This source vents natural gas from: a vapor recovery tower Emissions from this source are: routed to a flare Natural gas venting from a vapor recovery tower.Emissions from this source are routed to a flare during gas compressor downtime. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=0•MW•Xx/C Ex=emissions of pollutant x 0=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas'MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm The gas flowrate off the VRT is 2.91 MMscf/yr.The VRU's will be bypassed 35%of the year.This value with a 20%buffer results in a requested Throughput(Cr) 1.2 MMscf/yr 139.6118721 acf/hr flowrate of 1.2 MMscf/yr MW 58.7 Ib/b-mol 0.003350685 MMscf/d mole% MW lbx/Ibmol mass fraction lb/hr Ib/yr tpy Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 0.64 44.01 0.282 0.005 0.10 910.14 046 N2 022 28.013 0.060 0001 0.02 194.92 0.10 methane 2.55 16.041 0.409 0.007 0.15 1320.31 066 ethane 10.74 30.063 3.228 0.055 1.19 10417.98 5.21 propane 2899 44.092 12 784 0.218 4.71 41253.54 20.63 isobutane 4.57 58.118 2.655 0.045 0.98 8566.38 4.28 n-butane 18.93 58.118 10.999 0.187 4.05 35493.02 17.75 isopentane 4.55 72.114 3.284 0.056 1.21 10598.60 5.30 n-pentane 5.60 72.114 4.035 0.069 109 13020.13 6.51 cyclopentane 2.19 70.13 1.535 0.026 0.57 4952.65 2.48 n-Hexane 4.34 86.18 3.741 0.064 1.38 12072.90 604 cyclobexane 1.33 84.16 1.118 0.019 041 360.95 1.80 Other hexanes 774 86.18 6669 0.114 2.46 21521.83 10.76 heptanes 2.76 100.21 2761 0.047 1.02 8910.50 4.46 methylcyclohexane 1.08 98.19 1.058 0.018 0.39 340846 1.70 224-TMP 0.36 114.23 0412 0.007 0.15 1328.36 0.66 Benzene 0.72 78.12 0.565 0.010 0.21 1822.23 0.91 Toluene 056 92.15 0.513 0.009 0.19 1655.37 0.83 Ethylbenzene 0.07 106.17 0.072 0.001 0.03 232.40 0.12 Xylenes 0.14 106.17 0.150 0.003 0.06 483.80 0.24 08+Heavies 194 1222195068 2.370 0.040 0.87 764933 382 VOC mass frail 0.932 Total VOC(Uncontrolled) 88.29 Notes Mole%,MW,and mass fractions from a VRT flash promax model with upstream inputs from two pressurized liquids analyses collected 9/3/2014 from the Pronghom 11-14- 17HNB and Pronghom F-J-17HNC wells. Emissions are based on 35%VRU Downtime plus a 20%buffer on the flared volume The MW is from the VRT gas stream on the promax simulation. 15WE0022.CP 1.xlsm One vapor recovery tower controlled by four enclosed flares during gas compressor downtime.The flares 007 have a minimum destruction efficiency of 95%. Flaring Infonsation Equipment Description Flare to combust low-pressure separator gas during VRU downtime. Gas Heating Value 3255 btu/scf Throughput 3980.865 MMBtu/yr 'Overall Control I 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.068 alb NOX/MMBtu 0.37 jIb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 144380 Ib/MMscf 7218.99 Ib/MMscf 88.29 tpy 4.41 toy Promos Nox 0.07 Ib/MMBTU 0.07 Ib/MMBTU 0.14 toy 0.14 toy AP-42 CO 037 Ib/MMBTU 0.37 Ib/MMBTU 0.74 toy O.74 toy AP-42 Benzene 1489.97 lb/MMscf 74.50 lb/MMscf 1822 lb/yr 91 lb/yr n-Hexane 9871.54 Ib/MMscf 493.5772 Ib/MMscf 12073 lb/yr 604 lb/yr Toluene 1353535 Ib/MMscf 67.6768 Ib/MMscf 1655 lb/yr 83 lb/yr Promos with pressurized liquids Xylenes 395.588 lb/MMscf 19779416/MMscf 484 lb/yr 24 lb/yr analyses input upstream of VRT Ethylbenzene 190.02716/MMscf 9501316/MMscf 232 lb/yr 12 lb/yr 224 TMP 1086.1521b/MMscf 54.3079 ib/MMscf 1328 lb/yr 66 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 other flare for the combustion of waste gases shall allow or cause emissions i into the atmosphere of any air pollutant which is in excess of 30%opacity.' AQCC Regulation 2 Section IA applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in 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." 15WE0022.CP 1.xlsm 009 One candlestick flare to be used in case of emergency.Flare has a minimum destruction efficiency of 95%. Equipment Description This source vents natural gas from: exploration and production operations during emergency situations Emissions from this source are: routed to a flare Natural gas venting from exploration and production operations during emergency situations.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(0) 10 MMscf/vr 1141.552511 sc(/hr MW 22.09 Ib/Ib-mol 0.02739726 MMscf/d mole% MW Ibx/Ibmol mass fraction lb/hr Ib/vr tpy Helium 0.0000 4.0026 0.000 0.000000 0.00 0.00 0.00 C02 2.3832 44.01 1.049 0047481 3.16 27674.05 13.84 N2 0.9650 28.013 0.270 0.012237 0.81 7132.60 3.57 methane 74.4730 16.041 11.946 0.540797 35.98 315203.53 157.60 ethane 11.8314 30.063 3.557 0.161017 10.71 93848.91 46.92 propane 6.9198 44.092 3.051 0.138120 9.19 80503.38 40.25 isobutane 0.6196 58.118 0.360 0.016301 1.08 9501.30 4.75 n-butane 1.8358 58.118 1.067 0.048299 3.21 28151.19 14.08 isopentane 0.2970 72.114 0.214 0.009696 0.65 5651.15 2.83 n-pentane 0.3673 72.114 0.265 0.011991 0.80 6988.78 3.49 cyclopentane 0.0336 70.13 0.024 0.001087 0.07 621.73 0.31 n-Hexane 0.0727 86.18 0.063 0.002836 0.19 1653.11 0.83 cyclohexane 0.0233 84.16 0.020 0.000888 0.06 517.40 0.26 Other hexanes 0.1054 86.18 0.091 0.004112 0.27 2396.67 1.20 heptanes 0.0186 100.21 0.019 0.000844 0.06 491.80 0.25 methylcyclohexane 0.0158 98.19 0.016 0.000702 0.05 409.34 0.20 224-TMP 0.0073 114.23 0.008 0.000377 0.03 220.02 0.11 Benzene 0.0110 78.12 0.009 0.000389 0.03 226.73 0.11 Toluene 0.0082 92.15 0.008 0.000342 0.02 199.37 0.10 Ethylbenzene 0.0019 106.17 0.002 0.000091 0.01 53.23 0.03 Xylenes 0.0032 106.17 0.003 0.000154 0.01 89.64 0.04 C8+Heavies 0.0067 744.2395224 0.050 0.002257 0.15 1315.67 0.66 VOC mass tract 0.238 Total VOC(Uncontrolled) 69.50 Notes Mole%,MW,and mass fractions from weighted avg of two gas analyses collected 9/3/2014 from two Pronghom wells that feed to this facility. Emissions are based on 8760 hours of operation per year. MW of CS.is MW of n-octane 15WE0022.CP1.xlsm 009 One candlestick flare to be used in case of emergency.Flare has a minimum destruction efficiency of 95%. Flaring Information Equipment Description Flare to combust gas during emergency conditions. Gas Heating Value 1262 Btu/scf Throughput 12620 MMBtu/yr Overall Control 95.00% Combustion emission factor source: AP-42:Chaster 13.5 0.07 llb NOXIMMBtu 0.37 llb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 13899 lb/MMscf 694.95 lb/MMscf 69.50 tpy 3.47 tpy Gas Analysis Nox 007 Ib/MMBTU 0.07 Ib/MMBTU 0.43 tpy 0.43 tpy AP-42 CO 0.37 Ib/MMBTU 0.37 Ib/MMBTU 2.33 tpy 2.33 tpy AP-42 Benzene 22.67 lb/MMscf 1.13 lb/MMscf 226.73 lb/yr 11.34 lb/yr Gas Analysis n-Hexane 165.31 lb/MMscf 8.2655 lb/MMscf 1653.11 lb/yr 82.66 lb/yr Gas Analysis Toluene 19.937 lb/MMscf 0.99691b/MMscf 199.37 Ib/yr 9.97 lb/yr Gas Analysis Xylenes 8.964 lb/MMscf 0.4482 lb/MMscf 89.64 Ib/yr 4.48 lb/yr Gas Analysis Ethylbenzene 5.323 lb/MMscf 0.2661 lb/MMscf 53.23 lb/yr 2.66 lb/yr Gas Analysis Regulatory Applicability AOCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' AOCC Regulation 2 Section I.A applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air." 15WE0022.C P1,xlsm 011 Six(6)500 above ground atmospheric condensate storage tanks IRequsted Throughput214620 bbl Combustion Emissions Volume to be flared 0.001892 MMscfd Control Flare I 0.690554 MMscf/yr Efficiency 95.00%j Heating Value 3098.2 Btu/scf 2139.4 MMBtu/yr Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.5169 lb/bbl 55.5 tpy 2.8 tpy Promax Benzene 0.00357 lb/bbl 766 lb/yr 38 lb/yr Promax n-Hexane 0.02386 lb/bbl 5121 lb/yr 256 lb/yr Promax Toluene 0.00330 lb/bbl 708 lb/yr 35 lb/yr Promax Ethylben 0.00047 lb/bbl 101 lb/yr 5 lb/yr Promax Xylene 0.00099 lb/bbl 212 lb/yr 11 lb/yr Promax 224TMP 0.00324 lb/bbl 695 lb/yr 35 lb/yr Promax NOx 0.068 lb/MMBtu 0.073 tpy 0.073 tpy Promax CO 0.37 lb/MMBtu 0.396 tpy 0.396 tpy Promax Regulatory Review Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20%opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR, Part 60, Appendix A(July, 1992))in all subsections of Section II. A and B of this regulation. Section II.A.5 -Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2—Odor Section I.A-No person,wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air. Regulation 6-New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. This source is not subject because each tank is less than 19,800 gallons(471 bbl) Pie 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 a non attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is currently subject to this since actual uncontrolled emissions are greater than 20 tpy of VOC.) 012 Two(2) above ground 500 bbl produced water storage tanks. Emission from all three tanks are routed to one of four enclosed combustors that achieve a minimum destruction efficiecny of 95%. Emissions Calculations Requsted Throughput 258420 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.262 lb/bbl 33.85302 tpy 1.692651 tpy CDPHE Benzene 0.007 lb/bbl 1808.94 lb/yr 90.447 lb/yr CDPHE n-Hexane 0.022 lb/bbl 5685.24 lb/yr 284.262 lb/yr CDPHE Regulatory Review Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A(July, 1992)) in all subsections of Section II. A and B of this regulation. Section Il.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. Requlation 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. 013 Hydrocarbon Loadout to Tanker Trucks Calculations L=12.46*S*P*M/T(AP-42:Chapter 5.2,Equation 1) L=loading losses in lb per 1000 gallons loaded Factor Meaning Value Units Source S Saturation Factor 1 AP-42 P True Vapor Pressure 11.34 psia Sales Oil Analysis M Molecular Weight of Vaf 28.9 lb/lb-mole Sales Oil Analysis T Liquid Temperature 523.67 deg.R Field Data The Loading Loss emission factor is multiplied 4.20 lb/109 gal by the[VOC wt fraction in the vapors]- 1.76E-01 lb/bbl 0.5385 to get the actual"L" Annual requested Throughput 214620 BBL/yr 9014040 gal/yr Annual requested VOC emissions 37851 lb/yr 18.93 tpy Control: Flare Efficiency: 66.50% based on 70%collection efficiency and 95%destruction efficiency NCRPs Component Mass Fraction Combustion Emissions Benzene 0.001803 Volume 921790.2136 scf/yr n-hexane 0.022602 HV 1721 Btu/scf Toluene 0.001152 1586.4 MMBtu/yr Xylenes 0.000254 Ethylben 0.000115 Volume of flared gas was calculated with the mass emission rate of 224 TMP 0.001739 hydrocarbons,the MW of the gas,and 379 scf/Ibmol Source: Truck Loading Vapor Composition from speciated sales oil analysis Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.17636 lb/bbl 18.9 tpy 6.3 tpy AP-42 Benzene 0.00032 lb/bbl 68.2 lb/yr 22.9 lb/yr AP-42 n-Hexane 0.00399 lb/bbl 856 lb/yr 287 lb/yr AP-42 Toluene 0.00020 lb/bbl 44 lb/yr 15 lb/yr AP-42 Xylenes 0.00004 lb/bbl 10 lb/yr 3 lb/yr AP-42 Ethylben 0.00002 lb/bbl 4 lb/yr 1 lb/yr AP-42 224 TMP 0,00031 lb/bbl 66 lb/yr 22 lb/yr AP-42 CO 0.37000 lb/MM Btu 0.29 tpy 0.29 tpy AP-43 NOx 0.06800 lb/MM Btu 0.05 tpy 0.05 tpy AP-44 Regulatory Review 'Regulation 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: goes the operator unload less than 10,000 gallons(238 gifts)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 IL 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 AIRS(County/Plant) 123/9CFA Permit No. 15WE0022 Date 3/5/2015 Controlled Controlled Actual Requested NCRP a Uncontrolled Emission Emissions Emissions Ctrl. reportable Point# 5CC Pollutant or CAS Factor Emisison Factor Source (ipy)' (toy)' PTE ppyp Err! ? 006 31000205 VOC 50476.775 lb/MMscf Gas Analysis 4.4 88.3 95% Yes 006 31000205 NOx 0 061b/MMBTL AP-42 0.2 0.2 0% No 006 31000205 CO 0.371b/MMBTL AP-42 1.1 1.1 0% Yes 006 31000205 Benzene 108626 lb/MMscf Gas Analysis 19 380.2 95% Yes 006 31000205 n-Hexane 616 221 Gas Analysis 10.8 2156.8 95% Yes 006 31000205 Toluene 65.161 lb/MMscf Gas Analysis 11.4 228.1 95% No 006 31000205 Ethylbenzene 6.163 lb/MMscf Gas Analysis 1.1 21.6 95% No 006 31000205 Xylenes 14.287 lb/MMscf Gas Analysis 2.5 50 95% No 007 31000205 VOC 1443797641b/MMscl Promax 44 88.3 95% Yes 007 31000205 NOx 0.0681b/MMBTL AP-42 0.1 0.1 0% No 007 31000205 CO 0.37 lb/MMBTL AP-42 07 0.7 0% No 007 31000205 Benzene 1489.9671b/MMscf Promax 91.1 1822.2 95% Yes 007 31000205 n-Hexane 9871.544 lb/MMscf 603.6 12072.9 95% Yes 007 31000205 Toluene 1353.535 lb/MMscf 82.8 1655.4 95% Yes 007 31000205 Ethylbenzene 190.027 Ib/MMsct 11.6 232.4 95% No 007 31000205 Xylenes 395.588 lb/MMscf 242 483.8 95% Yes 009 31000205 VOC 13899.052 lb/MMscf Gas Analysis 3.5 69.5 95% Yes 009 31000205 NOx 0.068 Ib/MMBTL AP-42 0.4 0.4 0% No 009 31000205 CO 0.37 Ib/MMBTL AP-42 2.3 2.3 0% Yes 009 31000205 Benzene 22.673 Ib/MMscf Gas Analysis 11.3 226.7 95% No 009 31000205 n-Hexane 165.311 lb/MMscf Gas Analysis 82.7 1653.1 95% Yes 009 31000205 Toluene 19.937 lb/MMscf Gas Analysis 10 199.4 95% No 009 31000205 Ethylbenzene 5.323 Ib/MMsct Gas Analysis 2.7 53.2 95% No 009 31000205 Xylenes 8.964 lb/MMscf Gas Analysis 4.5 89.6 95% No 011 40400311 VOC 12.307 lb/1000 qa Promax 2.8 55.5 95% Yes 011 40400311 NOx O0681b/MMBtu Pmmax 0.1 0.1 0% No 011 40400311 CO 0.37 lb/MMBIu Promax 0.4 0.4 0% No 011 40400311 Benzene 0.085 10/1000 ga Promax 38.3 766.2 95% Yes 011 40400311 n-Hexane 0.568 lb/1000 qa Promax 256 5120.8 95% Yes 011 40400311 Toluene 0.079 lb/1000 ga Promax 35.4 708.2 95% Yes 012 40400315 VOC 6.238 lb/1000 ga CDPHE 1.7 33.9 95% Yes 012 40400315 Benzene 0.167 lb/1000 ga CDPHE 904 1808.9 95% Yes 012 40400315 n-Hexane 0.524 lb/1000 qa CDPHE 284.3 5685.2 95% Yes 013 40600132 VOC 4.199lb/1000 qa AP-42 6.3 18.9 67% Yes 013 40600132 NOx 0 061b/MMBtu AP-44 0.1 0.1 0% No 013 40600132 CO 0.37 lb/MMBtu AP-03 0.3 0.3 0% No 013 40600132 Benzene 0.008 lb/1000 qa AP-42 22.9 68.2 66% No 013 40600132 n-Hexane 0.095 lb/1000 ga AP-42 2866 855.5 66% Yes 013 40600132 Toluene 0.005 lb/1000 ga AP-42 14.6 43.6 67% No 013 40600132 Xylenes 0.001 lb/1000 qa AP-42 3.2 9.6 67% No h O Y X a . - C O E . 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