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Home My WebLink About20143022.tiff STATE OF COLORADO John W.Hickenlooper,Governor Larry Wolk,MD,MSPH .oF coto Executive Director and Chief Medical Officer , €atis 3 *Dedicated to protecting and improving the health and environment of the people of Colorado 4300 Cherry Creek Dr.S. Laboratory Services Division ' * Denver,Colorado 80246-1530 8100 Lowry Blvd. SiI Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.gov/cdphe and Environment Weld County -Clerk to the Board 1150 O St PO Box 758 RECEIVED Greeley, CO 80632 September 23,2014 SEP 2 9 2014 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On September 26. 2014,the Air Pollution Control Division will publish a public notice for Bonanza Creek Energy Operating Company LLC—Pronghorn T-3 Production Facility, in the The Greeley Tribune. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30)days from the date the public notice is published. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health& Environment APCD-SS-B I 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, • f i• J Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure ?u1:44. -NEE ) 2014-3022 10 - 10-P-1 CC: Pc,Tw- 'Vag STATE OF COLORADO John W.Hickenlooper,Governor co Larry Wolk, MD.MSPH r_ \q Executive Director and Chief Medical Officer 74%, fi; \Tp Dedicated to protecting and improving the health and environment of the people of Colorado �' ;,`* * 4300 Cherry Creek Dr S. Laboratory Services Division 'len Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.gov/cdphe and Environment Website Title: Bonanza Creek Energy Operating Company LLC—Pronghorn T-3 Production Facility —Weld County Released To: The Greeley Tribune On: September 23, 2014 Published: September 26,2014 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Bonanza Creek Energy Operating Company LLC Facility: Pronghorn T-3 Production Facility Oil and Natural Gas Exploration and Production Facility SESE Section 3,T5N. R61 W, approximately 14 miles northwest of Wiggins, CO Weld County The proposed project or activity is as follows: Applicant is requesting permit coverage for a pump jack engine, condensate loadout operation, fugitive component leaks, and pneumatic pumps at a new E&P site. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.I.a (25 tpy in a non-attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 13WE2615 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: Oluwaseun Ogungbenle Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B 1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us . STATE OF COLORADO .0v.°pzo; „co # COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT t'� AIR POLLUTION CONTROL DIVISION * ' '. *I TELEPHONE: (303) 692-3150 1:/876 t. CONSTRUCTION PERMIT PERMIT NO: 1 3WE261 5 Issuance 1 DATE ISSUED: ISSUED TO: Bonanza Creek Energy Operating Company LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Pronghorn T-3 Production Facility, located in SESE Section 3, Township 5N, Range 61W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point One (1) Arrow, Model A-62, Serial Number 6B12004121, natural gas-fired, naturally aspirated, 4SRB reciprocating E2 004 internal combustion engine, site rated at 80 horsepower at 1800 RPM. This engine is equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio controller. This emission unit is a pump jack engine. Truck Loadout 005 Truck loadout of condensate. Fugitive Component Leak Emissions from Well head, heater FUG 006 treater, enclosed combustors, condensate tanks, produced water tanks, and gas meter house. One (1) Sandpiper, G20, Serial Number 2076866, Pump 1 007 pneumatic pump used for water transfer. Emissions from this pump are controlled using an enclosed flare. One (1) Sandpiper, G20, Serial Number 2004232, Pump 2 008 pneumatic pump used for heat trace. Emissions from this pump are controlled using an enclosed flare. AIRS ID: 123/9639 Page 1 of 19 DCo do p e o Public PollutionHealth ControlandEnvironment Division Point 004: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Arrow A-62 engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Points 007 and 008: These pumps may be replaced with another pump in accordance with the provisions of the Alternate Operating Scenario (AOS) in this permit. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et sect), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. 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. EMISSION LIMITATIONS AND RECORDS 6. 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: 123/9B39 Page 2 of 19 Col do • p e o' Public Health and Environment Air Pollution Control Division Annual Limits: Facility AIRS Tons per Year Emission Type Equipment ID Point NO, VOC CO E2 004 2.2 3.7 Point Truck Loadout 005 -- 2.2 -- Point FUG 006 -- 3.8 -- Fugitive Pump 1 007 0.6 4.8 3.0 Point Pump 2 008 0.4 3.5 2.2 Point See "Notes to Permit Holder"for information on emission factors and methods used to calculate limits. 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. 7. 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 E2 004 Non-Selective Catalytic Reduction System and NOx and CO air/fuel ratio controller Pump 1 007 Enclosed Flare VOC and HAPs Pump 2 008 Enclosed Flare VOC and HAPs 8. Point 006: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas analysis, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. PROCESS LIMITATIONS AND RECORDS 9. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate 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) AIRS ID: 12319B39 Page 3 of 19 D Co do p e o Public Health and Environment Air Pollution Control Division Process/Consumption Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point E2 004 Consumption of natural gas as fuel 6.3 MMscf/yr Truck Loadout 005 Condensate Loading 21,900 BBL/yr Pump 1 007 Venting of natural gas used to 11.6 MMscf/yr drive pneumatic pumps Pump 2 008 Venting of natural gas used to 8.4 MMscf/yr drive pneumatic pumps 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. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. Points 004, 007, and 008: The permit number and AIRS ID point number(e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 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.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) 12. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 13. Point 005: This source is located in an ozone non-attainment or attainment- maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 14. Point 005: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of • maintenance, gauging, or safety of personnel and equipment. AIRS ID: 12319B39 Page 4 of 19 Col- do p e o Public Health and Environment Air Pollution Control Division c. The owner or operator shall inspect loading equipment and operations onsite at the time of inspections to monitor compliance with Condition 14 (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. 15. Point 005: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 16. Point 006: This source is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. The operator shall comply with all applicable requirements of Section XII. 17. Point 006: Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). This requirement to apply RACT shall be satisfied by installing/implementing the following emission controls: a. Directed Inspection & Maintenance as described below shall satisfy the requirement to apply RACT. i. Auditory/visual/olfactory inspection (AVO) will be performed on a semi-annual basis. The first AVO inspection must be completed within 180 days of permit issuance. ii. For each leak found in the AVO inspection, a gas detector may be used to determine the size of the leak. The gas detector shall be regularly calibrated. Component leaks greater than 10,000 ppm shall be managed in accordance with Item (vi) below, unless it is unfeasible to make the repair without shutting down the affected operation of the facility. Component leaks less than 10,000 ppm shall not require repair. For such component leaks that require a shutdown to be repaired, repair shall occur during the first shutdown of the affected operation after the leak is discovered. iii. For repair, valves adjacent to the equipment to be repaired will be closed if practicable, minimizing the volume released. iv. Repaired components shall be re-screened using AVO to determine if the leak is repaired. v. The following records shall be maintained for a period of two years: • The name of the site screened via AVO inspection and the name of the inspector. • Components evaluated with the gas detector. • Repair methods applied. AIRS ID: 123/9B39 Page 5 of 19 D Co do p e o Public Health and Environment Air Pollution Control Division • Dates of the AV1VOO inspections, gas detector calibrations, attempted repairs, successful repairs, repair delays, and post- repair screenings. vi. Leaks shall be repaired as soon as practicable, but no later than 15 calendar days after detection, unless it is technically or operationally infeasible to make the repair within 15 calendar days. Records documenting the rationale shall be maintained if it is technically or operationally infeasible to make the repair within 15 calendar days. OPERATING & MAINTENANCE REQUIREMENTS 18. Points 004, 007, and 008: 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.) 19. Points 005 and 006: This source is not required to follow a Division-approved operating and maintenance plan. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 20. Point 006: Within one hundred and eighty days (180) after issuance of this permit, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. Periodic Testing Requirements 21. Point 004: This engine may be subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. 22. Point 006: On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. ALTERNATE OPERATING SCENARIOS FOR PNEUMATIC PUMPS 23. Points 007 and 008: These pumps may be replaced with a like-kind pump in accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a revision to this permit or obtaining a new construction permit. A like-kind AIRS ID: 123/9B39 Page 6 of 19 Co kdo •, p.. e o Public Health and Environment Air Pollution Control Division replacement pump shall be the same make, model and capacity as authorized in this permit. 24. Points 007 and 008: The owner or operator shall maintain a log on-site or at a local field office to contemporaneously record the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of the replacement pump. 25. Points 007 and 008: All pump replacements installed and operated per the alternate operating scenarios authorized by this permit must comply with all terms and conditions of this construction permit. ADDITIONAL REQUIREMENTS 26. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO,) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 1. Point 004: Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative-operating scenario and is installing a permanent replacement engine. AIRS ID: 123/9B39 Page 7 of 19 D Co do p e o Public Health and Environment Air Pollution Control Division 27. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS: 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 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. 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 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. 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 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. 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 AIRS ID: 123/9B39 Page 8 of 19 Col do p e o Public Health and Environment Air Pollution Control Division 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: Oluwaseun Ogungbenle Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bonanza Creek Energy Operating Company LLC. Emission points covered under this permit include: one pump jack engine, condensate truck loadout, fugitive equipment leaks, and two pneumatic pumps. AIRS ID: 12319B39 Page 9 of 19 J Co do p e o Public Health and Environment Air Pollution Control Division 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 (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. Uncontrolled Are the Controlled AIRS Pollutant CAS# BIN Emission emissions Emission Point Rate reportable? Rate(Ib/yr) (Ib/yr) Formaldehyde 5000 A 139 No 139 Methanol 67561 C 20 No 20 Acetaldehyde 75070 A 18 No 18 004 Acrolein 107028 A 17 No 17 Benzene 71432 A 11 No 11 1,3-Butadiene 106990 A 4 No 4 Toluene 108883 C 3 No 3 n-Hexane 110543 C 491 Yes 491 Benzene 71432 A 90 No 90 005 Toluene 108883 C 177 No 177 Ethylbenzene 100414 C 39 No 39 Xylenes 1330207 C 162 No 162 Benzene 71432 A 78 No 78 Toluene 108883 C 142 No 142 006 Ethylbenzene 100414 C 30 No 30 Xylenes 1330207 C 127 No 127 n-Hexane 110543 C 422 Yes 422 AIRS ID: 12319B39 Page 10 of 19 .. ... .". ... Co do op m ° e o Public Health and Environment . . Air Pollution Control Division Uncontrolled Are the Controlled AIRS Pollutant CAS# BIN Emission emissions Emission Point Rate reportable? Rate(lb/yr) (Ib/yr) Benzene 71432 A 516 Yes 516 Toluene 108883 C 422 Yes 422 007 Ethylbenzene 100414 C 74 No 74 Xylenes 1330207 C 198 No 198 n-Hexane 110543 C 2814 Yes 2814 Benzene 71432 A 374 Yes 374 Toluene 108883 C 306 Yes 306 008 Ethylbenzene 100414 C 54 No 54 Xylenes 1330207 C 144 No 144 n-Hexane 110543 C 2046 Yes 2046 5) The emission levels contained in this permit are based on the following emission factors: Point 004: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.9197 14.7000 0.7466 2.8000 CO 1.5465 5.8000 1.2799 4.8000 VOC 0.0107 0.0400 0.0107 0.0400 5000 Formaldehyde 0.0240 0.0900 0.0240 0.0900 67561 Methanol 0.0031 0.0115 0.0031 0.0115 75070 Acetaldehyde 0.0028 0.0105 0.0028 0.0105 107028 Acrolein 0.0026 0.0099 0.0026 0.0099 71432 Benzene 0.0016 0.0059 0.0016 0.0059 106990 1,3-Butadiene 0.0007 0.0025 0.0007 0.0025 108883 Toluene 0.0006 0.0021 0.0006 0.0021 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8268 Btu/hp-hr, a site-rated horsepower value of 80, and a fuel heat value of 918 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EF Source Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 5000 Formaldehyde Manufacturer Manufacturer 67561 Methanol AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 71432 Benzene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas AIRS ID: 123/9639 Page 11 of 19 Co do p e o Public Health and Environment Air Pollution Control Division CAS Pollutant Uncontrolled EF Source Controlled EF Source 106990 1,3-Butadiene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 108883 Toluene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas Point 005: Emission Factors -Uncontrolled CAS Pollutant lb/BBL loaded Source VOC 0.203 AP-42 71432 Benzene 0.0041 Engineering Estimate 110543 n-Hexane 0.0224 Engineering Estimate The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L= 12.46*S*P*M/T S =0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) =4.99 psia M (vapor molecular weight) =68 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 weight fraction of each NCRP in the vapors by the VOC loading loss and then by the requested throughput. Point 006: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 467 0 156 130 Flanges 48 0 135 68 Open-ended Lines 25 0 11 5 Pump Seals 0 0 0 0 Valves 79 0 45 25 Other* 15 0 0 2 VOC Content(wt. 0.2601 0.0000 0.9903 1.0000 fraction) Benzene Content(wt. 0.0007 0.0000 0.0203 0.0012 fraction) Toluene Content(wt. 0.0006 0.0000 0.0398 0.0003 fraction) Ethylbenzene(wt. 0.0001 0.0000 0.0089 0.0001 fraction) Xylenes Content(wt. 0.0003 0.0000 0.0364 0.0001 fraction) n-hexane Content(wt. 0.0039 0.0000 0.1102 0.0001 fraction) *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): AIRS ID: 12319B39 Page 12 of 19 Co do a p . e o Public Health and Environment h' 41 Air Pollution Control Division Water/Oil Component Gas Service Heavy Oil Light Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas and liquids analyses. Point 007: Emission Emission Factors- Factors - Uncontrolled Controlled lb/MMscf vented lb/MMscf Source AIRS Point CAS# Pollutant vented VOC 16,385.53 819.28 All emission 71432 Benzene 44.55 2.23 factors are based 108883 Toluene 36.48 1.82 on the 007&008 100414 Ethylbenzene 6.47 0.32 displacement 1330207 Xylenes 17.05 0.85 equation and the Pronghorn T-3 wet 110543 n-Hexane 243.31 12.17 gas analysis. The displacement equation can found in "EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10- Displacement Equation (10.4-3)." Note: The emission factors above are the same for the two pneumatic pumps under points 007 and 008. Controlled emission rates are based on a combustor 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) Point 004: This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting — effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf 8) Point 004: This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf AIRS ID: 123/9B39 Page 13 of 19 Co do p e o Public Health and Environment Air Pollution Control Division Additional information regarding area source standards can be found on the EPA website at: http://www.epa.qov/ttn/atw/area/arearules.html 9) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of VOC NANSR Synthetic Minor Source of VOC PSD True Minor MACT ZZZZ Area Source Requirements:Applicable 10) 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.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 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 11) 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: 123/9839 Page 14 of 19 Co do to p a es o Public Health and Environment Air Pollution Control Division ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit(including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9B39 Page 15 of 19 Co do p e o Public Health and Environment Air Pollution Control Division 2.1.2 The owner or operator may permanently replace the existing compressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOr) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: http://www.colorado.gov/cs/Satellite/CDPHE-AP/CBON/1251596520270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. AIRS ID: 123/9639 Page 16 of 19 � r k Co itdo P p e o Public Health and Environment Air Pollution Control Division For comparison with a short-term limit that is either input based (Ib/MMBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOx and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOx and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOx or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOx and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine 2.3.1 Reasonably Available Control Technology(RACT): Reg. 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOx are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOx and SO2, as precursors to PM10, if the potential to emit of NOx or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOx: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/9639 Page 17 of 19 Co do p e o Public PollutionHealthaCdontrol DivisionEnvironment The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII.E—State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date x NO CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 500<Hp July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean bum engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § 1.B (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart 7777. An analysis of the applicable monitoring, recordkeeping, and reporting AIRS ID: 123/9B39 Page 18 of 19 Co do p e o Public Health and Environment Air Pollution Control Division requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9B39 Page 19 of 19 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Bonanza Creek Energy Operating Company LLC Permit Number: 13WE2615 Source Name: Pronghorn T-3 Production Facility Source Location: SESE Section 3, Township 5 North, Range 61 West Equipment Description: Truck loadout of condensate AIRS ID: 123-9B39-005 Review Date: December 2, 2013 Review Engineer: Oluwaseun Ogungbenle Section 2—Action Completed X CP1 Modification APEN Required/Permit Exempt Final Approval Transfer of Ownership APEN Exempt/Permit Exempt Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no" to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? January 23, 2014 Section 4—Source Description AIRS Point Equipment Description 005 Truck Condensate Loadout Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria X Yes No pollutant? If"yes", for what pollutant? PM10 CO X Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? • If"yes", for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B, Section III.D.2) Is this source located in the 8-hour ozone non- attainment region? (Note: If"yes" the provisions of X Yes No Regulation 7, Sections XII and XVII.C may apply) Is this source located at an oil and gas exploration site? X Yes No Page 1 If yes, does this source load less than 10,000 gallons of crude oil per day on an annual average, splash fill less than 6750 bbl of condensate(hydrocarbons that have Yes X No an API gravity of 40 degrees or greater)per year or submerged fill less than 16,308 bbl of condensate per year? Is this source located at a facility that is considered a major source of hazardous air pollutant(HAP) Yes X No emissions? Will this equipment be operated in any NAAQS nonattainment area? X Yes No Does this source load gasoline into transport vehicles? Yes X No Section 5—Emission Estimate Information AIRS Point Emission Factor Source AP-42: Chapter 5.2, Equation 1 L= 12.46'S'P'M/T 005 L = loading losses in lb per 1000 gallons loaded S= Saturation Factor P=true vapor pressure of liquid loaded [psia] M =molecular weight of vapors [lb/lb-mole] T=temperature of bulk liquid loaded [deg. R] Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/Throughput/Production 005 21,900 BBL per year condensate loaded Basis for Actual Emissions Reported During this APEN Filing(Reported to Inventory) AIRS Point Process Consumption/Throughput/Production 005 Applicant did not provide actual process data Basis for Permitted Emissions(Permit Limits' AIRS Point Process Consumption/Throughput/Production 005 21,900 BBL per year condensate loaded Does this source use a control device? Yes X No Section 6—Emission Summary (tons per year) Point NO, VOC CO Single HAP HAP PTE: 005 2.2 0.25 (n-Hexane) 0.5 Uncontrolled point --- --- —source emission rate --- Permitted point source 005 2.2 0.25(n-Hexane) 0.5 emission rate: Section 7—Non-Criteria/Hazardous Air Pollutants Uncontrolled Arethe Controlled Emission Pollutant CAS# BIN Emission Rate emissions (Ib/yr) reportablei Rate(iblyr) Benzene 71432 A 90 No N/A n-Hexane 110543 C 491 Yes N/A Page 2 Toluene 108883 C 177 No N/A Ethylbenzene 100414 C 39 No N/A Xylenes 1130207 C 162 No N/A Note: Regulation 3, Part A, Section ll.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory Yes X No standard? • Section 9—Source Classification Is this a new previously un-permitted source? X Yes No What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V PSD X NA NSR MACT Is this a modification to an existing permit? Yes X No If"yes"what kind of modification? Minor Synthetic Major Minor Section 10—Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes", for which pollutants?Why? VOC For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? Yes No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 —Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards (NAAQS)? AIRS Point Section 12—Regulatory Review Regulation 1 - Particulate, Smoke, Carbon Monoxide and Sulfur Dioxide Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of 005 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.) 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 005 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Page 3 Regulation 3-APENs, Construction Permits. Operating Permits, PSD Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: each individual emission point in a nonattainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant (pollutants are not summed) for which the area is nonattainment. (Applicant is required to file an APEN since emissions exceed 1 ton per year VOC) Part B—Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold(Reg. 3, Part B, Section II.D.3.a) 005 Part B, III.D.2-RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is located in the 8-hour ozone nonattainment area, but not the 1-hour ozone area. The date of interest for determining whether the source is new or modified is,therefore, November 20, 2007(the date of the 8-hour ozone NA area designation). Since this loadout operation commenced after the date above, this source is considered "new or modified." Operator is using submerged fill (0.6 saturation factor), therefore, RACT requirements are satisfied. Regulation 6-New Source Performance Standards 005 No applicable subpart. This facility is not a bulk gasoline terminal. Regulation 7—Volatile Organic Compounds No sections apply. Per Regulation 7, Section VI.C, a terminal is defined as a petroleum liquid storage and distribution facility that has a daily average throughput of more than 005 76,000 liters of gasoline(20,000 gallons), which is loaded directly into transport vehicles. This facility is neither a terminal, nor a bulk plant per definitions in Reg. 7, Section VI.C. Regulation 8—Hazardous Air Pollutants MACT EEEE: 005 This source is not subject to MACT EEEE because it is a minor source of HAPs and its also located at a production field facility and thus exempt per 40CFR 63.2334(c)(1). Section 13—Aerometric Information Retrieval System Coding Information Process/ Emission Process Emission Pollutant/ Fugitive Control Point Process Description throughput Factor CAS# (y N) Factor (%) Limit Source 4.84 01 Truck Condensate 21,900 lb/1,000 VOC No AP-42 0 Loadout BBL/yr gallon 005 throughput SCC 40600132: Crude Oil: Submerged Loading (Normal Service) Page 4 Section 14— Miscellaneous Application Notes AIRS Point 002 Truck Condensate Loadout Units Basis S 0.6 n/a Submerged loading: dedicated normal service based on source's description P 4.99 Psia Based on regression analysis for crude oil (AP-42 Chapter 7.1 page 56) and a Reid vapor pressure of 7.1 psia M 68 Lb/lb-mole Molecular weight of vapors based on AP-42, Chapter 7, Table 7.1-2 (using an RVP of 7.1) T 524 Deg R Based on EPA TANKS Meteorological Database for Denver, CO L 4.84 Lb/10'gal This value is used to calculate annual emissions 2.03 E-01 Lb/bbl This value is used to calculate annual emissions AP-42: Chapter 5.2 Equation 1 L = 12.46*S*P*M/T L= loading losses in lb per 1000 gallons loaded S = Saturation Factor P =true vapor pressure of liquid loaded [psia] M = molecular weight of vapors [lb/lb-mole] T =temperature of bulk liquid loaded [deg. R] L 4.841b/103 gal 2.03E-01 lb/bbl Annual requested Throughput 919800 gal/yr Annual requested VOC emissions 4453 lb/yr 2.23 tpy Page 5 The Division has identified an issue with BCEOC's determination of the molecular weight of displaced vapors. This piece information is used in estimating loadout emissions according to Equation 1 above. The Division believes BCEOC is underreporting this value (for this and a number of other loadout operations). It appears that the E&P Tanks results from which this value is obtained is based on un- stabilized oil (condensate) sample analysis rather than a stabilized sample analysis. For example, the molecular weight used to calculate emissions from this loadout operation (40.84 Ib/Ib-mol) is more representative of the lighter hydrocarbons (particularly C3). The Division believes that once the condensate is stabilized, prior to being trucked off, the lighter hydrocarbons will have flashed off leaving behind the heavier hydrocarbons. In light of this, the Division assumed the molecular weight used in calculating loadout emissions should be more representative of the heavier remnant hydrocarbons. Chris Laplante brought this to BCEOC's attention and after a protracted discussion on this issue, BCEOC agreed to the Division's proposal concerning the proper methodology for determining the molecular weight of the displaced vapors. The Division gave BCEOC the option of either interpolating this number from AP-42, Chapter7, Table 7.1-2 or determining it from the analysis of a sales oil sample. A correspondence received from James Van Home (one of BCEOC's permit contacts)on 01/23/2014 reads: "The division has decided to that truck loading vapor MW need to either be based on AP-42 OR a sales oil sample and Raoult's Law. More details are provided in the attached email. Since we do not have sales gas analysis these emissions will be calculated using the data in AP-42. Based on RVP of 7.1 I calculate that the appropriate vapor MW is 68 lb/lb-mole. This is projected to increase Load out emission up to 2.2 tpy. I have attached revised Calcs,APCD-102 form and APEN form." • Page 6 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Bonanza Creek Energy Operating Company LLC Permit Number: 13WE2615 Source Name: Pronghorn T-3 Production Facility Source Location: SESE Section 3, Township 5 North, Range 61 West Fugitive Component Leak Emissions from Well head, heater treater, Equipment Description: enclosed combustors, condensate tanks, produced water tanks, and gas meter house. AIRS ID: 123-9839-006 Date: November 29, 2013 Review Engineer: Oluwaseun Ogungbenle Control Engineer: Chris Laplante Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X Initial Approval Transfer of Ownership APEN Exempt/Permit Exempt Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no" to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? August 6, 2013 Section 4—Source Description AIRS Point Equipment Description 006 Fugitive VOC leak emissions Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria X Yes No pollutant? If"yes", for what pollutant? Mc) CO X Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B, Section 111.8.2) Is this source located in the 8-hour ozone non- attainment region? (Note: If"yes" the provisions of X Yes No Regulation 7, Sections XII and XVII.C may apply) Page 1 Section 5—Emission Estimate Information AIRS Point Emission Factor Source 006 EPA-453/R-95-017,Table 2-4 Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit(PTEI AIRS Point Process Consumption/Throughput/Production Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 467 --- 156 130 006 Flanges 48 --- 135 68 Open-Ended Lines 25 --- 11 5 Pump Seals 0 --- 0 0 Valves 79 -- 45 25 Other 15 — 0 2 Basis for Actual Emissions Reported During this APEN Filing(Reported to Inventorvi AIRS Point Process Consumption/Throughput/Production 006 Applicant did not provide actual process data Basis for Permitted Emissions(Permit Limit$ AIRS Point Process Consumption/Throughput/Production Equipment Type Gas Heavy Oil Light Oil (or Water/Oil (or Heavy Light Liquid) Liquid) Connectors 467 --- 156 130 006 Flanges 48 --- 135 68 Open-Ended Lines 25 --- 11 5 Pump Seals 0 --- 0 0 Valves 79 -- 45 25 Other 15 --- 0 2 Does this source use a control device? Yes X No Section 6—Emission Summary (tons per year) Point NOX VOC CO Single HAP Total HAP PTE: 006 --- 3.76 — 0.21 (n-Hexane) 0.4 Uncontrolled point -- --- --- --- --- source emission rate: --- Permitted point source 006 3.8 0.2 (n-Hexane) 0.4 emission rate: Section 7—Non-Criteria/Hazardous Air Pollutants Uncontrolled Amte Controlled Emission Pollutant CAS# BIN Emission Rate embuione (lblyr) reportable? Rate(Iblyr) Benzene 71432 A 78 No 78 Toluene 108883 C 142 No 142 Ethylbenzene 100414 C 30 No 30 Xylenes 1330207 C 127 No 127 n-Hexane 110543 C 422 Yes 422 Page 2 Note: Regulation 3, Part A, Section lI.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory Yes X No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method Section 9—Source Classification Is this a new previously un-permitted source? X Yes No What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V PSD X NA NSR MACT Is this a modification to an existing permit? Yes X No If"yes"what kind of modification? Minor Synthetic Major Minor Section 10— Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes", for which pollutants?Why?VOC For Reg. 3, Part B, III.C.1.a (emissions increase> 25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? Yes No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 —Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards (NAAQS)? If"yes", for which pollutants?Why? AIRS Point Section 12— Regulatory Review Requlation 1 - Particulate Smoke, Carbon Monoxide and Sulfur Dioxide Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which 006 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 006 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Page 3 Regulation 3-APENs, Construction Permits, Operating Permits, PSD Part A-APEN Requirements Criteria Pollutants: For criteria pollutants,Air Pollutant Emission Notices are required for: 006 each individual emission point in a nonattainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant(pollutants are not summed) for which the area is nonattainment. (Applicant is required to file an APEN since emissions exceed 1 ton per year VOC) Part B—Construction Permit Exemptions 006 Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold(Reg. 3,Part B, Section II.D.3.a) Part B, III.D.2-RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is located in the 8-hour ozone nonattainment area. The date of interest for determining whether the source is new or modified is therefore 006 November 20, 2007(the date of the 8-hour ozone NA area designation). Since the fugitives became operational after the date of interest above, this source is considered "new." Operator has agreed on the Division's standard conditions. These fugitive component leaks are not subject to NSPS KKK and no LDAR program is in place at the facility. Therefore, operator will have to comply with Division-developed Direct inspection & Maintenance Program to satisfy RACT requirements. These requirements are contained in the permit. Operator has agreed to the Division's standard conditions. Regulation 6-New Source Performance Standards NSPS KKK: Equipment Leaks of VOC from onshore natural gas processing plants. Affected facilities at onshore natural gas facilities (any processing site engaged in the extraction of natural gas liquids from field gas,fractionation of mixed natural gas liquids (NGLs)or both). 006 Is this source at a"natural gas processing plant?" No Is this source subject to NSPS KKK? No This source is not located at a natural gas processing plant;therefore, it is not subject to the requirements of NSPS KKK. NSPS OOOO: Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution. For fugitive emissions at natural gas processing plants subject to NSPS OOOO. This subpart establishes emission standards and compliance schedules for the control of volatile organic compounds(VOC)and sulfur dioxide (8O2 )emissions from affected facilities that commence construction, 006 modification or reconstruction after August 23, 2011. Is this source at a"natural gas processing plant?" No Is this source subject to NSPS OOOO? No This source is not located at a natural gas processing plant; therefore, it is not subject to the requirements of NSPS OOOO. Regulation 7—Volatile Organic Compounds Section XII.G: If facility is a natural gas processing plant located in non-attainment area,then subject to Section XII.G. 006 Although this facility is in a non-attainment area, it is not subject to the requirements of this section because it is not considered a natural gas processing plant. Regulation 8—Hazardous Air Pollutants Page 4 MACT HH: If facility is MAJOR source for HAP at a natural gas processing plant ONLY (summation of HAPS of dehydrators and fugitives), then fugitive emissions are subject to MACT HH. 006 Is this facility considered MAJOR for HAPS? No Is this source subject to MACT HH? No This facility is not considered a major source of HAPs; therefore, it is not subject to the requirements of MACT HH. Section 13—Aerometric Information Retrieval System Coding Information Point Process Process Description Pollutant/ Fugitive Emission Factor Control CAS# (Y/N) Source (%) 006 01 Fugitive V0C Leak V0C Yes EPA-453/R-95-017, NA Emissions Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves,flanges, connections,seals, drains) Section 14—Miscellaneous Application Notes AIRS Point 006 Fugitive VOC Leak Emissions A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY (permit threshold). This emission point will be covered under a facility wide permit(13WE2615). The extended natural gas and extended natural gas liquids analyses submitted with this application were both less than a year old at the time of submittal. Therefore, neither a natural gas analysis nor a natural gas liquids analysis will be required in the permit as part of initial compliance testing. The Division's standard DI&M plan for component leaks at E&P sites requires that AVO inspection be conducted on a quarterly basis. However, BCEOC requested that this be done on a semi-annual basis in conformity with other BCEOC permits. I checked this with Carissa Money and she confirmed that the Division has indeed agreed to semi-annual AVO inspections for BCEOC. • Page 5 Division Information Engineer: Oluwaseun Ogungbenle Control Engineer: Chris Laplante Review Date: 11/27/2013 Application Date: 08/06/2013 Facility Identifiers Permit No. 13WE2615 Potentially Located within EAC-determine attainmi County# 123 weld Attainment Status AIRs Facility# 9B39 PM10 Attainment Point# 007 PM2.5 Attainment Facility Equipment ID Pump 1 SOx Attainment NOx Nonattainment VOC Nonattainment CO Attainment Section 01: Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: Pronghorn T-3 Production Facility SESE Section 3, Township 5N, Range 61W Source Location: Approximately 14.2 miles NW of Wiggins, CO SIC: 1311 Elevation (feet) 4,753 Address 1: Bonanza Creek Energy Operating Company LLC Mailing ,� Address Address 2: 410 17 Street, Suite 1500 'ity, State Zip: Denver, CO 80202 Name: Peg Young Person To Phone: 720-440-6133 Contact Fax: 720-279-2331 Email: Pyounq(a7BonanzaCrk.com Section 02: Requested Action X New permit/ newly reported emission source Request Mod-Change fuel/equipment Request Mod-Change permit limit Request Mod -Change company name Request Mod -Transfer of ownership Request Mod -Other 'Request to limit HAPs with federally enforceable limits Issuance Number: 1 Add'I Info and This is one of two Sandpiper G20 pneumatic pumps at this facility. notes: Section 03: General Facility Information For existing sources, operation began on: n/a For New/recon sources, projected startup date: 5/8/2013 Normal hours of operation: 24 hrs/day 7 days/wk 10 weeks/yr General description of equipment purpose: This emission unit will be used for water transfer. Will this equipment be operated in any nonattainment area?IYes Section 04: Pump Information Manufacturer: Sandpiper Model G20 Number: Serial 2076866 Pump Number: Information Pump capacity 25.2 gallons per minute pumped natural gas 1320 scf/hour used consumption Section 05: Emission Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II, Chapter 10- Displacement Equation (10.4 Ex=Q* MW * Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW= Molecular weight of gas=SG of gas * MW of air Xx= mass fraction of x in gas C= molar volume of ideal gas (379 scf/lb-mol)at 60F and 1 atm Q 1320 sdf/hr MW 23.9 Ib/Ib-mol Hours of Op. 8760 hours/yr Requested Throughput 11.6 Component mole% MW mass fraction Component lb/hr lb/yr propane 7.5946 44.09 0.1401 propane 11.662 102160.693 isobutane 0.652 58.12 0.0159 isobutane 1.320 11561.443 n-butane 1.9402 58.12 0.0472 n-butane 3.927 34404.158 isopentane 0.334 72.15 0.0101 isopentane 0.839 7352.273 n-pentane 0.4241 72.15 0.0128 n-pentane 1.066 9335.626 n-hexane 0.102 86.18 0.0037 n-hexane 0.306 2681.918 cyclohexane 0.0273 84.18 0.0010 cyclohexane 0.080 701.149 Other hexanes 0.1727 86.18 0.0062 Other hexanes 0.518 4540.855 heptanes 0.0945 100.21 0.0040 heptanes 0.330 2889.227 methylcyclohex 0.0225 98.19 0.0009 methylcyclohe 0.077 674.045 224-TMP 0.0001 114.22 0.0000 224-TMP 0.000 3.485 Benzene 0.0206 78.11 0.0007 Benzene 0.056 490.922 Toluene 0.0143 92.14 0.0006 Toluene 0.046 401.997 Ethylbenzene 0.0022 106.17 0.0001 Ethylbenzene 0.008 71.263 Xylenes 0.0058 106.17 0.0003 Xylenes 0.021 187.875 C8+ Heavies 0.0674 315 0.0089 C8+ Heavies 0.739 6477.528 Mass Fraction VOC: 0.2522 Total Total 91.967 tpy VOC Notes Mole%, MW,and mass fractions from extended gas analysis from Pronghorn T-3 facility dated 7/29/2013 Scenario A CAS# Total (Ib/yr) Bin Reportable? n-hexane 110543 2681.9 C Yes 224-TMP 540841 3.5 C No Benzene 71432 490.9 A Yes Toluene 108883 402.0 C Yes E-Benzene 100414 71.3 C No Xylenes 1330207 187.9 C No Resultant Emission Factors VOC 15906.882 lb/MMscf natural gas used Benzene 42.456 lb/MMscf natural gas used n-hexane 231.936 lb/MMscf natural gas used Toluene 34.765 lb/MMscf natural gas used E-Benzene 6.163 lb/MMscf natural gas used Xylenes 16.248 lb/MMscf natural gas used 224-TMP 0.301 lb/MMscf natural gas used ant status of NOx and VOC -3) M Mscf/yr tpy 51.080 5.781 17.202 3.676 4.668 1.341 0.351 2.270 1.445 0.337 0.002 0.245 0.201 0.036 0.094 3.239 91.967 Division Information Engineer: Oluwaseun Ogungbenle Control Engineer: Chris Laplante Review Date: 11/29/2013 Application Date: 08/06/2013 Facility Identifiers Permit No. 13WE2615 Potentially Located within EAC -determine attainmi County# 123 weld Attainment Status AIRs Facility# 9B39 PM10 Attainment Point# 008 PM2.5 Attainment Facility Equipment ID Pump 2 SOx Attainment NOx Nonattainment VOC Nonattainment CO Attainment Section 01: Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: Pronghorn T-3 Production Facility SESE Section 3, Township 5N, Range 61W Source Location: Approximately 14.2 miles NW of Wiggins, CO SIC: 1311 Elevation (feet) 4,753 Address 1: Bonanza Creek Energy Operating Company LLC Mailing Address 2: 410 17th Street, Suite 1500 Address .ity, State Zip: Denver, CO 80202 Name: Peg Young Person To Phone: 720-440-6133 Contact Fax: 720-279-2331 Email: PyounqaBonanzaCrk.com Section 02: Requested Action X New permit/ newly reported emission source Request Mod -Change fuel/equipment Request Mod -Change permit limit Request Mod -Change company name Request Mod -Transfer of ownership Request Mod -Other 'Request to limit HAPs with federally enforceable limits Issuance Number: 1 Add'I Info and This is one of two Sandpiper G20 pneumatic pumps at this facility. notes: Section 03: General Facility Information For existing sources, operation began on: n/a For New/recon sources, projected startup date: 5/8/2013 Normal hours of operation: 24 hrs/day 7 days/wk 10 weeks/yr General description of equipment purpose: This emission unit will be used for heat trace. Will this equipment be operated in any nonattainment area?lYes Section 04: Pump Information Manufacturer: Sandpiper Model G20 Number: 2004232 Pump Serial Number: Information Pump capacity 16.8 gallons per minute pumped natural gas 960 scf/hour used consumption Section 05: Emission Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation (10.4 Ex=Q* MW * Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW= Molecular weight of gas =SG of gas * MW of air Xx= mass fraction of x in gas C= molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm Q 960 scf/hr MW 23.9 Ib/Ib-mo l Hours of Op. 8760 hours/yr Requested Throughput 8.4096 Component mole% MW mass fraction Component lb/hr lb/yr propane 7.5946 44.09 0.1401 propane 8.482 74298.686 isobutane 0.652 58.12 0.0159 isobutane 0.960 8408.322 n-butane 1.9402 58.12 0.0472 n-butane 2.856 25021.206 isopentane 0.334 72.15 0.0101 isopentane 0.610 5347.108 n-pentane 0.4241 72.15 0.0128 n-pentane 0.775 6789.546 n-hexane 0.102 86.18 0.0037 n-hexane 0.223 1950.486 cyclohexane 0.0273 84.18 0.0010 cyclohexane 0.058 509.927 Other hexanes 0.1727 86.18 0.0062 Other hexanes 0.377 3302.440 heptanes 0.0945 100.21 0.0040 heptanes 0.240 2101.256 methylcyclohex 0.0225 98.19 0.0009 methylcyclohe 0.056 490.214 224-TM P 0.0001 114.22 0.0000 224-TMP 0.000 2.534 Benzene 0.0206 78.11 0.0007 Benzene 0.041 357.034 Toluene 0.0143 92.14 0.0006 Toluene 0.033 292.362 Ethylbenzene 0.0022 106.17 0.0001 Ethylbenzene 0.006 51.828 Xylenes 0.0058 106.17 0.0003 Xylenes 0.016 136.636 C8+ Heavies 0.0674 315 0.0089 C8+ Heavies 0.538 4710.929 Mass Fraction VOC: 0.2522 Total Total 66.885 tpy VOC Notes Mole%, MW, and mass fractions from extended gas analysis from Pronghorn T-3 facility dated 7/29/2013 Scenario A CAS# Total (Ib/yr) Bin Reportable? n-hexane 110543 1950.5 C Yes 224-TMP 540841 2.5 C No Benzene 71432 357.0 A Yes Toluene 108883 292.4 C Yes E-Benzene 100414 51.8 C No Xylenes 1330207 136.6 C No Resultant Emission Factors VOC 15906.882 lb/MMscf natural gas used Benzene 42.456 lb/MMscf natural gas used n-hexane 231.936 lb/MMscf natural gas used Toluene 34.765 lb/MMscf natural gas used E-Benzene 6.163 lb/MMscf natural gas used Xylenes 16.248 lb/MMscf natural gas used 224-TMP 0.301 lb/MMscf natural gas used ant status of NOx and VOC -3) M Mscf/yr tpy 37.149 4.204 12.511 2.674 3.395 0.975 0.255 1.651 1.051 0.245 0.001 0.179 0.146 0.026 0.068 2.355 66.885 S n LZ e = C N E It d`o Ed a c a —v Z a co in -w O a_ G w a z. 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