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Home My WebLink About20182047.tiffCOLORADO Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 O St PO Box 758 Greeley, CO 80632 June 25, 2018 Dear Sir or Madam: J RECEIVED JUN 2 7 2018 WELD COUNTY COMMISSIONERS On June 28, 2018, the Air Pollution Control Division will begin a 30 -day public notice period for Bill Barrett Corporation - Peterson 5-63-30 SWNE. 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 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer ?L( IMv+, ITP) , � L C TT' ?w ( ERICH isin!CI of -aq-18 2018-2047 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Bill Barrett Corporation - Peterson 5-63-30 SWNE - Weld County Notice Period Begins: June 28, 2018 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: Bill Barrett Corporation Facility: Peterson 5-63-30 SWNE Exploration and production SWNE Section 30, T5N, R63W Weld County The proposed project or activity is as follows: Synthetic minor facility with one existing process stream (called GW) and one new process stream. The new process stream includes two natural gas RICEs, condensate and produced water tank batteries, emissions from hydrocarbon loadout, and separator flaring during gas pipeline collection system downtime. This project includes all points in the new process stream. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and drafts of Construction Permits 17WE1267, 17WE1268, 17WE1269, 17WE1270, 17WE1271, and 18WE0322 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: Betsy Gillard, PE Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us (COLORADO 1 I ! Departmente, tic Health(' Emiromeot Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Package #: Received Date: Review Start Date: Betsy Gillard 372279 12/8/2017 3/19/2018 Section 01- Facility Information Company Name: Bill Barrett Corporation County AIRS ID: 123 Plant AIRS ID: 7168 Facility Name: Peterson 5-63-30 SWNE Physical Address/Locatio SWNE quadrant of Section 30, Township 5N, Range 63W, in Weld County, Colorado Type of Facility: Exploration & Production Well Pad What industry segment? Oil & Natural Gas Production & Processing Is this facility located in a NAAQS non -attainment area? ` Yes � If yes, for what pollutant? Bon Monnede (CO) Pa ;Dilate Matter (PM) L� e (NOx rf WC) Weld Quadrant Section Township Range SWNE; 30 EN 63 Section 02 - Emissions Units In Permit Application AIRS Point # Emissions Source Type Equipment Name Emissions Control? Permit# Issuance # Self Cert Required? Action Engineering Remarks 001 Condensate Tank GW Tank Battery Yes 17WE1266.XP 1 No APEN Required / Permit Exempt Previously GP01 004 Natural Gas RICE C-17696/1 Yes 17WE1267 1 Yes Permit.Initial =Issuance 005 Natural Gas ??ICE G P02 Cancellation No longer exists 006 Condensate Tank Condensate Tank Battery Yes 17WE1268 1 Yes Permit initial Issuance t 007 Produced Water Tank Produced Water Tanks yes 17WE1269 1 Yes Permit Initial issuance. 008 Separator Venting Steffes Flare Yes 17WE1270 1 Yes Permit Initial. Issuance 009 Natural GasRI t C-13160/1 Yes 17WE1271 1 Yes Permit Initial Issuance 010 Hydrocarbon liquid Loading Hydrocarbon Loadout Yes 18WE0322 1 Yes Permit Initial issuance Section 03 - Description of Project Synthetic minor facility with two process strea i with "GW"). The original process stream, called "OW'includes loadout, watert and condensateta nks (all names are prefaced Point001 was initially permitted under a 0501. On 12/8/2017, BBC requested an individual perm for the point. On 3/23/2018, BBC sent a new APEN requesting an XP letter for the point, as decreased throughput make emissions fall below permit thresholds. Operator submitted APEN for Hydrocarbon Loadout, was mistakenly assigned in PTS as Point 002 (which is GW Tank Truck Loadout, and is permit -exempt). Corrected in PTS: New Loadout is now Point 010. No changes were made to Point 002. Section 04 - Public Comment Requirements Is Public Comment Required? Yes If yes, why? Greater than 25 tons put yPar in Non -Attainment Area Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? Plo If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) Is this stationary source a major source? 502 NOx CO VOC PM2.5 PM10 TSP HAPs J J ❑ ❑J 004 One (1) Waukesha L7044GS1, Serial Number C-17696/1, natural gas -fired, turbocharged 4SRB reciprocating internal combustion engine, site rated at 1680 horsepower at 1200 RPM. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Engine Information Engine date of mfg 8/4/2007 Manufacturer: Waukesha Model Number: L7044GSI Serial Number: C-17696/1 RPM: 1200 Site -rated RPM: 1200 Engine Function Compression Mfg's Max. Rated Horsepower @ sea level: 1680 Derating Horsepower used for calcuations: 1680 BSCF @ 100% Load (btu/hp-hr): 7744 Site - Rated BSCF @ 100% load (btufhp-hr): 7744 Other Parameters Engine Type 4SRB Aspiration turbo -charged Electrical Generator Max Site Rating (kw) 0 Max hrs/yr of Operation 8760 Calculations Fuel Use Rate @ 100% Load 13523.82536 scf/hr ACTUAL Annual Fuel Consumption 0 MMscf/yr MAX HOI LN I IALAnnuafhuei Consumption 118.469 MMscf/yr REQUESTED Annual Fuel Consumption 118.469 MMscf/yr Fuel Heating Value 962 btu/scf Emission Control Information This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. NOTES Initial testing for'NOxand CO will be required, becaus is syn minor for NOx and CO and ,>500 hp. BSFC an uncontrolled CO & NOx emission factors are frorri. manufacture spec sheet. VOC EF on manufacturer spec sheei Is 035 g/hp-hr, operator used NSPS Mil limit of 0.7 g/hp-hr. Controlled NOx and CO EFs are from Emit Techno ogles specification sheet. Tney will be verified with a stack test.' e source Operator calculated uncontrolled emissions using a throuforengii18 MMscghputf/yr. Reofque119stedMMscf/throughputbut and uncontrolled ne emisss 1 i80. o.5ns on APEN were .redlined with operator consent. Operator requested removal of "Emission and Operating imitations"section from Condition 13,1 removed it since this facility isn't major for kIAPs. Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source NOx 13.300 g/hp-hr 0.600 g/hp-hr 215.3 tpy 9.7 tpy Manufacturer CO 11.200 g/hp-hr 1.000 g/hp-hr 181.3 tpy 16.2 tpy Manufacturer VOC 0.700 g/hp-hr 0.700 g/hp-hr 11.3 tpy 11.3 tpy NSPS JJJJ Formaldehyde 0.050 g/hp-hr 0.012 g/hp-hr 1619 lb/yr 389 lb/yr AP -42 Acetaldehyde 0.0028 lb/MMBTU 0.003 Ib/MMBTU 319 lb/yr 319 lb/yr AP -42 Acrolein 0.0026 Ib/MMBTU 0.003 Ib/MMBTU 296 lb/yr 296 lb/yr AP -42 Methanol 0.0031 Ib/MMBTU 0.003 Ib/MMBTU 353 lb/yr 353 lb/yr AP -42 Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT ZZZZ Facility is an area source of HAPs, so engine is not subject to major source requirements. Engine is existing Reg 7 XVII.E.2 Standards The engine is not subject to Reg 7 because it is subject to MACT ZZZZ and NSPS JJJJ Reg 7 XVII.E.3 The engine is subject to Reg 7 X\/II.E.3 because the engine is rated greater than 500 hp Reg 7 XVI.B applies? Engine is subject to Reg 7 XVI.B MACT 7777 (area Is this engine subject to MACT ZZZZ area source requirements? Yes source) NSPS JJJJ Is this engine subject to NSPS JJJJ? I Yes Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. 17 WE 1267.CP1.xlsm CONSTRUCTION PERMIT Permit number: Date issued: Issued to: 17WE1267 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Bill Barrett Corporation Peterson 5-63-30 SWNE 123/7168 SWNE SEC 30 T5N R63W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description C-17696/1 004 One (1) Waukesha L7044GSI, Serial Number: C17696/1, natural gas -fired, turbo -charged 4SRB reciprocating internal combustion engine, site rated at 1680 horsepower. This emission unit is used for natural gas compression. Non selective catalytic reduction (NSCR) system and air -fuel ratio control This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Waukesha L7044GSI engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS) included in this permit as Attachment A. 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 the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) 2. 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 COLORADO Air Pollution Control Division Page 1 of 16 of thi ' construction permit or the date on which such duled to ommence as set forth in the permit application iat- _ h -r conti onstruction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 3. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 4. 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 5. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO, VOC CO C-17696/1 004 -- 9.7 11.3 16.2 Point Note: 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 not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits for both criteria and hazardous air pollutants shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 6. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device - Pollutants Controlled C 17696/1 004 Non -selective catalytic reduction (NSCR) system and air -fuel ratio control NOx, CO, HAPs PROCESS LIMITATIONS AND RECORDS 7. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits ;COLORADO Air Pollution Control Division ueuast nr t of tYuhE _ biet;;tn. v E- _agannrent Page 2 of 16 Epm ; t '; •'pmt roces .Parameter Annual Limit C-17696/1 004 Natural Gas Consumption 118.5 MMscf Fuel consumption shall be measured by one of the following methods: individual engine fuel meter or facility -wide fuel meter attributed to fuel consumption rating and hours of operation. 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 8. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 9. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. Et 4.) 10. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 11. This equipment is subject to the control requirements for stationary and portable engines in the 8 -hour ozone control area under Regulation 7, Section XVI.B.1. For rich burn reciprocating internal combustion engines, a non -selective catalyst reduction system and an air -fuel ratio controller shall be required. 12. This source is subject to the requirements of: • Regulation No. 8, Part E , Subpart III.FFFF: National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (RICE) of 40 C.F.R. Part 63, Subpart ZZZZ, and • Regulation No. 8, Part E, Subpart I.A, National Emission Standards for Hazardous Air Pollutants for Source Categories: General Provisions, 40 CFR Part 63 including, but not limited to, the following: • General Compliance Requirements o §63.6605(a) - You must be in compliance with the emission limitations and operating limitations in this subpart that apply to you at all times, except during periods of startup, shutdown, and malfunction. o §63.6605(b) - If you must comply with emission limitations and operating limitations, you must operate and maintain your stationary RICE, including air pollution control and monitoring equipment, in a manner consistent with good air pollution control practices for minimizing emissions at all times, including during startup, shutdown, and malfunction. • Testing and Initial Compliance Requirements o §63.6610(a) - You must conduct the initial performance test or other initial compliance demonstrations in Table 4 to Subpart ZZZZ of Part 63 that apply to you within 180 days after the compliance date that is specified for your stationary RICE in §63.6595 and according to the provisions in §63.7(a)(2). COLORADO Air Pollution Control. Division r,r nt Pa*c HC£ n v E:^vttoraxr t Page 3 of 16 e emission limitations and operating limitations, ance tests semiannually (as per Table 3 of e demonstrated compliance for two consecutive tests, you may reduce the frequency of subsequent performance tests to annually. If the results of any subsequent annual performance test indicate the stationary RICE is not in compliance with the CO or formaldehyde emission limitation, or you deviate from any of your operating limitations, you must resume semiannual performance tests. o §63.6625(a) - If you elect to install a CEMS as specified in Table 5 of this subpart, you must install, operate, and maintain a CEMS to monitor CO and either oxygen or CO2 at both the inlet and the outlet of the control device according to the requirements in paragraphs 63.6625(a)(1) through 63.6625(4) of Subpart ZZZZ to Part 63. o §63.6625(b) - If you are required to install a continuous parameter monitoring system (CPMS) as specified in Table 5 of this subpart, you must install, operate, and maintain each CPMS according to the requirements in §63.8. o §63.6630(a) - You must demonstrate initial compliance with each emission and operating limitation that applies to you according to Table 5 of Subpart ZZZZ to Part 63. o §63.6630(b) - During the initial performance test, you must establish each operating limitation in Tables lb and 2b of Subpart ZZZZ to Part 63 that applies to you. o §63.6630(c) - You must submit the Notification of Compliance Status containing the results of the initial compliance demonstration according to the requirements in §63.6645. • Continuous Compliance Requirements o §63.6635(b) - Except for monitor malfunctions, associated repairs, and required quality assurance or control activities (including, as applicable, calibration checks and required zero and span adjustments), you must monitor continuously at all times that the stationary RICE is operating. o §63.6635(c) - You may not use data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities in data averages and calculations used to report emission or operating levels. You must, however, use all the valid data collected during all other periods. o §63.6640(a) - You must demonstrate continuous compliance with each emission limitation and operating limitation in Tables la and 1b and Tables 2a and 2b of subpart ZZZZ of Part 63 that apply to you according to methods specified in Table 6 of Subpart ZZZZ of Part 63. o §63.6640(b) - You must report each instance in which you did not meet each emission limitation or operating limitation in Tables 1a and 1b and Tables 2a and 2b of Subpart ZZZZ of Part 63 that apply to you. These instances are deviations from the emission and operating limitations in this subpart. These deviations must be reported according to the requirements in §63.6650. If you change your catalyst, you must reestablish the values of the operating parameters measured during the initial performance test. When you reestablish the values of your operating parameters, you must also conduct a performance test to demonstrate that you are meeting the required emission limitation applicable to your stationary RICE. o §63.6640(d) - Consistent with §§63.6(e) and 63.7(e)(1), deviations from the emission or operating limitations that occur during a period of startup, shutdown, or malfunction are not violations if you demonstrate to the Administrator's satisfaction that you were operating in accordance with §63.6(e)(1). For new, reconstructed, and rebuilt stationary RICE, deviations from the emission or operating limitations that occur during COLORADO Air Pollution Control Division ur kl4. ki Yh 6 Grim M5rl Page 4 of 16 engine startup (engine burn -in period) are not § •4i ou repo instance in which you did not meet the requirements in Table 8 of Subpart ZZZZ to Part 63 that apply to you. • Notifications, Reports and Records o §63.6645(a) - If you own or operate a stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions you must submit alt of the notifications in §563.7(b) and (c), 63.8(e), (f)(4) and (f)(6), 63.9(b) through (e), and (g) and (h) that apply to you by the dates specified. o §63.6645(g) - If you are required to conduct a performance test, you must submit a Notification of Intent to conduct a performance test at least 60 days before the performance test is scheduled to begin as required in §63.7(b)(1). o §63.6645(h) - If you are required to conduct a performance test or other initial compliance demonstration as specified in Tables 4 and 5 of Subpart ZZZZ to Part 63, you must submit a Notification of Compliance Status according to §63.9(h)(2)(ii). • §63.6645(h)(1) - For each initial compliance demonstration required in Table 5 of Subpart ZZZZ to Part 63 that does not include a performance test, you must submit the Notification of Compliance Status before the close of business on the 30th day following the completion of the initial compliance demonstration. • 563.6645(h)(2) - For each initial compliance demonstration required in Table 5 of Subpart ZZZZ to Part 63 that includes a performance test conducted according to the requirements in Table 3 to this subpart, you must submit the Notification of Compliance Status, including the performance test results, before the close of business on the 60th day following the completion of the performance test according to §63.10(d)(2). o 563.6650(a) - You must submit each report in Table 7 of Subpart ZZZZ to Part 63 that applies to you. o §63.6655(a) - If you must comply with the emission and operating limitations, you must keep the records described in §63.6655(a)(1) through (a)(3), §63.6655 (b)(1) through (b)(3) and §63.6655 (c). o §63.6660(a) - Your records must be in a form suitable and readily available for expeditious review according to 563.10(b)(1). o §63.6660(b) - As specified in §63.10(b)(1), you must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. o §63.6660(c) - You must keep each record readily accessible in hard copy or electronic form on -site for at least 2 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to §63.10(b)(1). You can keep the records off -site for the remaining 3 years. o §63.6655(d) - You must keep the records required in Table 6 of Subpart ZZZZ of Part 63 to show continuous compliance with each emission or operating limitation that applies to you. • Other Requirements -and Information o §63.6665 - Table 8 to this subpart shows which parts of the General Provisions in §563.1 through 63.15 apply to you. OPERATING Et MAINTENANCE REQUIREMENTS 13. 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 COLORADO Mr Pollution Control Division Dep.:ctrrt'r ut 2 O.A s•,NA til ['Environment Page 5 of 16 l prior to implementation. (Regulation Number 3, COMP CE TE ING AND PL Initial Testing Requirements 14. A source initial compliance test shall be conducted on the emissions point in this permit to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emission limits in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. Periodic Testing Requirements 15. This engine is subject to the periodic testing requirements of 40 C.F.R Part 63, Subpart ZZZZ. ADDITIONAL REQUIREMENTS 16. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) in ozone nonattainment areas emitting less than 100 tons of VOC or 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. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. • 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, serial number, and horsepower of COLORADO Air Pollution Control Division rYXa�2 or Pubik:lieuik^. G L..;vor✓era Page 6 of 16 the appropriate APEN filing fee and a cover letter is exercising an alternative operating scenario and ngine. GENERAL TERMS AND CONDITIONS 17. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 18. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 19. 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. 20. 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. 21. 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. 22. 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. 23. 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: Betsy Gillard, PE Permit Engineer COLORADO Air Pollution Control Division PeatAc Hei1 E4 prrr nr;ti:r, Page 7 of 16 Issuance Date Description Issuance 1 This Issuance Issued to Bill Barrett Corporation. !COLORADO Air Pollution Control Division ` epsrtmrr;t W . r Health & Elr nvnr:rert Page 8 of 16 Notes Per �° H.. t the a�°.f th"."a mil is' ance: 1) Th red t••a es forth _ rocessing time for this permit. An invoice for these .�, ... fees will be issued a ter t e permit is issued. e permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 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 Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 004 Formaldehyde 50000 1619 389 Acetaldehyde 75070 319 319 Acrolein 107028 296 296 Methanol 67561 353 353 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 004: Pollutant CAS # Uncontrolled Emission Factors Controlled Emission Factors Units (lb/MMBtu or g/bhp-hr) Uncontrolled Source/Controlled Source N0x 13.30 0.60 g/bhp-hr Manufacturer CO 11.50 1.00 g/bhp-hr Manufacturer V0C 0.70 0.70 g/bhp-hr NSPS JJJJ Formaldehyde 50000 0.050 0.012 g/bhp-hr Manufacturer Acetaldehyde 75070 0.0028 N/A Lb/MMBtu AP -42 Acrolein 107028 0.0026 N/A Lb/MMBtu AP -42 Methanol 67561 0.0031 N/A Lb/MMBtu AP -42 Note: The controlled emissions factors for this point are based on a Brake -Specific Fuel Consumption Factor of 7,744 Btu/hp-hr and a fuel heat value of 962 Btu/scf. 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 COLORADO Air Pollution Control Division. ` ep£:r uvnt ut Pubtiv, 4,5ea,,th +'s ^virgr,m nt Page 9 of 16 th ost ` a ual fey ice tF='ermin `the APEN expiration date for each emissions point as .,°ciate� it _ this �..er F• .ny estions r arding a specific expiration date call the Division a 92- 7) 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.govittn/atw/area/fr181a08.pdf 8) 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/fr181a08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.Rovittn/atw/area/arearules.html 9) This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines (See August 20, 2010 Federal Register posting - effective October 19, 2010). The August 20, 2010 amendments to include requirements for existing engines located at area sources and existing 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/rice/fr20au10.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html 10) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 11) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, CO, n -Hex, total HAPs NANSR Synthetic Minor Source of: VOC, NOx PSD Synthetic Minor Source of: CO MACT ZZZZ Area Source Requirements: Applicable 12) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ 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 COLORADO ; Air Pollution Control Division Deparl:ment l {Ce,th.'C4 eriironmer t Page 10 of 16 ardous Air Pollutants for Source Categories 6 bpart=a:..,`ubpart 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 'COLORADO Air Pollution Control Division Page 11 of 16 OPE A TING SCENARIOS TER COMBUSTION ENGINES December 10, 2008 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 permittee shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. A.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 permittee 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 permittee shall maintain a copy of all Applicability Reports required under section A.1.2 and make them available to the Division upon request. A.1.1 The permittee 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 emissions from the temporary replacement engine comply with the emission limitations for the existing permitted engine as determined in section A.2. Measurement of emissions from the temporary replacement engine shall be made as set forth in section A.2. A.1.2 The permittee may permanently replace the existing compressor engine with an engine that is of the same manufacturer, model and horsepower without modifying this permit so long as the emissions from the permanent replacement engine comply with 1) the permitted annual emission limitations for the existing engine, 2) any permitted short-term emission limitations for the existing permitted engine, and 3) the applicable emission limitations as set forth in the Applicability Report submitted to the Division with the Air Pollutant Emissios Notice (APEN) for the replacement engine (see 'COLORADO Air Pollution Control Division 1 txgxot,rxht it P Ltk!t Page 12 of 16 ittin tml for example applicability report formats). nent replement engine and compliance with the applicable th in w m, _ n 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 permittee 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 https://www.colorado.gov/pacific/cdphe/alternate- operating-scenario-aos-reporting-forms. This submittal shall be accompanied by a certification from a person legally authorized to act on behalf of the source 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 permittee 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. A.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 permittee 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 permittee shall measure nitrogen oxide (NOX) 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 website at: http://www.cdphe.state.co.us/ap/down/portanalyzeproto.pdf 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. For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the ICOi ORADO I Mr Pollution Control Division DGYi" k. 1t iii PUE2'� SzC{i₹^ 3.1�$'aiirlTuelef' Page 13 of 16 replac units a the test shall be converted to the appropriate nalyzer 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. A.3 Applicable Regulations for Permanent Engine Replacements A.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B S 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 5O2 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 5O2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (5 60.331) and 40 CFR Part 72 (5 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. A.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. COLORADO Air Pollution Control Division L i Heti n & environment Page 14 of 16 priately sized for the engine and shall be operated ons. The source shall submit copies of the relevant Applicability Reports required under Condition A.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 aver the entire life of the engine so that it achieves the emission standards required in the table below: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NOx CO VOC 100<Hp<500 January 1, 2008 2.0 4.0 1.0 January 1, 2011 1.0 2.0 0.7 500<Hp July1, 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 A.1.2 A.3.3 NSPS for spark ignition internal combustion engines: 40 CFR 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 burn 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 40 CFR 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 A.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 A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.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 November 1, 2008 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, § 1.8 (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. A.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A.3.4.1 Area Source for HAPs A permanent replacement engine located at an area source that commenced construction or reconstruction after June 12, 2006 as defined in S 63.2, will meet the requirements of 40 CFR Part 63, !COLORADO Air Pollution Control Division Page 15 of 16 Subpa 40 C Part 60, Subpart JJJJ. An analysis of the applic to g, ` core ` eep a reportin - requirements for the permanent engine replashah n in t - .bility rts required under Condition A.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 A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. A.4.3.2 Major source for HAPs A permanent replacement engine that is located at major source is subject to the requirements in 40 CFR Part 63 Subpart ZZZZ as follows: Existing, new or reconstructed spark ignition 4 stroke rich burn engines with a site rating of more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 12/19/02) 2 stroke and 4 stroke lean burn engines with a site rating of more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 4 stroke lean burn engines with a site rating of greater than or equal to 250 but less or equal to 500 hp and were manufactured on or after 1/1/08 are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 2 stroke lean burn or 4 stroke rich burn engines with a site rating of 500 hp or less will meet the requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 4 stroke lean burn engines with a site rating of less than 250 hp will meet the requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition A.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 A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. A.3.5 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. COLORADO Air Pollution Control Division lb I.'fuukn ur Page 16 of 16 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Package II: Received Date: Review Start Date: Betsy.Glilard 372279.: 12/8/2017 3/19/2018 Section 01- Facility Information Company Name: Bit Barrett Corporation County AIRS ID: 123 Plant AIRS ID: '`7168 Facility Name: Peterson 5-63-30 SWNE. Physical Address/Locatio SWNE quadrant of Section 30, Township 5N, Range 63W, in Weld County, Colorado Type of Facility: Exploration & Production Well Pad What industry segment? oil & Natural Gas Production & Processing Is this facility located in a NAAQS non attainment area? Yes If yes, for what pollutant? on Monoxide (CO) Riculate Matter (PM) Erie (NOx & VOC) Weld Quadrant Section Township Range SWNE 30 5 63 Section 02 - Emissions Units In Permit Application AIRS Point SS Emissions Source Type Equipment Name Emissions Control? Permit SS Issuance SS Self Cert Required? Action Engineering Remarks 001 Condensate Tank GW Tank Battery Yes 17WE1266.XP 1 No APEN Required! Permit Exempt Previously GP01 004 Natural Gas RICE .. C-17696/1 Yes 17WE1267 1 Yes Permit Initial Issuance 005 Natural Gas RICE GP02 Cancellation No longer exists 006 Condensate Tank Condensate Tank Battery - Yes 17WE1268 1 Yes Permit Initial Issuance 007 Produced Water Tank Produced Water _ Tanks yes 17WE1269 1 - Yes Permit Initial Issuance 008 Separator Venting Steffes Flare Yes 17WE1270 1 Yes Permit Initial Issuance O09 Natural Gas RICE C-13160/1 Yes 17WE1271 1 Yes Permit Initial Issuance 010 - Hydrocarbon Liquid Loading Hydrocarbon Loadout Yes 18WE0322 1 Yes Permit Initial Issuance Section 03 - Description of Project Synthetic minor facility with two proces with "GW'). eam, called "OW `, includes Loadout, water tanks, and condensate to nks (all names are prefaced Point 001 was initially permitted under a'GP01. On 12/8/2017, BBC requested an individual permit for the point On 3/23/2018, BBC sent a new APEN requesting en XP letter for the point, as decreased throughput make emissions fall below permit thresholds. Operator submitted APEN for Hydrocarbon Loadout, was mistakenly assigned in PTS as Point 002 (which is GW Tank Truck Loadout, and is permit -exempt). Corrected in PTS: New Loadout is now Point 010. No changes were made to Point 002: Section 04 - Public Comment Requirements Is Public Comment Required? Yes If yes, why? Greater than 25 tons p/ryear in Non -Attainment Area Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? `No If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: - Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) Is this stationary source a major source? No Yes SO2 NOx CO VOC PM2.5 PM10 TSP HAPs J J ❑ ❑ Condensate Storage Tank(s) Emissions Inventory Section 01- Administrative Information 'Facility Allis ID: X23': County 7 Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Foot (4);400•bblfbcedwoof condensateutol Description: _. _..... Emission Control Device Enclosed Flare Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions- Storage Tank(s) Actual Condensate Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Condensate Throughput 700,000.'. Barrels (bbl) per year 840,000! Barrels (bbl) per year 000 Barrels (bbl) per year Secondary Emissions - Combustion Device(s) Heat content of waste gas= _......,,;;�„�7.w?$�4'. Btu/scf Volume of waste gas emitted per BBL of liquid produced = T.76 scf/bbl Actual heat content of waste gas routed to h ston device Requested heat content of waste gas routed to combustion device = Actual Condensate Throughput While Emissions Controls Operating = 700 OB0• Barrels (bbl) per year 17,323 MM BTU per year 20,329 MM BTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 20,329 MM BTU per year Section 04 - Emissions Factors & Methodologies Mill this storage tank emit flash emissions? Pollutant MEIMIMM EMEI 7.34E-04®' Uncontrolled Controlled (Ib/bbl) (Ib/bbl) (Condensate Throughput) 4.86E -0S (Condensate Throughput) 0.04 2.43E-06 7.95E-04 Pollutant Control Device Uncontrolled Uncontrolled (lb/MMBtu) (waste heat combusted) (Ib/bbl) 0.0500 0.3100 (Condensate Throughput) 0.0000 0.0000 0.0013 0.0060 0 Emission Factor Source Emission Factor Source Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC PM10 PM2.5 NOx CO 377.6 314.7 15.7 377.6 18.9 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.7 0.6 0.6 0.7 0.7 3.2 2.7 2.7 3.2 3.2 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 1295 1082 54 1298 65 911 760 38 912 46 41 38 2 45 2 273 228 11 273 14 13356 11132 557 13359 668 617 512 26 615 31 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Section XII.C, D, E, F Regulation 7, Section XII.G, C Regulation 7, Section XVII.B, C.1, C.3 Regulation 7, Section XVII.C.2 Regulation 6, Part A, NSPS Subpart Kb Regulation 6, Part A, NSPS Subpart 0000 Regulation 8, Part E, MACT Subpart HH (See regulatory applicability worksheet for detailed analysis) Source requires APEN, is permit exempt Storage tank is subject to Regulation 7, Section XII.C-F Storage Tank is not subject to Regulation 7, Section XII.G Storage tank is subject to Regulation 7, Section XVII, 6, C.1 & C.3 Storage tank is subject to Regulation 7, Section XVII.C.2 Storage Tank is not subject to NSPS Kb Storage Tank is not subject to NSPS 0000 Storage Tank is not subject to MACF HH 2 of 5 K:\PA\2017\ 17WE1268.CP1.xlsm Condensate Storage Tank(s) Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons V0C per year? If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted? This sample should be considered representative which generally means she -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no Ifw wells brought on-line), then it maybe appropriate to use an older site -specific sample. no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company request a control device efficiency greater than 95% for a flare or combustion device?!`p_ If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes W&B emissors calculated from EPA Tanks 4.0.9d simulation, based on gasoline (RVP 6.3).The'sales oil sample. shows an RVP.'of7.7sothis is conservativeFIx. sh emiss ors a oeratien an oe a Pressurized liquid sample collected 10/16/2017 The molecular weight of the -lashed gas was 47.55615 and the V0C content by weigh[ was 83.646°'". Alt collected samples were mte speelfle and collected wiThin less than a year of permit application submittal. As a result, there arena Mahal testing requ reme� HAPs requested permit lints were adjusted based on operator cal Pons. The numbers are very similar to my alculotinno(PT E in the Section 5 table] Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # Process # SCC Code 006 01 Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons condensate throughput PM2.5 0.00 0 lb/1,000 gallons condensate throughput N0x 0.04 0 lb/1,000 gallons condensate throughput V0C 21.4 95 lb/1,000 gallons condensate throughput CO 0.18 0 lb/1,000 gallons condensate throughput Benzene 0.04 95 lb/1,000 gallons condensate throughput Toluene 0.03 95 lb/1,000 gallons condensate throughput Ethylbenzene 0.00 95 lb/1,000 gallons condensate throughput Xylene 0.01 95 lb/1,000 gallons condensate throughput n -Hexane 0.38 95 lb/1,000 gallons condensate throughput 224 TMP 0.02 95 lb/1,000 gallons condensate throughput 3 of 5 K:\PA\2017\17 W E1268.CP1.xlsm Flash Liberation Analysis Throughput 840000Ibbl/yr 7.76Iscf/bbl Throughput (Q) 6.52 MMscf/yr 744.1 scf/hr MW 47.682 Ib/Ib-mol 0.018 MMscf/d 0.55 MMscf/mo mole % MW lbx/lbmol mass fraction E lb/hr lb/yr tpy Helium 2.4611 32 0.788 0.017 Helium 1.5 13544 6.77 CO2 0.3725 44.01 0.164 0.003 C02 0.3 2819 1.41 N2 11.1351 28.013 3.119 0.065 N2 6.1 53649 26.82 methane 0.6777 16.041 0.109 0.002 methane 0.2 1870 0.93 ethane 12.0339 30.063 3.618 0.076 ethane 7.1 62234 31.12 propane 35.212 44.092 15.5257 0.326 propane 30.5 267047 133.52 isobutane 6.9105 58.118 4.0162 0.084 isobutane 7.9 69082 34.54 n -butane 19.4331 58.118 11.2941 0.237 n -butane 22.2 194266 97.13 isopentane 3.8951 72.114 2.8089 0.059 isopentane 5.5 48334 24.17 n -pentane 4.5243 72.114 3.2627 0.068 n -pentane 6.4 56142 28.07 cyclopentane 0.2245 70.13 0.1574 0.003 cyclopentane 0.3 2708 1.35 n -Hexane 0.8186 86.18 0.7055 0.015 n -Hexane 1.4 12133 6.07 cyclohexane 0.1708 84.16 0.1437 0.003 cyclohexane 0.3 2472 1.24 Other hexanes 1.337 86.18 1.1522 0.024 Other hexanes 2.3 19815 9.91 heptanes 0.3361 100.21 0.3368 0.007 heptanes 0.7 5793 2.90 methylcyclohexane 0.1079 98.19 0.1059 0.002 methylcyclohexane 0.2 1823 0.91 224-TMP 0.0284 114.23 0.0324 0.001 224-TMP 0.1 558 0.28 Benzene 0.0878 78.12 0.0686 0.001 Benzene 0.1 1179 0.59 Toluene 0.0523 92.15 0.0482 0.001 Toluene 0.1 828 0.41 Ethylbenzene 0.0022 106.17 0.0023 0.000 Ethylbenzene 0.0 41 0.02 Xylenes 0.0136 106.17 0.0144 0.000 Xylenes 0.0 248 0.12 C8+ Heavies 0.1655 126.298 0.2090 0.00425 C8+ Heavies 0.4 3484 1.74 100 VOC mass fraction: 47.682 0.8365 Total VOC Emissions (Uncontrolled) EPA TANKS 5880000 gallons/yr 140000 bbl/yr VOC 11716.01 lb/yr 0.083685786 lb/bbl Benzene 20.140 lb/yr 0.000143856 lb/bbl Toluene 14.141 lb/yr 0.000101009 lb/bbl E 0.698 lb/yr 4.98767E-06 lb/bbl Xylenes 4.239 lb/yr 3.02775E-05 lb/bbl n -Hexane 207.256 lb/yr 0.001480402 lb/bbl 2,2,4-TMP 9.536 lb/yr 6.81119E-05 lb/bbl 0.001719 0.001207 0.00 0.0004 0.0177 0.0008 840000 bbl/yr 343.0 TOTALS Uncontrolled Flash WEB Total Uncontrolled Emissions Controlled Emissions VOC 0.8166 0.0837 0.9003 Ib/bbl 378.13 18.91 tpy Benzene 0.0014 0.0001 0.0015 lb/bbl 1300 65 lb/yr Toluene 0.0010 0.0001 0.0011 lb/bbl 913 46 lb/yr Ethylbenzene 0.0000 0.0000 0.0001 lb/bbl 45 2 lb/yr Xylenes 0.0003 0.0000 0.0003 lb/bbl 274 14 lb/yr n -Hexane 0.0144 0.0015 0.0159 lb/bbl 13376 669 lb/yr 224-TMP 0.0007 0.0001 0.0007 lb/bbl 616 31 lb/yr 17WE1268.CP1.xlsm Condensate Tank Regulatory Analysis Worksheet col oradoR Iatlon3 PartsBand B-APEN and Perm It Requirements rourca l:; In the 4on-A4L3inment Strut ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this Individual source greater than 2 TPY (Regulation 3, Part A, Section I I.D.1.a)? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05.01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NON greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.1.3)? 'You have indicated that sauna, s in the Non.Attrrnment unto NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than 1 TPY (Regulation 3, Party, Section Ital.e)? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 0501 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions from the greaten that? TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section 11.0.2)? 'Source requires APBN, is permit exempt Colorado Reguladon 7, Section %II.C-F 1. Is this storage tank located In the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at an oil and gas exploration and production operation', natural gas compressor station or natural gas drip station? 3. Is this storage tank located upstream of a natural gas processing plant? 'Storage tank Is subject to Regulation 7. Section %II.C-F Section %II.C.1 -General Requirements for Air Pollution Control Equipment- Prevention of Leakage Section %II.C.2-Emission Estimation Procedures Section 011.0- Emissions Control Requirements Section %II.E-Monitoring Section %II.F- Recordkeeping and Reporting Colorado Regulation 7. Section 011.0 1. Is thls storage tank located In the 5 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at a natural gas processing plant? 3. Does this storage tank exhibit "Flash" (e.g. storing non-stabRized liquids) emissions and have uncontrolled actual emissions greater than or equal to 2 tons per year VOC? 'Storage Tank is not subject to Regulation 7, SecLun 211.3 Section 011.0.2 - Emissions Control Requirements Section %II.C.1 -General Requirements for Air Pollution Control Equipment -Prevention of Leakage Section %II.C.2-Emission Estimation Procedures Colorado Regulation 7. Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this condensate storage tank' located at an oil and gas exploration and production operation , well production facility', natural gas compressor stations or natural gas processing plant? 3. Is this condensate storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions° of this storage tank equal to or greater than 6 tons per year VOC? Storage tank Is suh(ect to aeyulatlor 7, SemRon fVil, 0, C.1 G (.0 Section %VII.B-General Provisions for Air Poll Won Control Equipment and Prevention of Emissions Section %VII.C.1- Emissions Control and Monitoring Provisions Section %VII.C.3 - Recordkeeping Requirements 5. Does the condensate storage tank contain only "stabilized" liquids? (Storage tank is suh(eet t.^ Regulation 7, Section )(V:I.C..2 Section %VII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart Kb. Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the Individual storage vessel capacity greater than or equal to ?5 cubic meters (m) (-4?2 BBB'? 'Storage tank is not subject to NSPS Kb 40 CFR. Part fill. Subpart 0000. Standards of Performance for Crude Oil and Natural Gas Production. Transmission and Distdbudon 1. Is this condensate storage vessel located at a facility In the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industn/? 2. Was this c depsgte storage Yeisel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? [Storage Tank is not subject to NSPS 0000 40 CFR, Part 63, Subpart MAR NH. Oil and Gas Production Facilities 1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)), OR b. A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or Is delivered toe final end user' (63.360(a)(3))? 2. Is the tank boated eta facility that Is major' for HAPs? 'Storage Tank 1, not subject £a MACY Hli RACT Review RACT review is required if Regulation 7 does not apply AND K the tank is le the non -attainment area. If the tank meets both criteria, then review PACT requirements. No the Source Req Source Is Al Source Req Continue -` Continue Source isst Continue Storage Tar Source Is sc ontinue Go to then Go to then Source Isst Continue Storage Tar boo 'Continue Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulaflon, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this -document and the language of the Clean Air Act„ its implementing regulations, and Air Qualify Control - Commission regulations, the language of rho statute or regulation will control The use of non -mandatory language such as"recommend,""may,"`should," and 'can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such es "must" and °required"are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself Permit number: Date issued: Issued to: Division Department of Public Health & Environment CONSTRUCTION PERMIT 17WE1268 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Bill Barrett Corporation Peterson 5-63-30 SWNE 123/7168 SWNE SEC 30 T5N R63W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description COND 006 Six (6) 400 -barrel fixed roof storage vessels used to store condensate Enclosed Flare 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 the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) COLORADO Air Pollution Control Division Page 1 of 7 3. w' r s ll a F=•ire° th- er or'xperator of the source for which this permit was issued: es c•' ce tion/ `==fication or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section I I .A.4. ) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO, VOC CO COND 006 -- -- 18.9 3.2 Point Note: 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 not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits for both criteria and hazardous air pollutants shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled COND 006 Enclosed Flare VOC and HAP COLORADO Air Control Division Dop:;n me ;t of Pubic 4;e£`tn 6 E>riiror rtsf;t Page 2of7 PROC A "O. AN ! RD 8. is source sha a imi a of The following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS . Point Process Parameter Annual Limit COND 006 Condensate throughput 840,000 barrels 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 9. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 10. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 11. This source is subject to Regulation Number 7, Section XII. The operator shall comply with all applicable requirements of Section XII and, specifically, shall: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for condensate storage tanks; and • Ensure that the combustion device controlling emissions from this storage tank be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. (Regulation Number 7, Section XII.C.) (State only enforceable) 12. The combustion device covered by this permit is subject to Regulation Number 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, as defined under Regulation Number 7, XVII.A.16; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. This flare must be equipped with an operational auto -igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 13. The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall 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 except where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section COLORADO } Mr Pollution Control Division »..e; rt e t PuNie 4e...c c??h EmpirsovAent Page 3 of 7 spections for a period of two years, made available to uuirement must be met within 90 days of the date that the storage tank commences operation. 14. The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Section XVII.C.2. OPERATING a MAINTENANCE REQUIREMENTS 15. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEM) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 16. The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen -minute period during normal operation. (Regulation Number 7, Sections XII.C, XVII.B.2. and XVII.A.16) Periodic Testing Requirements 17. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 18. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NOX per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. COLORADO Air Pollution Control Division ate€iC I (e21°, 'n Ekveenrnent Page 4 of 7 GENE'- S .: N G,: , ON 19. is permi an any a ac ments mus .e retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 20. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 21. 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. 22. 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. 23. 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. 24. 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. 25. 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: Betsy Gillard, PE Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bill Barrett Corporation. COLORADO I Air Pollution Control Division vimnt ot. PulAc 11eeEthv Er-rnor:mer:t Page 5 of 7 Notesissuance: 1) e permit o •er is require.o pay fees or e processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 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 Point Pollutant CAS # Uncontrolled Emissions ' (Ib/yr) Controlled Emissions (lb/yr) 006 Benzene 71432 1298 65 Toluene 108883 912 46 Ethylbenzene 100414 45 2 Xylenes 1330207 273 14 n -Hexane 110543 13,359 668 2,2,4- Trimethylpentane 540841 615 31 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 006: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source CO 0.0060 0.0060 AP -42 VOC 0.8991 0.0450 Flash Liberation Analysis and EPA Tanks 4.0.9d based on site - specific sample 71432 Benzene 1.54E-03 7.71 E-05 108883 Toluene 1.08E-03 5.42E-05 1330207 Xylene 3.25E-04 1.63E-05 110543 n -Hexane 1.59E-02 7.95E-04 540841 2'2'4 Trimethylpentane 7.34E-04 167E-05 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. COLORADO Air Pollution Control Division ?XP`'r?me: d He.fu`^\ i1 E'wir:rirgenl Page 6 of 7 6) In cor• cs C R:: �,7 11.1 each -Air Pollutant Emission Notice (APEN) associated with it teryear . 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 permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, CO, n -Hex, total HAPs NANSR Synthetic Minor Source of: VOC, NOx PSD Synthetic Minor Source of: CO 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ 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 )00000( COLORADO Air Pollution Control Division Page 7 of 7 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Package #: Received Date: Review Start Date: Section 01- Facility Information Company Name: ii31j@arrett Corporation County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Locatio SWNE quadrant of Section 30, Township 5N, Range 63W, in Weld County, Colorado Type of Facility: . tion & Production V,reil.P;ark What industry segment? foraEGas Production Is this facility located in a NAAQS non -attainment area? If yes, for what pollutant? Bon Monoxide (CO) son 5-63-30 SWNE Weld Section 02 - Emissions Units In Permit Application Quadrant Section Township Range p 53 Riculate Matter (PM) Elne (NOx & VOC) AIRs Point # Emissions Source Type 004 Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks W Tank Battery Yes 17WE1266.XP end:: Previously GP01 C-17696/1 Yes 17WE1267 RICE G PO2 Permit initial,. ncellation, `- No longer exists Condensate Tadk%>: Condensate Tank Battery Produced Water Tanks 17WE1268 I 007 Prarlluceii.WaterTank -• - 17WE1269 008 Separator Venting Steffes Flare 17 W E1270 do C-13160/1 7WE1271 -PerrnifInitlaf.. Issuance 010 V Ieacax6an,G quidLoading,:.'Hydrocarbon Loadout Yes 18WE0322 Section 03 - Description of Project Synthetic minor facility with two process a reams. The original process stream, called."GW?`, includes loadout; water tans, and con kdensat with "GN! j `; Point,001 was initially permitted: under aOP01-,On 12/8/2017, BBC requested an individual permit for the point. On 3/23/2018, letter for the point' as decreased: throughput r"nake emissions fail below permit thresholds_ • nks (all met are i BCsent a new APEN requesting an XP ;Operator submitted APEN"for;hydrocarbon Loadout, was mistakenly assigned in PTS as Point 002 (which is GW Tank Truck €oadout, and is permit -exempt): Corrected in PTS New Loadout is now Point 010. Na changes were made to Point 002. : Section 04 - Public Comment Requirements Is Public Comment Required? If yes, why? 1greatef'thwit,5t>�rs.6perYear Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) Is this stationary source a major source? SO2 NOx CO VOC PM2.5 PM10 TSP HAPs ❑ 0 I .l J ,./ J Produced Water Storage Tank(s) Emissions Inventory Section 01 - Administrative Information Facility AIRS ID: I .13.1 :.1,33. County 7180 .:. Plant Paint Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Produced Water Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Produced Water Throughput = "Barrels (bbl) per year 01 Barrels (bbl) per year 1,000:_ Barrels (bbl) per year Secondary Emissions - Combustion Device(s) Heat content of waste gas= . 2510' Btu/scf Actual heat content of waste gas routed to combustion device Requested heat content of waste gas routed to combustion device = Potential to Emit (PTE) heat content of waste gas routed to combustion device= Section 04 - Emissions Factors & Methodologies Actual Produced Water Throughput While Emissions Controls Operating= 2,524 MMBTU per year 2,962 MMBTU per year 2,962 MMBTU per year Emission Factors Produced Water Tank Pollutant Uncontrolled Controlled (03/bbl) (Ib/bbl) (Produced Water Throughput) (Produced Water Throughput) Emission Factor Source VOC 0.01 0.000 0.001 Control Device Benzene n -Hexane Pollutant Uncontrolled Uncontrolled (Ib/MMBtu) (Ib/bbl) (waste heat combusted) (Produced Water Throughput) PM10 PM2.5 0.0000 0.0000 0.0000 0.0000 NOx CO 680 It, Emission Factor Source Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC PM10 PM2.5 NOx CO 55.0 45.9 2.3 55.0 2.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 0.1 0.1 0.1 0.1 0.5 0,4 0.4 0.5 0.5 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene n -Hexane 2940 2450 123 2940 147 9240 7700 385 9240 I 462 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XVII.B, C.1, C.3 Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3 Regulation 7, Section XVII.C.2 Storage tank is subject to Regulation 7, Section XVIl.C.2 Regulation 6, Part A, NSPS Subpart 0000 Storage Tank is not subject to NSPS 0000 (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use a site specific emissions factor to estimate emissions? Does the company request a control device efficiency greater than 95% for a flare or combustion device? Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # Process # SCC Code 007 01 4-04-003-15 Fixed Roof Tank, Produced Water, working+breathing+flashing losses Uncontrolled Pollutant Emissions Factor Control % Units PM10 0.00 0 lb/1,000 gallons liquid throughput P442.5 0.00 0 lb/1,000 gallons liquid throughput 900 0.01 0 lb/1,000 gallons liquid throughput VOC 6.2 95 lb/1,000 gallons liquid throughput CO 0.05 0 lb/1,000 gallons liquid throughput Benzene 0.17 95 lb/1,000 gallons liquid throughput n -Hexane 0.52 95 lb/1,000 gallons liquid throughput 2 of 3 K:\PA\2017\17 W E1269. CP1.xlsm Produced Water Storage Tank Regulatory Analysis Worksheet Please note that NSPS Kb might be might be applicable for certain tanks at water management and Injection facilities. If the tanks you are reviewing are at one of these facilities, please review NSPS Kb. Colorado Regulation 3 Parts A and B - APEN and Permit Requirements .Source to in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TRY (Regulation 3, Part B, Section I I.5.3)? 'You have indicated that source is in the Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section 11.5.1.a)? 2. Is the operator claiming less than 1% crude oil and Is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section il.D.2)? 'Source requires a permit Colorado Regulation 7, Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this produced water storage tank' located at an oil and gas exploration and production operation , well production facility', natural gas compressor station' or natural gas processing plant? 3. Is this produced water storage tank a fixedroof storage tank? 4. Are uncontrolled actual emissions' of this storage tank equal to or greater than 6 tons per year VOC? yes....,'!. tie Yes 'Storage tank is subject to Regulation 7, Section XVIi, b, C1 & C.3 Section XVII.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1 - Emissions Control and Monitoring Provisions Section XVII.C.3 - Recordkeeping Requirements 5. Does the produced water storage tank contain only "stabilized" liquids? If no, the following additional provisions apply. 'Storage tank is subject to Regulation 7, Section XVlt.C.2 Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60. Subpart 0000, Standards of Performance for Crude Oil and Natural Gas Production. Transmission and Distribution 1. Is this produced water storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this produced water storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? 4. Does this produced water storage vessel meet the definition of "storage vessel" per 60.5430? 'Storage Tank is not subject to NSPS 0090 Subpart A, General Provisions per §60.5425 Table 3 460.5395 - Emissions Control Standards for VOC 460.5413 - Testing and. Procedures 460.5395(g) - Notification, Reporting and Recordkeeping Requirements §60.5416(c) - Cover and Closed Vent System Monitoring Requirements 460.5417 - Control Device Monitoring Requirements [Note: If a storage vessel is previously determined to be subject to NSPS 0000 due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS 0000 per 60.5365(e)(2) even if potential VOC emissions drop below 6 tons per year] RAC' Review RACr review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is note rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend,""may," "should," and "can,"is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. Yes AWE Source Req Go to next Source Req Continue -' Continue -' Go to the n Source is st Source is st Continue -' Storage Tar Permit number: Date issued: Issued to: Division Department of Public Health & Environment CONSTRUCTION PERMIT 12WE69 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Bill Barrett Corporation Peterson 5-63-30 SWNE 123/7168 SWNE SEC 30 T5N R63W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description PW 007 Two (2) 400 -barrel fixed roof storage vessels used to store produced water Enclosed Flare 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 the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) COLORADO Air Pollution Control Division 'merit of Pubt c t.fea:th v aw rorple nt Page 1 of 7 3. °' r s ° ll a ire th- er or , perator of the source for which this permit was issued: tion/ fication or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) ) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO. VOC CO PW 007 -- -- 2.8 -- Point Note: 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 not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits for both criteria and hazardous air pollutants shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled PW 007 Enclosed Flare VOC and HAP !COLORADO Air Pollution Control Division Page 2 of 7 8. is source shao�fhe following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit PW 007 Produced water throughput 420,000 barrels 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 9. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 10. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 11. The combustion device covered by this permit is subject to Regulation Number 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, as defined under Regulation Number 7, XVII.A.16; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. This flare must be equipped with an operational auto -igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 12. The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall 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 except where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 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 requirement must be met within 90 days of the date that the storage tank commences operation. 13. The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Section XVII.C.2. OPERATING Et MAINTENANCE REQUIREMENTS 14. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEM) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to COLORADO Air Pollution control Division F?spr,�t4;t'x :t ktS€w 3 per€th E Enviralrne4 Page 3 of 7 royal prior to implementation. (Regulation Number 3, COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 15. The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen -minute period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.16) Periodic Testing Requirements 16. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 17. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) 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. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. GENERAL TERMS AND CONDITIONS 18. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 19. 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 - COLORADO Air Pollution Control Division rr=n= Page 4 of 7 ulati= ` Number 3, Part B, Section III.G. Final authorization of a :_• til ation tivity 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. 20. 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. 21. 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. 22. 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. 23. 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 wilt terminate. 24. 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: Betsy Gillard, PE Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bill Barrett Corporation. COLORADO Air Pollution Control Division or. Put E Het v Ermrc.nrrvnt Page 5 of 7 Notes per issuance: 1) e permit otter is require : o pay fees or e processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 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 Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 006 Benzene 71432 2940 147 n -Hexane 110543 9240 462 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 006: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 0.262 1.31E-02 CDPHE Emission Factor 71432 Benzene 0.007 3.50E-04 110543 n -Hexane 0.022 1.10E-03 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. COLORADO Air'rPollutio tControlDivision t'„),;:fxrtoa,nt Ur Fri HOA:th n 6>rrt'Jrertont Page 6 of 7 Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, CO, n -Hex, total HAPs NANSR Synthetic Minor Source of: VOC, NOx PSD Synthetic Minor Source of: CO 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ 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 COLORADO Air Pollution Control Division RAt, t to i .! u E:avunnmril Page 7 of 7 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Betsy Gillard Package 6: 372274. Received Date: 12/8/2017 Review Start Date: 3/19/2018 Section 01- Facility Information Company Name: Bill Barrett Corpora County AIRS ID: 123 Plant AIRS ID: 7168 Facility Name: Peterson 5-63-30 SWNE.. Physical Address/Locatio SWNE quadrant of Section 30, Township 5N, Range 63W, in Weld County, Colorado Type of Facility: Exploration & Production Well Pad What industry segment? Oil & Natural Gas Production & Processing Is this facility located in a NAAQS non attainment area? Yes _ If yes, for what pollutant? on Monoxide (CO) Eliculate Matter (PM) ie (NOx & VOC) Weld Quadrant Section Township Range SWNE 30 SN '. 63 Section 02 - Emissions Units In Permit Application AIRs Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks 001 Condensate Tank GW Tank Battery Yes 17WE1266.XP 1 No APEN Required / Permit Exempt Previously GP01 004 Natural Gas RICE C-17696/1 Yes 17WE1267 1 Yes Permit Initial Issuance 005 Natural Gas RICE GP02 Cancellation No longer exists 006 Condensate Tank Condensate Tank Battery Yes 17WE1268 1 Yes Permit Initial Issuance 007 Produced Water Tank Produced Water Tanks yes 17WE1269 1 Yes Permit Initial Issuance 008 Separator Venting Steffes Flare Yes 17WE1270 1 Yes Permit Initial Issuance 009 Natural Gas RICE C-13160/1 Yes 17WE1271 1 Yes Permit Initial Issuance 010 Hydrocarbon Liquid Loading Hydrocarbon Loadout Yes -:18WE0322 1 Yes Permit initial Issuance Section 03 - Description of Project Synthetic minor facility with two process streams_ The original process stream, called "GW", includes loadout, water tanks, and condensate to nks {ail names are prefaced with "GW"). Point 001 was initially permitted under a GPD1- On 12/8/2017, BBC requested an individual permit for the point On 3/23/2018, BBC sent a new APEN requesting an XP letter for the point, as decreased throughput make emissions fall below permit thresholds. Operator submitted APEN for Hydrocarbon Loadout, was mistakenly assigned in PTS as Point 002 (which is GW Tank Truck Loadout, and is permit -exempt). Corrected in PTS: New Loadout is now Point 010. No changes were made to Point 002. Section 04 - Public Comment Requirements Is Public Comment Required? Yes If yes, why? Greater than 25 tons per year in Non -Attainment Area Section OS - Ambient Air Impact Analysis Requirement: Was a quantitative modeling analysis required? No If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) Is this stationary source a major source? No Yes. SO2 NOx CO VOC PM2.5 PM10 TSP HAPs ❑ L1 Separator Venting Emissions Inventory Section 01- Administrative Information 'Facility AIRs ID: Coun Plant Poin Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control E Limited Process Parameter Gas meter Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Separator Actual Throughput ='. Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = 4. MMscf per year r MMscf per year 74 MMscf per year Secondary Emissions - Combustion Device(s) for Air Pollution Control Separator Gas Heating Value: Section 04 - Emissions Factors & Methodologies Description Displacement Equation Ex=Q*MW*Xx/C 73 Btu/scf Weight Helium CO2 N2 methane ethane propane isohutane n -butane isopentane n -pentane cyclopentane n -Hexane cyclohexane Other hexanes heptanes methylcyclohexane 224-TMP Benzene Toluene Ethylbenzene Xylenes i O.G5! C8+ Heavies 0.47! Total loo. 40 VOC Wt% 32.21 0':34 '... ".....4:46 Ib/Ib-mol 2 of 4 K:\PA\2017\ 17WE1270.CP1xlsm Separator Venting Emissions Inventory Emission Factors Separator Venting Pollutant Uncontrolled Controlled (lb/MMscf) (lb/MMscf) (Gas Throughput) (Gas Throughput) VOC 20741.7978 1037.0899 Benzene Toluene 49.9703 63.5576 5.1516 34.7088 411.0959 27.3678 2.4985 3.1779 0.2576 1.7354 20.5548 1.3684 Ethylbenzene Xylene n -Hexane 224 TMP Emission Factor Source Emission Factor Source Operator Calculations Uncontrolled (lb/MMscf) Controlled (lb/MMscf) (Gas Throughput) (Gas Throughput) 20719.0000 49.9380 65.8940 5.1352 34.6940 410.6620 27.3280 1035.9500 2.4969 3.2947 0.2568 1.7347 20.5331 1.3664 Pollutant Primary Control Device Uncontrolled Uncontrolled (Ib/MMBtu) lb/MMscf (Waste Heat Combusted) (Gas Throughput) PM10 PM2.5 9.485 9.485 0.000 86.564 394.630 500 NOx CO Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 SOx NOx VOC CO 0.35 0.35 0.35 0.35 0.35 0.35 0.35 0.35 0.35 0.35 0.00 0.00 0.00 0.00 0.00. 3.20 3.20 3.20 3.20 3.20 767.45 767.45 38.37 766.56 38.33 14.60 14.60 14.60 14.60 14.60 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) llbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 3698 3696 185 3696 185 4703 4694 235 4696 235 381 380 19 380 19 2568 2567 128 2567 128 30421 30389 1519 30389 1519 2025 2022 101 2022 101 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Section XVII.B, G Regulation 7, Section J(VII.B.2.e (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Using Gas Throughput to Monitor Compliance Does the company use site specific emission factors based on a gas sample to estimate emissions? This sample should represent the gas outlet of the equipment covered under this AIRS ID, and should have been collected within one year of the application received date. However, if Are facility -wide permitted emissions of VOC greater than or equal to 90 tons per year? Will the operator have a meter installed and operational upon startup of this point? yes Does the company request a control device efficiency greater than 95% for a flare or combustion device? Source requires a permit Source is subject to Regulation 7, Section XVII.B.2, G The control device for this separator is subject to Regulation 7, Section XVII.8.2.e Section 08 Technical Analysis Notes Section 09- Inventory SCC Coding and Emissions Factors AIRS Point 8. ffd-•II be errors. Perr Process 9 SCC Code 008 01 3.10-001-60 Flares egi'dr¢dbeca se tfnsasa major facify itw)ll'ref(ectooerotar at ht Pollutant PM10 PM2.5 SOX NOx VOC CO Benzene Toluene `Ethylbenzene Xylene n -Hexane 224 TMP Uncontrolled Emissions Factor 9.49 9.49 0.00 86.56 20741.80 394.63 49.97 63.56 5.15 34.71 411.10 27.37 Control % Units 0 lb/MMSCF 0 Ib/MMSCF 0 0 95 0 95 95 •95 95 95 95 lb/MMSCF lb/MMSCF lb/MMSCF Ib/MMSCF Ib/MMSCF Ib/MMSCF lb/MMSCF Ib/MMSCF lb/MMSCF lb/MMSCF 3 of 4 Kr\PA\2017\ 17WE1270.CP1.xlsm Separator Venting Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? 'You have indicated that source is in the Non-Attainnsent Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual sourcegreater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section II.D.2)? 'Source requires a permit Colorado Regulation 7, Section XVII 1. Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014? 'Source is subject to Regulation 7, Section XVIi.B.2, G Section XVII.B.2 —General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.G - Emissions Control Alternative Emissions Control (Optional Section) a. Is this separator controlled by a back-up or alternate combustion device (i.e., not the primary control device) that is not enclosed? 'The control device for this separator is subject to Regulation 7, Section XV€I,B.2,e Section XVII.B.2.e —Alternative emissions control equipment Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," "may," "should," and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as `must" and `required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. yen Source Req Source Req SlIMA The control Permit number: Date issued: Issued to: of Division Department of Public Health Er Environment CONSTRUCTION PERMIT 1 7W 1270 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Bill Barrett Corporation Peterson 5-63-30 SWNE 123/7168 SWNE SEC 30 T5N R63W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description Steffen Flare 008 High pressure separators routed to flare during sales pipeline unavailability Open Flare This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to this specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) COLORADO Air Air.Pailution Control Division r.?apar 4e it 1'ei41€r• hie s E- tt�rv3 f Page 1 of 7 3.%er �s ,•ir.wner • • aerator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) ) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO Steffes Flare 008 -- 3.2 38.3 14.6 Point Note: 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 not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The emission points in the table below shalt be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled Steffes Flare 008 Emissions from the separators are routed to an open flare during gas sales pipeline downtime VOC and HAP COLORADO Aix Pollution Control Division Page 2 of 7 PRO 8. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Steffes Flare 008 Natural Gas Venting 74 MMSCF Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 9. The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from the separator(s) using the flow meter. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 11. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 12. The open flare covered by this permit has been approved as an alternative emissions control device under Regulation Number 7, Section XVII.B.2.e. The open flare must have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16, and be designed so that an observer can, by means of visual observation from the outside of the open flare, or by other convenient means approved by the Division, determine whether it is operating properly. This open flare must be equipped with an operational auto -igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 13. The separator covered by this permit is subject to Regulation 7, Section XVII.G. (State Only). On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the date of first production by air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. OPERATING a MAINTENANCE REQUIREMENTS 14. 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 the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING ;COLORADO Air Pollution Gorttrot Division I part: .t of Puti He £Y E Environment Page 3 of 7 15. The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XVII.H.2. and XVII.A.16) Periodic Testing Requirements 16. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 17. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) in ozone nonattainment areas emitting less than 100 tons of VOC or 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. Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. GENERAL TERMS AND CONDITIONS 18. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 19. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of [COLORADO Air Potlutioxt Control Division 7eP Is •>x:3 a PbOutMic Health fo,Nir nrne t Page 4 of 7 for o • ::'ning final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 20. 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. 21. 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. 22. 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 shalt 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. 23. 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. 24. 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: Betsy Gillard, PE Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bill Barrett Corporation. COLORADO Air Pollution Control. Division. S,,wtrfx,rttyr Pt,Wi ° §ie " 6 EmPwonment Page 5 of 7- Note ,,.1" it+ d a •., is pe issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/agcc-reps 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Facility Equipment ID AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) Steffes Flare 008 Benzene 71432 3696 185 Toluene 108883 4696 235 Ethylbenzene 100414 380 19 Xylenes 1330207 2567 128 n -Hexane 110543 30,389 1519 2,2,4- Trimethylpentane 540841 2022 101 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 008: CAS # Pollutant Uncontrolled Emission Factors (lb/MMSCF) Controlled Emission Factors (lb/MMSCF) Source N0x 86.564 86.564 AP -42 Chapter 13.5 CO 394.630 394.630 V0C 20719.00 1035.95 Site -specific extended gas analysis 71432 Benzene 49.938 2.497 108883 Toluene 65.894 3.295 100414 Ethylbenzene 5.135 0.257 COLORADO Air Pollution Control Division pavtrmet%. Purkzsie i+Gea-lrrirmeit Page 6 of 7 CAS # Pollutant U . trolled Emission Factors (lb/MMSCF) Controlled Emission Factors (lb/MMSCF) Source 1330207 Xylene 34.694 1.735 110543 n -Hexane 410.662 20.533 540841 2, Trimethylpentane 27.328 27.328 1.366 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, CO, n -Hex, total HAPs NANSR Synthetic Minor Source of: VOC, NOx PSD Synthetic Minor Source of: CO 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ 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 COLORADO Mr Pollution Control Division t ep6:xent of Public Heatth is eriinonment Page 7 of 7 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: BetsyGillard Package #: 372279''. Received Date: 12/8/2017 Review Start Date: 3/19/2018 Section 01 - Facility Information Company Name: Bill Barrett Corporation County AIRS ID: 123 Plant AIRS ID: 7168 Facility Name: Peterson 5-63-30 SWNE Physical Address/Locatio SWNE quadrant of Section 30, Township 5N, Range 63W, in Weld County, Colorado Type of Facility: Exploration & Production Well Pad What industry segment? oil &Natural Gas Production & Processing Is this facility located in a NAAQS non attainment area? If yes, for what pollutant? ca on Monoxide (CO) Pa iculate Matter (PM) ne (NOx & VOC) Weld Quadrant Section Township Range SWNE 63 Section 02 - Emissions Units In Permit Application AIRS Point 8 Emissions Source Type Equipment Name Emissions Control? Permit tt Issuance # Self Cert Required? Action Engineering Remarks 001 Condensate Tank GW Tank Battery Yes - 17WE1266.XP 1 No APEN Required Permit Exempt Pre viouslyGP01 004 Natural Gas RICE C-17696/1 , Yes 17WE1267 1 Yes,' Permit initial Issuance ; 005 Natural Gas RICE GP02 Cancellation No longer exists 006 Condensate Tank Condensate Tank Battery Yes 17WE1268 1 Yes Permit initial l5suanee 007 Produced Water Tank Produced Water Tanks yes -;17WE1269'- 1 Yes Permit Initial Issuance 008 Separator Venting Steffes Flare Yes 17WE1270 1 Yes Permit Initial Issuance 009 Natural Gas RICE C-13160/1 Yes 17WE1271 1 Yes Permit Initial Issuance 010 Hydrocarbon Liquid Loading Hydrocarbon Loadout Yes 18WE0322 1 Yes Permit Initial Issuance Section 03 - Description of Project Synthetic minor facility with two process streams. The original process stream, called "OW", includes loadout, water tanks, and condensate to nks (all names are prefaced with Point 001 was initially permitted under a GPO'. On 12/8/2417, BBC requested an individual permit for the point. On 3 letter for the point, as decreased throughput make emissions fall below permit thresholds. Operator submitted APEN for Hydrocarbon Loadout, was mistakenly assigned in PIS as Point 002 (which is OW PTS: New Loadout is now Point 010. No changes were made to Point002. Section 04 - Public Comment Requirements Is Public Comment Required? Yes If yes, why? Greater than 25 tons peryear in Non -Attainment Area 23/2018, BBC sent a new APEN requesting an XP Tank Truck Loadout, and is permit exempt)': Corrected In Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) Is this stationary source a major source? SO2 No Yes. NOx CO VOC PM2.5 PM10 TSP HAPs 1 No J 1 151 El 009 One (1) Waukesha L7044GS1, Serial Number C-13160/1, natural gas -fired, turbocharged 4SRB reciprocating internal combustion engine, site rated at 1680 horsepower at 1200 RPM. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Engine Information Engine date of mfg 10/1/2000 Manufacturer: Waukesha Model Number: L7044GSI Serial Number: C-13160/1 RPM: 1200 Site -rated RPM: 1200 Engine Function Compression Derating Mfg's Max. Rated Horsepower @ sea level: 1680 Horsepower used for calcuations: 1680 BSCF @ 100% Load (btu/hp-hr): 7744 Site - Rated BSCF @ 100% load (btu/hp-hr): 7744 Other Parameters Engine Type 4SRB Aspiration turbo -charged Electrical Generator Max Site Rating (kw) 0 Max hrs/yr of Operation 8760 Calculations Fuel Use Rate @ 100% Load 13523.82536 scf/hr ACTUAL Annual Fuel Consumption 0 MMscf/yr MAX F'U I EN I IAL Annual Fuel Consumption 118.469 MMscf/yr REQUESTED Annual Fuel Consumption 118.469 MMscf/yr Fuel Heating Value 962 btu/scf Emission Control Information This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. Emissions Summary Table NOTES Initial testing for NOx and CO will be required, because source syn minor for NOx and CO and ;>500,hp. BSFC and uncontrolled CO & NOx emission factors are from manufacture spec sheet. VOC EF on manufacturer spec sheet is 0.35 g/hp hr, operator used NSPS JJJJ limit of 0.7 g/hp-hr strolled NO sand CO EFs are from Emit Technologies specification sheet. They will be verified with a stack test. Operator calculated uncontrolled emissions using a throughput of 119 MMscf/yr, but PTE :for this engine is 118.5' MMscf/yr. Requested throughput arid uncontrolled emissions on APEN were redlined with operator consent. Operator requested removal of "Emission and Operating Limitations"section from Condition 14, I removed t since this. facility isn't major for HAPs.', Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source NOx 13.300 g/hp-hr 0.600 g/hp-hr 215.3 tpy 9.7 tpy Manufacturer CO 11.200 g/hp-hr 1.035 g/hp-hr 181.3 tpy 16.8 tpy Manufacturer VOC 0.700 g/hp-hr 0.700 g/hp-hr 11.3 tpy 11.3 tpy NSPS JJJJ Formaldehyde 0.050 g/hp-hr 0.012 g/hp-hr 1619 lb/yr 389 lb/yr AP -42 Acetaldehyde 0.0028 Ib/MMBTU 0.003 Ib/MMBTU 319 lb/yr 319 lb/yr AP -42 Acrolein 0.0026 Ib/MMBTU 0.003 Ib/MMBTU 296 lb/yr 296 lb/yr AP -42 Methanol 0.0031 lb/MMBTU 0.003 Ib/MMBTU 353 lb/yr 353 lb/yr AP -42 Regulatory Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT ZZZZ Facility is en area source of HAPs, so engine is not subject to major source requirements. Engine is existing Reg 7 XVII.E.2 Standards The engine is not subject because it is existing Req 7 XVII.E.3 The engine is subject to Reg 7 XVII.E.3 because the engine is rated greater than 500 hp Reg 7 XVI.B applies? Engine is subject to Reg 7 X\/I.B MACT 7777 (area Is this engine subject to MACT ZZZZ area source requirements? Yes source) NSPS JJJJ Is this engine subject to NSPS JJJJ? I No Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. 17WE1271.CP1.xlsm CONSTRUCTION PERMIT Permit number: Date issued: Issued to: 17WE1271 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Bill Barrett Corporation Peterson 5-63-30 SWNE 123/7168 SWNE SEC 30 T5N R63W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description C-13160/1 009 One (1) Waukesha L7044GSI, Serial Number: C13160/1, natural gas -fired, turbo -charged 4SRB reciprocating internal combustion engine, site rated at 1680 horsepower. This emission unit is used for natural gas compression. Non selective catalytic reduction (NSCR) system and air fuel ratio control This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Waukesha L7044GSI engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS) included in this permit as Attachment A. 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 the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) 2. 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 COLORADO Air Pollution Control Division w7v'p4T_S'k:!'tiL !:if I!Ufii� 3'₹C'£i:°n.C E �ii[DI^T3Y£f Page 1 of 16 of thi construction permit or the date on which such duled to ommence as set forth in the permit application at-= h -r conti - onstruction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 3. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 4. 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 5. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO), VOC CO C-13160/1 009 -- 9.7 11.3 16.2 Point Note: 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 not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits for both criteria and hazardous air pollutants shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 6. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled C 13160/1 009 Non -selective catalytic reduction (NSCR) system and air -fuel ratio control NOx, CO, HAPs PROCESS LIMITATIONS AND RECORDS 7. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits COLORADO Air Pollution Control Division Iietusie v f _-7.40r;men[ Page 2 of 16 Cl Epm . t int Elrocesarameter Annual Limit C-13160/1 009 Natural Gas Consumption 118.5 MMscf Fuel consumption shall be measured by one of the following methods: individual engine fuel meter or facility -wide fuel meter attributed to fuel consumption rating and hours of operation. 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 8. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 9. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. Ft 4.) 10. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 11. This equipment is subject to the control requirements for stationary and portable engines in the 8 -hour ozone control area under Regulation 7, Section XVI.B.1. For rich burn reciprocating internal combustion engines, a non -selective catalyst reduction system and an air -fuel ratio controller shall be required. 12. This equipment is subject to the control requirements for natural gas -fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas -fired reciprocating internal combustion 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: Maximum' Engine HP Construction or Relocation Date Emission Standard in g/hp-hr NOx CO VOC ≥500HP July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 0.7 Maximum engine horsepower is the nameplate rating of the engine and does not account for deration. Note: Per Regulation No. 7, Section XVII.B.5, internal combustion engines that are subject to an emission standard or an emissions control requirement in a federal maximum achievable control technology ("MACT") standard under 40 CFR Part 63, a Best Available Control Technology ("BACT") limit, or a New Source Performance Standard under 40 CFR Part 60 are not subject to this Section XVII. 13. This source is subject to the requirements of: COLORADO I Air Pollution Control Division 3 azpanfm3rit of PbttPi: 41133th a ewtronnie^ t Page 3 of 16 . National Emissions Standards for Hazardous Air ternal Combustion Engines (RICE) of 40 C.F.R. Part • Regulation No. 8, Part E, Subpart I.A, National Emission Standards for Hazardous Air Pollutants for Source Categories: General Provisions, 40 CFR Part 63 including, but not limited to, the following: • General Compliance Requirements o §63.6605(a) - You must be in compliance with the emission limitations and operating limitations in this subpart that apply to you at all times, except during periods of startup, shutdown, and malfunction. o §63.6605(b) - If you must comply with emission limitations and operating limitations, you must operate and maintain your stationary RICE, including air pollution control and monitoring equipment, in a manner consistent with good air pollution control practices for minimizing emissions at all times, including during startup, shutdown, and malfunction. • Testing and Initial Compliance Requirements o §63.6610(a) - You must conduct the initial performance test or other initial compliance demonstrations in Table 4 to Subpart ZZZZ of Part 63 that apply to you within 180 days after the compliance date that is specified for your stationary RICE in §63.6595 and according to the provisions in §63.7(a)(2). o §63.6615 - If you must comply with the emission limitations and operating limitations, you must conduct subsequent performance tests semiannually (as per Table 3 of Subpart ZZZZ to Part 63). After you have demonstrated compliance for two consecutive tests, you may reduce the frequency of subsequent performance tests to annually. If the results of any subsequent annual performance test indicate the stationary RICE is not in compliance with the CO or formaldehyde emission limitation, or you deviate from any of your operating limitations, you must resume semiannual performance tests. o §63.6625(a) - If you elect to install a CEMS as specified in Table 5 of this subpart, you must install, operate, and maintain a CEMS to monitor CO and either oxygen or CO2 at both the inlet and the outlet of the control device according to the requirements in paragraphs 63.6625(a)(1) through 63.6625(4) of Subpart ZZZZ to Part 63. o §63.6625(b) - If you are required to install a continuous parameter monitoring system (CPMS) as specified in Table 5 of this subpart, you must install, operate, and maintain each CPMS according to the requirements in §63.8. o §63.6630(a) - You must demonstrate initial compliance with each emission and operating limitation that applies to you according to Table 5 of Subpart ZZZZ to Part 63. o §63.6630(b) - During the initial performance test, you must establish each operating limitation in Tables 1 b and 2b of Subpart ZZZZ to Part 63 that applies to you. o §63.6630(c) - You must submit the Notification of Compliance Status containing the results of the initial compliance demonstration according to the requirements in §63.6645. • Continuous Compliance Requirements o §63.6635(b) - Except for monitor malfunctions, associated repairs, and required quality assurance or control activities (including, as applicable, calibration checks and required zero and span adjustments), you must monitor continuously at all times that the stationary RICE is operating. ;COLORADO Air Pollution Control Division ironment Page 4 of 16 data corded during monitoring malfunctions, uired qu , ity assurance or control activities in data averages ort e n or operating levels. You must, however, use all the valid data collected during all other periods. o §63.6640(a) - You must demonstrate continuous compliance with each emission limitation and operating limitation in Tables 1a and 1b and Tables 2a and 2b of subpart ZZZZ of Part 63 that apply to you according to methods specified in Table 6 of Subpart ZZZZ of Part 63. o §63.6640(b) - You must report each instance in which you did not meet each emission limitation or operating limitation in Tables 1a and 1b and Tables 2a and 2b of Subpart ZZZZ of Part 63 that apply to you. These instances are deviations from the emission and operating limitations in this subpart. These deviations must be reported according to the requirements in §63.6650. If you change your catalyst, you must reestablish the values of the operating parameters measured during the initial performance test. When you reestablish the values of your operating parameters, you must also conduct a performance test to demonstrate that you are meeting the required emission limitation applicable to your stationary RICE. o 563.6640(d) - Consistent with §563.6(e) and 63.7(e)(1), deviations from the emission or operating limitations that occur during a period of startup, shutdown, or malfunction are not violations if you demonstrate to the Administrator's satisfaction that you were operating in accordance with §63.6(e)(1). For new, reconstructed, and rebuilt stationary RICE, deviations from the emission or operating limitations that occur during the first 200 hours of operation from engine startup (engine burn -in period) are not violations. o §63.6640(e) - You must also report each instance in which you did not meet the requirements in Table 8 of Subpart ZZZZ to Part 63 that apply to you. • Notifications, Reports and Records o §63.6645(a) - If you own or operate a stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions you must submit all of the notifications in §563.7(b) and (c), 63.8(e), (f)(4) and (f)(6), 63.9(b) through (e), and (g) and (h) that apply to you by the dates specified. o §63.6645(g) - If you are required to conduct a performance test, you must submit a Notification of Intent to conduct a performance test at least 60 days before the performance test is scheduled to begin as required in §63.7(b)(1). o 563.6645(h) - If you are required to conduct a performance test or other initial compliance demonstration as specified in Tables 4 and 5 of Subpart ZZZZ to Part 63, you must submit a Notification of Compliance Status according to 563.9(h)(2)(ii). ■ §63.6645(h)(1) - For each initial compliance demonstration required in Table 5 of Subpart ZZZZ to Part 63 that does not include a performance test, you must submit the Notification of Compliance Status before the close of business on the 30th day following the completion of the initial compliance demonstration. • §63.6645(h)(2) - For each initial compliance demonstration required in Table 5 of Subpart ZZZZ to Part 63 that includes a performance test conducted according to the requirements in Table 3 to this subpart, you must submit the Notification of Compliance Status, including the performance test results, before the close of business on the 60th day following the completion of the performance test according to §63.10(d)(2). o 563.6650(a) - You must submit each report in Table 7 of Subpart ZZZZ to Part 63 that applies to you. COLORADO Air Pollution Control Division 1 Jewtme t a" Out , hes tis & E,v'monnlee.4 Page 5 of 16 the emission and operating limitations, you must 5(a)(1) through (a)(3), §63.6655 (b)(1) through o §63.6660(a) - Your records must be in a form suitable and readily available for expeditious review according to §63.10(b)(1). o §63.6660(b) - As specified in §63.10(b)(1), you must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. o §63.6660(c) - You must keep each record readily accessible in hard copy or electronic form on -site for at least 2 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to §63.10(b)(1). You can keep the records off -site for the remaining 3 years. o §63.6655(d) - You must keep the records required in Table 6 of Subpart ZZZZ of Part 63 to show continuous compliance with each emission or operating limitation that applies to you. • Other Requirements and Information o §63.6665 - Table 8 to this subpart shows which parts of the General Provisions in §§63.1 through 63.15 apply to you. OPERATING Ft MAINTENANCE REQUIREMENTS 14. 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 the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 15. A source initial compliance test shall be conducted on the emissions point in this permit to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emission limits in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. Periodic Testing Requirements 16. This engine is subject to the periodic testing requirements of 40 C.F.R Part 63, Subpart ZZZZ. ADDITIONAL REQUIREMENTS 17. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a charge in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or COLORADO Air Pollution Control Division ,:eu{;rt -x. tt PutAi t 1u th vthvirornmenc Page 6 of 16 ounds ) and nitrogen oxides sources (NOX) in ozone a ar ,"N g les 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) tans per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. • 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, 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. GENERAL TERMS AND CONDITIONS 18. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 19. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 20. 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. 21. 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. 22. 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 COLORADO 1 Air Pollution Control Division arprir_i - it of Poetic Pitmen &Environment Page 7 of 16 ll be d :-med denied ab initio. This permit may be revoked on and fi l authorization by the Air Pollution Control Division o u - fo Color. _ it 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. 23. 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. 24. 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: Betsy Gillard, PE Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bill Barrett Corporation. COLORADO Air Pollution Control Division Department Health Envirotinwnt Page 8 of 16 1) Th y �� ho -r i .-.. red is 'a es for thy, rocessing time for this permit. An invoice for these fees will be issued a ter t e permit is issued. e permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 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 Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 009 Formaldehyde 50000 1619 389 Acetaldehyde 75070 319 319 Acrolein 107028 296 296 Methanol 67561 353 353 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 009: Pollutant CAS # Uncontrolled Emission Factors Controlled Emission Factors Units (lb/MMBtu or g/bhp-hr) Uncontrolled Source/Controlled Source NOx 13.30 0.60 g/bhp-hr Manufacturer CO 11.50 1.00 g/bhp-hr Manufacturer VOC 0.70 0.70 g/bhp-hr NSPS JJJJ Formaldehyde 50000 0.050 0.012 g/bhp-hr Manufacturer Acetaldehyde 75070 0.0028 N/A Lb/MMBtu AP -42 Acrolein 107028 0.0026 N/A Lb/MMBtu • AP -42 Methanol 67561 0.0031 N/A Lb/MMBtu AP -42 Note: The controlled emissions factors for this point are based on a Brake -Specific Fuel Consumption Factor of 7,744 Btu/hp-hr and a fuel heat value of 962 Btu/scf. 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 ICOLORADO Mr Pollution Control Division :p: rtme t V' Pub ii•_ Helath 6 Envimr,r37ea;C Page 9 of 16 the APEN expiration date for each emissions point arding a specific expiration date call the Division 7) 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 Additional information regarding area source standards can be found on the EPA website at: http:/ /www.epa.gov/ttn/atw/area/arearules.html 8) This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines (See August 20, 2010 Federal Register posting - effective October 19, 2010). The August 20, 2010 amendments to include requirements for existing engines located at area sources and existing 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/rice/fr20au10.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html 9) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 10) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, CO, n -Hex, total HAPs NANSR Synthetic Minor Source of: VOC, NOx PSD Synthetic Minor Source of: CO MACT ZZZZ Area Source Requirements: Applicable 11) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix 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 ,COLORADO I Air Pollution Control Division prstoveit of Petral. Hfe, eh & Environment Page 10 of 16 CT aG 0-63. u part • Q - Subpart YYYY . 5 ...';. 83 1 fix, bpart. - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX COLORADO Air Pollution Control Division Page 11 of 16 OPE , A TING SCENARIOS AT Ax s, TER nh COMBUSTION ENGINES December 10, 2008 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 permittee shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. A.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 permittee 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 permittee shall maintain a copy of all Applicability Reports required under section A.1.2 and make them available to the Division upon request. A.1.1 The permittee 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 emissions from the temporary replacement engine comply with the emission limitations for the existing permitted engine as determined in section A.2. Measurement of emissions from the temporary replacement engine shall be made as set forth in section A.2. A.1.2 The permittee may permanently replace the existing compressor engine with an engine that is of the same manufacturer, model and horsepower without modifying this permit so long as the emissions from the permanent replacement engine comply with 1) the permitted annual emission limitations for the existing engine, 2) any permitted short-term emission limitations for the existing permitted engine, and 3) the applicable emission limitations as set forth in the Applicability Report submitted to the Division with the Air Pollutant Emissios Notice (APEN) for the replacement engine (see COLORADO Air r Pollution Control Division ;,'tier. -e^Hean E ,reran*nt Page 12 of 16 http:/ ittin tml for example applicability report formats). Measu a ssi s fr• th <.er =nent rept ement engine and compliance with the applicable emisati ath in n 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 permittee 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 https://www.colorado.gov/pacific/cdphe/alternate- operating-scenario-aos-reporting-forms.. This submittal shall be accompanied by a certification from a person legally authorized to act on behalf of the source 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 permittee 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. A.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 permittee 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 permittee shall measure nitrogen oxide (NOX) 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 website at: http://www.cdphe.state.co.us/ap/down/portanalyzeproto.pdf 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. For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd ® 15% O2) that the existing unit is currently subject to or the COLORADO Air Pollution Control Division Jepast+ru ,t of Pu€z€ I;ca3;vt E virortrrent Page 13 of 16 replac units a the test shall be converted to the appropriate nalyzer 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 wilt 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. A.3 Applicable Regulations for Permanent Engine Replacements A.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B 5 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 5O2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this A0S, 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 5O2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (5 60.331) and 40 CFR Part 72 (S 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. A.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. COLORADO Air Pollution Control Division Department of » HeaP.^. ;'J E ironnient Page 14 of 16 priately sized for the engine and shall be operated ions. The source shall submit copies of the relevant Applicability Reports required under Condition A.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: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NOx CO VOC 100<Hp<500 January 1, 2008 2.0 4.0 1.0 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 A.1.2 A.3.3 NSPS for spark ignition internal combustion engines: 40 CFR 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 burn 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 40 CFR 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 A.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 A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.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 November 1, 2008 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 8, S 1.8 (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. A.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A.3.4.1 Area Source for HAPs A permanent replacement engine located at an area source that commenced construction or reconstruction after June 12, 2006 as defined in S 63.2, will meet the requirements of 40 CFR Part 63, COLORADO 1 Air Pollution Control Division Izepourgnt t e b y G: vir6rimer:t Page 15 of 16 Subpa the F ^ me 40 C ` Part 60, Subpart JJJJ. An analysis of the applic • ₹ to ₹ g,cor. eep -�, a reportin requirements for the permanent engine repla shal bility rts required under Condition A.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 A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. A.4.3.2 Major source for HAPs A permanent replacement engine that is located at major source is subject to the requirements in 40 CFR Part 63 Subpart ZZZZ as follows: Existing, new or reconstructed spark ignition 4 stroke rich burn engines with a site rating of more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 12/19/02) 2 stroke and 4 stroke lean burn engines with a site rating of more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 4 stroke lean burn engines with a site rating of greater than or equal to 250 but less or equal to 500 hp and were manufactured on or after 1/1/08 are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 2 stroke lean burn or 4 stroke rich burn engines with a site rating of 500 hp or less will meet the requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 4 stroke lean burn engines with a site rating of less than 250 hp will meet the requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition A.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 A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. A.3.5 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. COLORADO Air Pollution Control Division Dewar -x, d s }"-trA t knah v En'Am ;r:cee Page 16 of 16 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Betsy Gitlard!. Package #: 372279'. Received Date: 12/8/2017 Review Start Date: 3/19/2018 Section 01 - Facility Information Company Name: Bill Barrett Corporation - County AIRS ID: Plant AIRS ID: 7168 Facility Name: Peterson 5-63-30 SWNE Physical Address/Locatio SWNE quadrant of Section 30, Township 5N, Range 63W, in Weld County, Colorado Type of Facility: Exploration & Production Well Pad What industry segment? Oil & Natural Gas Prodiittion & Processing Is this facility located in a NAAQS non -attainment area? Yes If yes, for what pollutant? ron Monoxide (CO) Pa iculate Matter (PM) Elne (Nox & VOC) Weld Quadrant Section Township Range SWNE 30 63 Section 02 - Emissions Units In Permit Application AIRS Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks 001 Condensate Tank OW Tank Battery Yes 17WE1266,XP 1 No APEN Required / Permit Exempt Previously GP01 004 Natural Gas RICE C-17696/1 ,: Yes 17WE1267 1 Yes Permit Initial Issuance 005 Natural Gas RICE GP02 Cancellation No longer exists 006 Condensate Talk Condensate Tank Battery Yes 17WE1268 1 Yes Permit Initial Issuance 007 Produced Water. Tank Produced Water Tanks yes 17WE1269 -. 1 Yes: Penis€t Inttial Issuance OD8 Separator Venting Steffes Flare Yes 17W E1270 --: 1 Yes Permit Initial Issuance 009 Natural Gas RICE - C-13160/1 Yes 17WE1271 1 Yes Permit Initial Issuance 010 -- Hydrocarbon Liquid loading Hydrocarbon Loadout Yes 18WE0322 '. 1 - Yes Permit Initial - Issuance Section 03 - Description of Project Synthetic minor facility with two process streams. The original proce with "GW"). ream, called "GW `, nc Point 001 was initially permitted under a GP01.On 12/8/2017, BBC requested an individual perr letter for the point, as decreased throughput make emissions fall below permit thresholds. udes loadou Operator submitted APEN for Hydrocarbon Loadout, was mistakenly assigned in PTS as Point 002 PTS: New Loadout is now Point 010. No changes were made to Point 002. Section 04 - Public Comment Requirements Is Public Comment Required? Yes If yes, why? Greater than 25. ions per year In Non -Attainment Area. ater tan nd condensateta nks II names are prefaced it for the point. On 3/23/2018, BBC sent a newAPEN requesting an XP (which is OW Tank Truck Loadout, and is permit -exempt). Corrected in Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? No If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) Is this stationary source a major source? No yes S02 NOx CO VOC PM2.5 PM10 TSP HAPs O El Hydrocarbon Loadout Emissions Inventory Section 01- Administrative Information Facility AIRs ID: r:. 123 ,,, .. 7168 Plant 10 Section 02 - Equipment Description Details Detailed Emissions Unit Description: Hydrocaebpn Fi Emission Control Device - Description: Encl, dfWrxn.: Is this loadout controlled? Collection Efficiency: Control Efficiency: 95.00 Requested Overall VOC & HAP Control Efficiency 0: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Hydrocarbon Loadout Actual Volume Loaded = Requested Permit Limit Throughput = Potential to Emit (PTE) Volume Loaded = Secondary Emissions - Combustion Device(s) Heat content of waste gas = Volume of waste gas emitted per year = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = 700,000; Barrels (bbl) per year 840,0001 Barrels (bbl) per year 840,000Barrels (bbl) per year 2273.: Btu/scf 792190 scf/year Potential to Emit (PTE) heat content of waste gas routed to combustion device = Section 04 - Emissions Factors & Methodologies Does the company use the state default emissions factors to estimate emissions? Are the emissions factors based on a stabilized hydrocarbon liquid sample drawn a being permitted? Loading Loss Equation L=12.46'5'P'M/T Actual Volume Loaded While Emissions Controls Operating= 3,260 MMBTU per year 3,826 MMBTU per year 3,826 MMBTU per year The stabilized hydrocarbon liquid sample is valid for developing site specific emissions factors. Factor Meaning Value Units Source 5 Saturation Factor 0.6 4 G. ` '42 CFI.pter$.2 Tahte 0.2-1 Sub err 5pa0tinn )066c$End f4onoiah$3sy '{ -G P True Vapor Pressure 4.0611 -.: psia : AP -42 M Molecular Weight of Vapors 60 '.' Ib/Ib-mol -_ AP -42 T Liquid Temperature 512.45 Rankine AP -42 L Loading Losses 4.028750678 lb/1000 gallons AP -42 0.169207528 lb/bbl Component Mass Fraction Emission Factor Units Source Benzene 0.00171915 0.000290893 Ib/bbl Flash gas analysis- Toluene 0.00120747 0.000204313 Ib/bbl Flash gas analysis Ethylbenzene 5.97757E-05 1.01145E-05 Ih/bbl Flash gas: analysis: Xylene 0.000362241 6.12939E -OS lb/bbl Flash „as analysis n -Hexane 0.017607636 0.002992881 Ib/bbl Flash gasanalysis_ 224 TMP 0.000814145 0.00013776 Ib/bbl Flash gas analysis <: Emission Factor Pollutant Hydrocarbon Loadaut Uncontrolled Controlled (Ib/bbl) (Ib/bbl) (Volume Loaded) VOC ;.1.69E-0 Benzene :2.916 -04:x - Toluene 2.04E-04 Ethylbenzene 1.011-0 Xylene 6:13E-0 (Volume Loaded) 8.46E-03 1.45E-05 1.02E-05 5.06E-07 3.06E-06 n -Hexane 2.99E-0 224 TMP 1.38E-04' .50E-04 6.89E-06 Control Device Uncontrolled Uncontrolled Emission Factor Source Pollutant (Ib/MMBtu) (lb/bbl) Emission Factor Source (was t heat combusted) (Volume Loaded) 0.00E+00 0.00E+00 0.00E+00 1.46E-04 PM10 NOx 0.0680 6.65E-04 d aFP=4 Cho... ptar'S�,5„Y�[t Barrels (bbl) per year 2 of 4 K:\PA\2018\18 W E0322.CP1.xlsm Hydrocarbon Loadout Emissions Inventory Section 05 - Emissions Inventory Criteria Pollutants / i Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 SOx NOx VOC CO 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.13 0.11 0.11. 0.13 0.13 71.07 59.22 2.96 71.07 3.55 0.59 0.51 0.51 0.59 0.59 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 244 204 10 244 12 172 143 7 172 9 8 7 0 S 0 51 43 2 51 3 2514 2095 105 2514 126 116 96 5 116 6 Section 06 - Regulatory Summ?OL Analysis Regulation 3, Parts A, B Source requires a permit The loadout must operate with submerged fill and loadout emissions must be routed to flare to satisfy RACT. RACT- Regulation 3, Part B, Section 111.0.2.a (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 00 - Technical Analysis Notes Site -specific sales oil sample collected 10/16/2017 indicates an RVP of 81 psi. Operator used EPA Tanks (AP.42), €or anatyais. Tfie weight%of-e ch HAP was divided by the total VOC weight% togetthe mass fractions Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point g 010 Process It SCC Code 01 4-06-001-32 Crude Oil: Submerged Loading Normal Service (S=0.6) 60 degrees, TVP_ic4: Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 o lb/1,000 gallons transferred PM2.5 0.00 0 lb/1,000 gallons transferred 5Ox 0.00 0 lb/1,000 gallons transferred NOx 0.01 0 lb/1,000 gallons transferred VOC 4.0 95 lb/1,000 gallons transferred CO 0.03 0 lb/1,000 gallons transferred Benzene 0.01 95 16/1,000 gallons transferred Toluene 0.00 95 lb/1,000 gallons transferred Ethylbenzene 0.00 95 lb/1,000 gallons transferred Xylene 0.00 95 lb/1,000 gallons transferred n -Hexane 0.07 95 lb/1,000 gallons transferred 224 TMP 0.00 95 lb/1,000 gallons transferred 3 of 4 K:\PA\2018\18 W E0322.CP1.xlsm Hydrocarbon Loadout Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.l)? 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? 'You have indicated that source is in the Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.1)? 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section II.D.2)? 'Source requires a permit 7. RACT - Are uncontrolled VOC emissions from the loadout operation greater than 20 tpy (Regulation 3, Part B, Section III.D.2.a)? 'The loadout must operate with submerged fill and badout emissions must be routed to flare to satisfy RACT, Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," "may," "should," and tan," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself yowl*: u Go to next, Go to the n Go to next, Go to next Go to next The loadou yes ,,. The loadou Permit number: Date issued: Issued to: Ol Division Department of Public Health & Environment CONSTRUCTION PERMIT 18WE0322 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Bill Barrett Corporation Peterson 5-63-30 SWNE 123/7168 SWNE SEC 30 T5N R63W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description Hydrocarbon Loadout 010 Truck loadout of condensate by submerged fill Enclosed Flare 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 the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failureto demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.Rov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months COLORADO I Air Pollution Control Division 3 p^xt - ^t f pcFtii€� 1 ton. i;;r noYm e,tt Page 1 of 8 after either, the date of i ante t c�; truct' ` . :_ it o th date ' which such construction or activity way che• d t�, co nc� as sea ort n the pert application associated with this permi , •iscont r - ` co ' ' on . : - of ei • months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall 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 5. Emissions of air pollutants shall not exceed the following limitations. (Reference: Regulation Number 3, Part B, Section II.A.4) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO Hydrocarbon Loadout 010 -- -- 3.6 -- Point Note: 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 not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits for criteria pollutants OR for both criteria and hazardous air pollutants shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 6. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled Hydrocarbon Loadout 010 Enclosed Flare VOC and HAP PROCESS LIMITATIONS AND RECORDS 7. 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 Number 3, Part B, II.A.4) COLORADO Air Pollution Control Division Page 2 of 8 Process/Consumption Limit Facility Equipment ID AIRS Point Proc '.,, ra `"'' '=' "'' Annua t Hydrocarbon Loadout 010 Condensate Loaded 840,000 barrels 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 8. 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 Number 1, Section II.A.5.) 9. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 10. 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 and emissions shalt be controlled by a flare. (Reference: Regulation 3, Part B, III.D.2) 11. 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. 12. 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.D.2): a. The owner or operator shall inspect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. b. All compartment hatches at the facility (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. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. d. Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs shall be set to release at a pressure that will ensure flashing, working and breathing losses are not vented through the PRD under normal operating conditions. e. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. 13. For this controlled loading operation, 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.D.2): ;COLORADO Air Pollution Control Division Page 3 of 8 a. Install and operate t vapo ' oll: is ;.nd re uipm t t collet apors during loading of tank comp b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. d. Operate all recovery and disposal equipment at a back -pressure less than the pressure relief valve setting of transport vehicles. OPERATING Et MAINTENANCE REQUIREMENTS 14. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEtM) 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 Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 15. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements 16. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 17. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30t'' 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 nonattainmentareas 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. For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or COLORADO AirPollution Control Division z prv,me t -.d b Ne.6 e"orbroiteqt Page 4 of 8 • Whenever a permit li • No later than 30 d,- the ng pir GENERAL TERMS AND CONDITIONS 18. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 19. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 20. 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. 21. 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. 22. 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. 23. 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. 24. 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: Betsy Gillard, PE Permit Engineer COLORADO Air Pollution Corttrol Division '7,%✓L"#. J of i5.ttr c lse£1 .i. E;EUVOrmer t Page 5 of 8 Permit History Issuance 'on Issuance 1 This Issuance Issued to Bill Barrett Corporation. ICOL0RAD0 Air Pollution Control Division :epotme n Err rvrm-, ,,t Page 6 of 8 Notes to Permit Holder at the time o 1) The permit holder is required tor o ems"me ,��.�_. it. An e for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 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 Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 010 Benzene 71432 244 12 Toluene 108883 172 9 Ethylbenzene 100414 8 0 Xylenes 1330207 51 3 n -Hexane 110543 2514 126 2,2,4- Trimethylpentane 540841 116 6 Note: All non -criteria reportable poi utants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 010: Pollutant CAS # Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source V0C 0.169 8.46E-03 AP 42 n -Hexane 110543 2.99E-03 1.50E-04 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) = 4.06 psia M (vapor molecular weight) = 68 lb/lb-mol T (temperature of liquid loaded) = 512.45 °R COLORADO Mr Pollution Control Division L<EnA;nDnmer t Page 7 of 8 The uncontrolled non -criteria multiplying the mass fraction of Controlled emission factors are based on a flare efficiency of 95% and a collection efficiency of 100%. 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: calculated by Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, CO, n -Hex, total HAPs NANSR Synthetic Minor Source of: VOC, NOx PSD Synthetic Minor Source of: CO 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ 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 0L 3RADO Mr Pollution Control Division Page 8 of 8 Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/aped. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: I7 wE J2(1 1 AIRS ID Number: 123 /7168 /004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Bill Barrett Corporation Site Name: Peterson 5-63-30 SWNE Site Location: SWNE Sec 30 T5N R63W Mailing Address: (Include Zip Code) 1099 18th Street, Ste 2300 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Marsha Sonderfan Phone Number: 303-312-8524 E -Mail Address2: CDPHE_Corr@billbarrettcorp.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 372276 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 1I m�� 7s Permit Number: AIRS ID Number: 123 /7168 / 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. OR- E MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit O Change permit limit ❑ Transfer of ownership4 0 Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: Convert GP02 to individual permit and change permit limits. 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. C-17696/1 General description of equipment and purpose: Waukesha L7044GSI Compressor Engine used for natural gas compression For existing sources, operation began on: 9/26/2017 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: //www.colorado.gov/cdphe/attainment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 25 E Yes ❑ No hours/day 7 days/week 52 weeks/year Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 ��. COLORADO 2 . e.p�x-merwnu� H�alr�6 Eavlrnnamrrt Permit Number: AIRS ID Number: 123 /7168 / 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: LI Compression What is the maximum number of hours this engine will be used for emergency back-up power? NA hours/year Engine Make: Waukesha Engine Model: L7044GSI Serial Number6: C-17696/1 What is the maximum designed horsepower rating? 1680 hp What is the engine displacement? 9.6 l/cyl What is the maximum manufacturer's site -rating? hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,744 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke LI 4 -Stroke Combustion: ❑ Lean Burn 0 Rich Burn Ignition Source: 0 Spark ❑ Compression Aspiration: ❑ Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? r❑ Yes ❑ No If yes, what type of AFRC is in use? ❑ 02 Sensor (mV) ❑NOx Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑ Yes El No Engine Dates: What is the manufactured date of this engine? 8/4/2007 What date was this engine ordered? unknown ❑✓ Other: What is the date this engine was first located to Colorado? 2017 What is the date this engine was first placed in service/operation? unknown What is the date this engine commenced construction? unknown What is the date this engine was last reconstructed or modified? NA Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 3 AV COLORADO [:V7 Hubbb EnvlronwN ,0 Permit Number: AIRS ID Number: 123 /7168 / 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (LatitudelLongitude or UTM) 40.373440°, -104.476800° - ' Operator Stac 8117` o � . fi... _ tsc alge Height'"` - R.. a # - u � .`fie . .. �f t4�s F -� �' F •wi to i x eil ' rml i ,Y o over: round LeveC eet) k ._ $_ , �{ Sep) € aua, -� .k..'a ,. 4, 25 1,179 8,162 Indicate the direction of the Stack outlet: (check one) E Upward El Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) E Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 15 ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information r ad r� Fuel Ups "Rat G 'MO Coady � A Actual Annual Fuet�ls� -2 , Requeste �''nnuaLL�e�tttt�Ltrntt�,�^ . tm SCFI(houf s r %§ 26"A$.:+f'%Ss�.... a .. }�,� :W7, MMSCF/ ear Ts, N^�F1i. Pr a.i^a �. .. !:� M SCF yt�eea �M{A.h�FDa = tF r 13,524 449 l 18 .5 E,G c/ i6 /i S From what year is the actual annual amount? NA Indicate the type of fuel used8: El Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) E Field Natural Gas Heating value: 962 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) El Landfill Gas Heating Value: BTU/scf El Other (describe): Heating Value (give units): seo. o4'h J erg J-1 for ill doconvictk'D }.`oh 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 I A- COLORADO 4amp EiYI]I16 Env�ronwnl Formaldehyde Permit Number: AIRS ID Number: 123 /7168 /004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? E Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant NSCR/AFRC Overall Requested, Control :' Efficiency reduction in emissions) TSP (PM) PM10 PM2.5 SOX NOx VOC 95.5% CO NSCR/AFRC 91% Other: Formaldehyde: NSCRIAFRC 76% Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Pollutant TSP (PM) Uncontrolled Basis Criteria: Pollutant.Emissionsinventory„ ,Source (AP -42, Mfg. etc) ncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Requested Annual Permit: ,mission:Li`mit(s)7 ' ncontrolled Emission's (Tons/year) NA 0.01941 lb/mmBtu AP -42 Table 3.2-3 PMi0 PM2.5 0.01941 lb/mmBtu AP -42 Table 3.2-3 NA 0.01941 lb/mmBtu AP -42 Table 32-3 NA SOX NOX VOC 0.00059 13.30 lb/mmBtu g/hp-hr AP -42 Table 3.2-3 Manufacturer e215.3 -sass NA 9.73 0.70 g/hp-hr Manuf./AQCC 11.3 -mse 196.3 11+.e9 11.3 #i-6e CO 11.50 g/hp-hr Manufacturer 16.22 Does the emissions source have any uncontrolled actual emissions of non -criteria ❑✓ Yes ❑ No pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable, Pollutant Emissions Inventory„ Chemical Abstract , Service (CAS) Number Emission Factor;.':'. ual.AnnuaL.Em ssiansy Uncontrolled Basis Units Source (AP -42, 'Mfg_ etc) Uncontrolled Emissions (Poundsfyear) ._ Controlled Emissions `(Pounds/year) 50000 75070 107028 0.05 g/hp-hr Manufacturer Data 1622 389 Acetaldehyde 0.0028 lb/mmBtu AP -42 Table 3.2-3 318 NA Acrolein 0.0026 lb/mmBtu AP -42 Table 3.2-3 300 NA Benzene 71432 Other: 67561 0.0031 lb/mmBtu AP -42 Table 3.2-3 349 NA 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 5 I A� Department of PLAY COLORADO NWa, b FavlronwM Permit Number: AIRS ID Number: 123 /7168 / 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. -l�- Signature of Legally Authorized Person (not ablandor or consultant) Date Marsha Sonderfan EHS Specialist Name (please print) Title Check the appropriate box to request a copy of the: ✓❑ Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https: //www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 l�� COLORADO 6 Oe�mdA.u. H�aIH� tl b:N�anm�irt Condensate Storage Tank(s) APEN - Form APCD-205 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/pacific/cdphe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: '1 Vv e (2(Q AIRS ID Number: 123 / 7168 /QQl p [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Bill Barrett Corporation Site Name: Peterson 5-63-30 SWNE Site Location: SWNE Sec 30 T5N R63W Mailing Address: (Include Zip Code) 1099 18th Street, Ste 2300 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Marsha Sonderfan Phone Number: 303-312-8524 E -Mail Address2: CDPHE_Corr@billbarrettcorp.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that wilt appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 372271 Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 [COLORADO 1 IAV= Permit Number: AIRS ID Number: 123 / 7168 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action El NEW permit OR newly -reported emission source ❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP01 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. - OR • MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: New site with 6 wells, adjacent to Peterson 30 battery. New condensate tank battery with (6) 400 -bbl tanks. Cover under individual permit. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: (6) 400 -bbl condensate tanks For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 Storage tank(s) located at: 9/11/2017 hours/day 7 days/week El Exploration E Production (EEtP) site 52 weeks/year ❑ Midstream or Downstream (non E£tP) site Will this equipment be operated in any NAAQS nonattainment area? IS Yes • No Are Flash Emissions anticipated from these storage tanks? • Yes • No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? 0 Yes ■ No If "yes", identify the stock tank gas -to -oil ratio: 0.00138 m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No 0 ■ Are you requesting a 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual• emissions a 6 ton/yr (per storage tank)? Yes No ■ Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 COLORADO 2 I _ I n,== Permit Number: AIRS ID Number: 123 / 7168 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount Requested Annual Permit Limit4 ` (bb(/year)' Condensate Throughput: 700,000 From what year is the actual annual amount? 2017 Average API gravity of sales oil: 47.1 degrees O Internal floating roof Tank design: ❑✓ Fixed roof 840,D00 RVP of sales oil: 8.1 psi ❑ External floating roof Storage TanklD # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent. Storage Vessel in Storage Tank (month/year). Date of First Production' (month/year) COND 6 2400 8/2017 9/2017 API Number Wells Serviced by this Storage Tank or Tank Battery , (E$P Sites Only) Name of Well , Newly, Reported Well See attached addendum CI CI CI CI CI 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The EaP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordin (Latitude/Longifude.or.U' 40.373440°, -104.476800° Operator Stack ID ; No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) ECDs 20 -- -- -- Indicate the direction of the stack outlet: (check one) 2 Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) El Circular Interior stack diameter (inches): El Square/rectangle Interior stack width (inches): ❑ Other (describe): El Upward with obstructing raincap Interior stack depth (inches): Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 3IAN, COLORADO Oerariater. .1 Public Permit Number: AIRS ID Number: 123 / 7168 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: ❑ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 10 Type: ECD MMBtu/hr Make/Model: (6) IES ECDs Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 % Minimum Temperature: 500 F Waste Gas Heat Content: —2273 Btu/scf MMBtu/hr Constant Pilot Light: ✓❑ Yes ❑ No Pilot Burner Rating: 0.1 ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: % Section 7 -Gas/Liquids Separation Technology Information (EEtP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 8 psig Describe the separation process between the well and the storage tanks: Stream from wells to (6) high-pressure inlet separators, then to (2) heater treaters, then to (4) vapor recovery towers (VRTs) then to condensate storage tanks. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 AV'COLORADO - 4 I AI = Benzene 71432 Permit Number: AIRS ID Number: 123 / 7168 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) VOC NOx CO ECDs 95 NA NA NA NA HAPs ECDs 95 Other: From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Pollutant VOC ,Source (AP -42, 'Mfg. etc) Controlled Emissions? (Tons/year) Requested Annual Permi Emission Limit(s)4 Uncontrolled . • Basis Units Uncontrolled Emissions (Tons%year). Uncontrolled Emissions (Tons% year) ontrolled Emissions (Tons/year) 0.8991 lb/bbl Flash 314.68 15.73 377.62 18.88 NOx 0.068 Ib/MMBtu AP -42 0.59 0.69 CO 0.31 lb/MMBtu AP -42 2.69 3.15 Non -Criteria Reportable Pollutant Emissions Inventory Emission Factor6 Actual Annual. Emissions Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled ": Emissions (Pounds/t'e'ar) 0.0015 lb/bbl Flash 1,082 ontrolled .missions?. ounds/year) 54 Toluene 108883 0.0011 lb/bbl Flash 760 38 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 0.0159 lb/bbl Flash 11,132 557 2,2,4- Trimethylpentane 540841 0.0007 lb/bbl Flash 512 26 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 Attach condensate liquid laboratory analyst, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. .0 COLORADO Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 5 AV t1 =, is Permit Number: AIRS ID Number: 123 / 7168 / [Leave blank Lnless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. 1--pP.1,- IR- Signature of Legally Authorized Person a vendor or consultant) Date Marsha Sonderfan EHS Specialist Name (print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd © COLORADO Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 6 I A- E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Forml Company Name: Bill Barrett Corporation Source Name: Peterson 5-63-30 SWNE Condensate Tanks Emissions Source AIRS M2: 123 / 7168 / 00 (_Q Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 44713 PETERSON 5-63-30-0758C2 /1 05 - 123 - 44714 PETERSON 5-63-30-0758B2 /5 05 -123 - 44718 PETERSON 5-63-30-0857B2 ►ZI 05 -123 - 44717 PETERSON 5-63-30-0560B2 /5 05 - 123 - 44715 PETERSON 5-63-30-0659D2 111 05 - 123 - 44716 PETERSON 5-63-30-0560C2B - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ Footnotes: 1 Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 6 AP FonnAPCD-212-EP-StorageTank-APEN-Addendum.docx Produced Water Storage Tank(s) APEN - Form APCD-207 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store produced water associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, condensate storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/pacific/cdphe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 11 yvri Zug AIRS ID Number: 123 / 7168 / 001 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 Administrative Information Company Name': Bill Barrett Corporation Site Name: Peterson 5-63-30 SWNE Site Location: SWNE Sec 30 T5N R63W lu Address: p Code1099 18th Street, Ste 2300 (Include Zip Code) Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Marsha Sonderfan Phone Number: 303-312-8524 E -Mail Address2: CDPHE_Corr@billbarrettcorp.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 372273 COLORADO 1I AI =o�d 7= Permit Number: AIRS ID Number: 123 / 7168 I [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action El NEW permit OR newly -reported emission source ✓❑ Request coverage under traditional construction permit El Request coverage under a General Permit ❑ GP05 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. OR ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name ❑ Change permit limit El Transfer of ownership' El Other (describe below) OR ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El APEN submittal for permit exempt/grandfathered source El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: New site with 6 wells, adjacent to Peterson 30 Pad. New water tank battery with (2) 400 -bbl tanks. Cover under individual permit. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: 2 produced water tanks For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 9/11/2017 Normal Hours of Source Operation: 24 hours/day 7 days/week 52 Storage tank(s) located at: ✓❑ Exploration Et Production (EU) site weeks/year ❑ Midstream or Downstream (non EEtP) site Will this equipment be operated in any NAAQS nonattainment area? Yes No 12 ■ Are Flash Emissions anticipated from these storage tanks? Yes No A • Are these storage tanks located at a commercial facility that accepts oil production wastewater for processing? Yes No MI 0 Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? Yes No • 0 Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)el 805 series rules? If so, submit Form APCD-105. Yes No • Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No 0 ■ Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 AV ;COLORADO 2H¢4 Permit Number: AIRS ID Number: 1 23 / 7168 I [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Produced Water Throughput: Actual Annual Amount (bbUyear) 350,000 equested Annual Permit. Li"mit4 (bbllyear) 420,000 From what year is the actual annual amount? Tank design: ✓❑ Fixed roof 2017 ❑ Internal floating roof ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage " , Vessels in Storage"Tank Total Volume of ' Storage Tank (bbl) Installation, Date' of Most . Recent Storage Vessel in` "Storage Tank (month/year) -, Date of First Production (month/year) " PW 2 800 8/2017 9/2017 Wells Serviced by this Storage Tank or Tank Battery5 (EB P Sites Only) API Number Name of Well Newly Reported Well See attached addendum 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The EItP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude(Longitude orUTM) 40.373440°, -104.476800° Operator Stac_ k ID No... _ L.Dischaege Height Above Ground Level (feet) ' T_ emp. ; (°F) Flow Rate `. , (ACFM) Velocity (ft/sec) "" ECDs 20 -- -- -- Indicate the direction of the stack outlet: (check one) ❑� Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Square/rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack width (inches): Interior stack depth (inches): Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 COLORADO °°` 3 I AV ,k Permit Number: AIRS ID Number: 123 / 7168 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information D Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: % ❑ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 10 Type: ECD Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: 500 F MMBtu/hr Make/Model: (6) I ES ECDs 95 % 98 Waste Gas Heat Content: Constant Pilot Light: ❑✓ Yes ❑ No Pilot Burner Rating: —2273 0.1 Btu/scf MMBtu/hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: % Section 7 -Gas/Liquids Separation Technology Information (EEtP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 43 psig Describe the separation process between the well and the storage tanks: Stream from wells to (15) high-pressure inlet separators, then to (2) heater treaters, then to produced water tanks. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 COLORADO 4 I AV DµDxm�o:m u1 rf..Dn4En�.. .a Chemical Name Permit Number: AIRS ID Number: 123 / 7168 I [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN forms. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant VOC NOx CO Description of Control Method(s) ECDs Overall Requested Control ;Efficiency (% reduction in emissions) 95 NA NA NA NA HAPs ECDs 95 Other: From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Pollutant VOC Emission Factors Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)4. Uncontrolled Basis Units Uncontrolled Emissions (Tons/year) Controlled Emissions? (Tons/year) Uncontrolled Emissions' (Tons/year) Controlled Emissions (Tons/year) 0.262 lb/bbl State 45.85 2.29 55.02 2.75 NOx 0.068 lb/MMBtu AP -42 0.09 0.10 CO 0.31 Ib/MMBtu AP -42 0.39 0.46 Non -Criteria Reportable Pollutant Emissions Inventory - Chemical Abstract. Service (CAS) Number Emission Factor6. Actual Annual Emissions ,` Uncontrolled Basis Units Source Mfg 'etc) Uncontrolled Emissions'r (Pounds/year) Controlled Emtsstons�, (Poundslyear) Benzene 71432 0.0007 lb/bbl State 2450 123 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 0.022 lb/bbl State 7700 385 2,2,4- Trimethylpentane 540841 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 Attach produced water laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 © !COLORADO 5 I m Departs:mmof AW c 4r p M. 4, cnwroe.,mnu Permit Number: AIRS ID Number: 123 / 7168 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP05 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. Signature of Legally Authorized Person not a vendor or consultant) Date Marsha Sonderfan EHS Specialist Name (print) Title Check the appropriate box to request a copy of the: E✓ Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 COLORADO Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 6 I IfiK E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Form' Company Name: Bill Barrett Corporation Source Name: Peterson 5-63-30 SWNE Produced Water Tanks Emissions Source AIRS ID2: 123 / 7168 / an Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 44713 PETERSON 5-63-30-0758C2 ►/ 05 -123 - 44714 PETERSON 5-63-30-0758B2 05 -123 - 44718 PETERSON 5-63-30-0857B2 05 -123 - 44717 PETERSON 5-63-30-0560B2 .1 05 -123 - 44715 PETERSON 5-63-30-0659D2 /1 05 - 123 - 44716 PETERSON 5-63-30-0560C2B .1 - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter Footnotes: Attach this addendum to associated APEN form when needed to report additional wells. N/A Form APCD-212 10 AP_FormAPCD-212-EP-StorageTank-APEN-Addendum.docx RCceN-ca vR ernes 1 1/6/2018 -6G Natural Gas Venting APEN - Form APCD-211 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Natural Gas Venting only. Natural Gas Venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options wilt not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: I-3 W E 1(2 -CD AIRS ID Number: 123 /7168/ 008 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: SteffeS Flare [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: Bill Barrett Corporation Peterson 5-63-30 SWNE Site Location: SWNE Sec 30 T5N R63W Mailing Address: (Include Zip Code) 1099 18th Street, Ste 2300 Denver, CO 80202 E -Mail Address' CDPHE_Corr@hpres.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Marsha Sonderfan Phone Number: 303-312-8524 /Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. a Form APCD-211 - Natural Gas Venting ADEN - Rev 03/2017 Permit Number: AIRS ID Number: 123 /7168/ 008 [Leave blank unless APCD has already assigned a permit r and AIRS ID] Section 2- Requested Action ✓❑ NEW permit OR newly -reported emission source -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) - OR APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - 111 Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: New site with 6 wells, adjacent to Peterson 30 Pad. Flaring, individual permit. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Operates as needed. (1) Steffes dual head high capacity flare For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 10 / 12 / 2017 / / ❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions days/week weeks/year ❑✓ Yes ❑ No ❑ Yes ❑✓ No co Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 2 I R ADD Permit Number: AIRS ID Number: 123 /7168/ 008 [Leave blank unless APCD has already assigned a permit r". and AIRS ID] Section 4 - Process Equipment Information ❑✓ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: Serial #: Capacity: Gal/min ❑ Compressor Rod Packing Make: Model: # of Pistons: Leak Rate: Scf/hr/pist ❑ Blowdown Events # of Events/year: Volume per event: MMscf/event ❑✓ Other Description: Steffes Dual head high capacity 12 MMscf/day flare If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? 0 Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: 1 ,273 BTU/SCF Requested: 74.00 MMSCF/year Actual: 74.00 MMSCF/year -OR- Requested: Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: Molecular Weight: 24.4056 VOC (mole %) 14.8357 VOC (Weight %) Benzene (mole %) 0.0243 Benzene (Weight %) Toluene (mole %) 0.0261 Toluene (Weight %) Ethylbenzene (mole %) 0.0018 Ethylbenzene (Weight %) Xylene (mole %) 0.0124 Xylene (Weight %) n -Hexane (mole %) 0.1808 n -Hexane (Weight %) entane 2,2,4-Trimethylphpentane (mole %) 0.0091 2,2,4-Trimet (we �ht %) Additional Required Information: ❑✓ Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 3 COLORADO Permit Number: AIRS ID Number: 123 /7168/ 008 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information eographicalCoordinates .' (Latitude/Longitude or UT4f) „ 40.373440°, -104.476800° n � eras© k Yc h h��- Disch r e ei ht � � �� €ground Le. e., 1 s ge Flare 20 Indicate the direction of the stack outlet: (check one) 0 Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): 0 Other (describe): ❑ Upward with obstructing raincap Section 6 - Control Device Information ❑ VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed ❑ Combustion Device: Pollutants Controlled: Rating: Type: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: MMBtu/hr Make/Model: % Waste Gas Heat Content Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating Btu / scf MMBtu / hr ❑✓ Other: Pollutants Controlled: VOC, HAPs Description: Flare Control Efficiency Requested 95% Form APCD-211 -Natural Gas Venting APi=N - Rev 03/2017 4 eCOL0RAD.o PM PM Permit Number: AIRS ID Number: 123 /7168i 008 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? El Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): verall Requested Control Efficteency reduction in emissions. SOX NO. VOC Flare 95% CO HAPs Flare 95% Other: From what year is the following reported actual annual emissions data? 2017 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) mission Factor; Units Emission;; Factor Source (AP -42, Mfg etc) :x ncontrolled (Tons/year,) Controlled6 (Tons/year, ncontrolte ('Tons/yeur) ontrolled ro s/year, SOX NO. 0.058 lb/MMBtu AP -42 3.20 3.20 VOC 103.59 lb/MMBtu Gas Anal. 766.56 38.33 766.56 38.33 CO 0.21 lb/MMBtu AP -42 14.59 14.59 Benzene 0.25 lb/MMBtu Gas Anal. 1.85 0.09 1.85 0.09 Toluene 0.32 Ib/MMBtu Gas Anal. 2.35 0.12 2.35 0.12 Ethylbenzene Xylenes 0.17 Ib/MMBtu Gas Anal. 1.28 0.06 1.28 0.06 n -Hexane 2.05 lb/MMBtu Gas Anal. 15.19 0.76 15.19 0.76 2,2,4- Trimethylpentane 0.14 Ib/MMBtu Gas Anal. 1.01 0.05 1.01 0.05 Other: 5 Requested values will become permit limiitations. Requested limit(s) should consider future process growth. 6Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. %toLoR ADO Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 5 I Permit Number: AIRS ID Number: 123 /7168/ 008 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Marsha Sonderfan Digitally signed by Marsha Sandedan ON; en -Marsha Sanded' , w831 Barrett Camoratim. au. Imiema derfan®bmalmnaary.wm, GJ_ 0Ne: ]B16A1A611313e -06bP 4/6/2018 Signature of Legally Authorized Person (not a vendor or consultant) Marsha Sonderfan EHS Specialist Date Name (please print) Title Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance El Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd 6I COLORADO DePer.enrc;gmtm x:: ^thMErs ana,.aa Reciprocating Internal Combustion Engine APEN Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.aov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 1 lvE 7_1AIRS ID Number: 123 /7168 / ooq [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Bill Barrett Corporation Peterson 5-63-30 SWNE Site Location: SWNE Sec 30 T5N R63W Mailing Address: (Include Zip Code) 1099 18th Street, Ste 2300 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Marsha Sonderfan Phone Number: 303-312-8524 E -Mail Address2: CDPHE_Corr@billbarrettcorp.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 372277 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 'AV COLORADO Department. aPanne Permit Number: AIRS ID Number: 123 /7168 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ✓❑ NEW permit OR newly -reported emission source (check one below) ✓❑ STATIONARY source ❑ PORTABLE source ❑✓ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) - OR APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. General description of equipment and purpose: used for natural gas compression C-13160/1 Waukesha L7044GSI Compressor Engine For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.gov/cdphe/attainment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 25 12/20/2017 ✓❑ Yes ❑ No hours/day 7 days/week 52 weeks/year Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 2I COLORADO Dcpartmcnt. Put 1.1c HNun _ Sm!ronnan, Permit Number: AIRS ID Number: 123 /7168 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ - Pump ❑ Water Pump ❑ Emergency Back-up ❑ - Other: ❑✓ Compression What is the maximum number of hours this engine will be used for emergency back-up power? NA Engine Make: Waukesha hours/year Engine Model: L7044GSI Serial Number6: C-13160/1 What is the maximum designed horsepower rating? 1680 hp What is the engine displacement? 9.6 l/cyl What is the maximum manufacturer's site -rating? hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,744 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ❑✓ 4 -Stroke Combustion: ❑ Lean Burn 2 Rich Burn Ignition Source: ❑✓ Spark ❑ Compression Aspiration: ❑ Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑r Yes ❑ No If yes, what type of AFRC is in use? ❑ O2 Sensor (mV) ❑NOX Sensor (ppm) Is this engine equipped with a Low-NOX design? ❑ Yes Q No Engine Dates: What is the manufactured date of this engine? 10/2000 What date was this engine ordered? unknown ❑✓ Other: What is the date this engine was first located to Colorado? 2017 What is the date this engine was first placed in service/operation? unknown What is the date this engine commenced construction? unknown What is the date this engine was last reconstructed or modified? NA Is this APEN reporting an AOS replacement engine? ❑ Yes ✓❑ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 3 • COLORADO �jWWii oepm,n, r s,p r Permit Number: AIRS ID Number: 123 /7168 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.373440°, -104.476800° Operator ac k Discharge Height a* Above Ground Level (Feet) c t $' p. Temp ( -- 3 � 4FlmvAtate fi ti CFM) '-' _ , r .., eloaty (ftlsecf 25 1,179 8,162 Indicate the direction of the Stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward El Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 15 El Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fjjel Use gate:,_100%Load , ( r SCF/hour s� � � � � '1' �r . try .,.a ₹�. fi� � �� _ k�u, w..r e ualAnnual Fuel Use iMMSCFIyear) ..� s„„{..�::}"`r�r+ � � ��e 4 Requested AnnuaGPermit,Limtt' �{� � �� MSCF/year) F,'at.,�w�a..'4K..R0-,.,.,. 13,524 1-1-9 11%.5 B(, From what year is the actual annual amount? NA Indicate the type of fuel used8: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑✓ Field Natural Gas Heating value: 962 BTU/scf © Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): $R!L akira-/ Q.?.\ dot.m ,,w)r..k; vA. 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 4 1.4k 7 COLORADO _ m . Sn+nrormm* Formaldehyde Permit Number: AIRS ID Number: 123 /7168 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant TSP (PM) Primary Control Equipment Description. Overall Requested Control Efficiency (% reduction in emissions) PM10 PM2.5 SOX NOx VOC NSCR/AFRC 95.5% CO NSCR/AFRC 91% Other: Formaldehyde: NSCR/AFRC 76% Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? Pollutant TSP (PM) Uncontrolled Basis Units Criteria Pollutant Emissions Inventory_ Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/yearn) ontrolled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) 0.01941 lb/mmBtu AP -42 Table 3.2-3 mtrolled missions .. ons/year) NA PM 10 PM2.5 0.01941 lb/mmBtu AP -42 Table 3.2-3 NA 0.01941 lb/mmBtu AP -42 Table 3.2-3 NA SOX NOx VOC 0.00059 lb/mmBtu AP -42 Table 3.2-3 NA 13.30 g/hp-hr Manufacturer 215.3 215.70 u- s —11.36 I86. 3 191.69 9.73 0.70 g/hp-hr Manuf./AQCC 11.3 1+86 CO 11.50 g/hp-hr Manufacturer 16.22 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑J Yes ❑ No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Abstract Service (CAS) Number. Emission Factor ncontrolled Basis g/hp-hr ctual.Annual Emissions',? ource Mfg_ ncontrolled Emissions (Poundsfyear)`. Controlled Emissions (Pounds/year) 50000 75070 107028 0.05 Manufacturer Data 1622 389 Acetaldehyde 0.0028 lb/mmBtu AP -42 Table 32-3 318 NA Acrolein Benzene 0.0026 lb/mmBtu AP -42 Table 32-3 300 NA • 71432 Other: 67561 0.0031 lb/mmBtu AP -42 Table 3.2-3 349 NA 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. ems') .for 2L do we -0,01r\ c/16/It Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 5 COLORADO I . Permit Number: AIRS ID Number: 123 /7168 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. ,ice oU -per- f - Signature of Legally Authorized Person not a vendor or consultant) Date Marsha Sonderfan EHS Specialist Name (please print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 COLORADO Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 6 I &.- °H,==t, Hydrocarbon Liquid Loading APEN - Form APCD-208 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Hydrocarbon Liquid Loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: �$\AT 0322 AIRS ID Number: 123/7168 / 010 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: Hydrocarbon Loadout [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Namel: Site Name: Bill Barrett Corporation Peterson 5-63-30 SWNE Site Location: SWNE Sec 30 T5N R63W Mailing Address: (Include Zip Code) 1099 18th Street, Ste 2300 Denver, CO 80202 E -Mail Address2: CDPHE_Corr@billbarrettcorp.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Marsha Sonderfan Phone Number: 303-312-8524 lUse the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017 372274 1 I AVCOLORADO mru‘ ,;4 Permit Number: AIRS ID Number: 123 /7168 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ® NEW permit OR newly -reported emission source ❑✓ Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN Filing fee. -OR- MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) OR - • APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: New site with 6 wells, adjacent to Peterson 30 Pad. New condensate tank battery with (6) 400 -bbl tanks. Individual permit. Loadout will be controlled. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Hydrocarbon loadout, controlled by ECDs. For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 9/ 11 /2017 / / Will this equipment be operated in any NAAQS nonattainment area? Q Yes Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Does this source load gasoline into transport vehicles? Is this source located at an oil and gas exploration and production site? If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Does this source splash fill less than 6750 BBL of condensate per year? Does this source submerge fill less than 16308 BBL of condensate per year? Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 2 I E Yes Yes Yes No No No No ❑ Yes lJ No ❑ Yes El No ❑ Yes El No COLORADO SmNa. ., Permit Number: AIRS ID Number: 123/7168/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: ❑✓ Condensate ❑ Crude Oil ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded4: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth 840,000 Bbl/yr This product is loaded from tanks at this facility into: (eg, "rail tank cars" or "tank trucks") Actual Volume Loaded: tank frucks 700,000 Bbl/yr If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: 0.6 Average temperature of bulk liquid loading: 52.45 °F True Vapor Pressure 4.0611 Psia @ 60 ° F Molecular weight of displaced vapors 6 V Lb/lb mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: Bbl/yr Actual Volume Loaded: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Bbl/yr Product Density: Lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume ft3/truckload Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 3 Y COLORADO . Gryftamnn.rP.{ Permit Number: AIRS ID Number: 123/7168/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Geographical Information Geographical Coordinates. (Latitude/Longitude or UTM) 40.373440°, -104.476800° P Stack,ID No� Discharge Height iAbove Ground Level -# (Facet) ,- Temp "x f ) Flow Rate�Ve[ocity £ { fACFMJ '«�.r ,) $ (ft/sec ECDs 20 -- -- -- Indicate the direction of the stack outlet: (check one) O Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Section 6 - Control Device Information ❑ Loading occurs using a vapor balance system: Requested Control Efficiency ❑ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 10 Type: ECD Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: 500 F MMBtu/hr Make/Model: (6) IES ECDs 95 98 Waste Gas Heat Content Constant Pilot Light: ❑r Yes ❑ No Pilot burner Rating -2273 Btu/scf 0.1 MMBtu/hr O Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO ryaaieryu4gnrv. ppTf PM PM Permit Number: AIRS ID Number: 123/7168/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach alt emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Control Equipment Description NA :Overall Requested Control Efficiency (% reduction in emissions) NA SOX NA NA NOx NA NA CO NA NA VOC ECDs 95 HAPs ECDs 95 Other: ❑ Using State Emission Factors (Required for GP07) VOC ❑ Condensate ❑ Crude 0.236 Lbs/BBL 0.104 Lbs/BBL Benzene n -Hexane 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? 2017 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Uncontrolled (Tons/year) ` . Controlleds (Tons/year)' Uncontrolled (Tons/year) Controlled ;' (Tons/year) " Sax NOx 0.11 0.13 VOC 0.16921 R�/bbl AP -42 59.22 2.96 71.07 3.55 CO 0.51 0.59 Benzene Toluene Ethylbenzene Xylenes n -Hexane O .0029°I -0704-76.9. lb/bbl AP -42, Flash 1.05 0.05 1.26 0.06 2,2,4- Trimethylpentane Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 51 171, COLORADO Dapaahirnt m PMYc xvun .•5mlwpmm, Permit Number: AIRS ID Number: 123 /7168 / [Leave blank unless APCD has already assigned a permit # and AIRS ID) Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. Signature of Legally Authorized Person ( a vendor or consultant) Date Marsha Sonderfan EHS Specialist Name (print) Title Check the appropriate box to request a copy of the: E✓ Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250 as applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 6 , Hsa!N?� 5+rvfr. nmm, Hello