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Home My WebLink About20202723.tiff .. COLORADO Department of Public Health&Environment RECEIVED Weld County - Clerk to the Board 1150 O St SEP 01 2020 PO Box 758 WELD COUNTY Greeley, CO 80632 COMMISSIONERS August 24, 2020 Dear Sir or Madam: On August 25, 2020, the Air Pollution Control Division will begin a 30-day public notice period for HighPoint Operating Corporation - Anschutz Coffelt 5-61-35_36 NWNW Production Facility. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Public Notice Coordinator 4300 Cherry Creek Drive S., Denver,Co 80246-1530 P 303-692-2000 www.colorado.gov/cdphe �� c`- t Jared Polls, Governor I Jill Hunsaker Ryan,MPH, Executive Director ,* ..,'. Pv 6 I ;c Rev;e•trJ cc:PI-CrP), 1L (ps))Pw(5 M/Ea/CH/cW), 2020-2723 o9/!'i /2006 (v4) 09/03/2.0 C ,, ,,,...r...; COLORADO 4. ®,/ Air Pollution Control Division Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado CONSTRUCTION PERMIT Permit number: 20WE0131 Issuance: 1 Date issued: Issued to: HighPoint Operating Corporation Facility Name: Anschutz Coffelt 5-61-35_36 NWNW Production Facility Plant AIRS ID: 123/9D9A Physical Location: NWNW SEC 35 T5N R61W County: Weld County Description: Well Production Facility Equipment or activity subject to this permit: Facility AIRS Emissions Control Equipment Point Equipment Description Description ID Crude TKs 008 Four (4) 840 barrel fixed roof storage Enclosed Combustion vessels used to store crude oil Device 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 (Division) no later than fifteen days after commencement of operation under this permit by submitting a Notice of Startup (NOS)form to the Division. The Notice of Startup (NOS) form may be downloaded online at https://www.colorado.gov/pacific/cdphe/air/manage-permit. Failure to notify the Division of startup of the permitted source is a violation of AQCC Regulation Number 3, Part B, 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 must 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/cdphe/air- permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) Page 1 of 9 C"i �Yy� COLORADO IV Air Pollution Control Division Department of Public Health 6 Environment Dedicated to protecting and improving the health and environment of the people of Colorado 3. This permit must expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) F.4.) 4. The operator must 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 must 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 must not exceed the following limitations. (Regulation Number 3, Part B, Section I I.A.4.) Annual Limits: Facility AIRS Tons per Year Emission Equipment ID Point PM2.5 NO,t VOC CO Type Crude TKs 008 --- --- 14.6 2.2 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 must not exceed 8.0 tons per year. Facility-wide emissions of total hazardous air pollutants must not exceed 20.0 tons per year. The facility-wide emissions limitation for hazardous air pollutants must apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, must 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 must 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 owner or operator must use the emission factors found in "Notes to Permit Holder" to calculate emissions and show compliance with the limits. The owner or operator must submit an Air Pollutant Emission Notice (APEN) and receive a modified permit prior to the use of any other method of calculating emissions. 8. The emission points in the table below must 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.) Page 2 of 9 CCOLORADO 4 Air Pollution Control Division Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Facility AIRS Pollutants Equipment Point Control Device Controlled ID Crude TKs 008 Enclosed Combustion Device VOC and HAP PROCESS LIMITATIONS AND RECORDS 9. This source must be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates must be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point Crude TKs 008 Crude Oil throughput 777,450 barrels The owner or operator must monitor monthly process rates based on the calendar month. Compliance with the annual throughput limits must 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 must calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) must be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.)E.) (State only enforceable) 11. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 12. This source is subject to Regulation Number 7, Part D, Section I. The operator must comply with all applicable requirements of Section I and, specifically, must: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for 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, Part D, Section I.C.) (State only enforceable) 13. The combustion device covered by this permit is subject to Regulation Number 7, Part D, Section II.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 II, it must be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, Part D, Section II.A.23; and be designed so that an observer can, by means of visual Page 3 of 9 :-» COLORADO 411 '440 Air Pollution Control Division Department of Public Health Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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 schedule in Regulation Number 7, Part D, Section II.B.2.d. 14. The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Part D, Section II.C.1. The owner or operator must install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons except where the combustion device has been authorized by permit prior to March 1, 2020. The source must follow the inspection requirements of Regulation Number 7, Part D, Section II.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. 15. The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Part D, Section II.C.2. 16. On or before June 30th, 2021 (and on June 30th each year thereafter), the owner or operator of oil and natural gas operations and equipment at or upstream of a natural gas processing plant in Colorado must submit a single annual report that includes actual emissions and specified information in the Division-approved report format. The information included in the annual report must be in accordance with the general reporting requirements of Regulation Number 7, Part D, Section V.B. Beginning July 1, 2020, and each calendar year thereafter, owners or operators must maintain the information according to Regulation Number 7, Part D, Section V.C. for inclusion in the annual report. (Regulation Number 7, Part D, Section V) OPERATING Et MAINTENANCE REQUIREMENTS 17. Upon startup of these points, the owner or operator must 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 OEM 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 18. The owner or operator must 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, Part D, Sections I.C, II.B.2. and II.A.23) Periodic Testing Requirements 19. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. Page 4 of 9 Cr�:^r COLORADO 0 Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado ADDITIONAL REQUIREMENTS 20. A revised Air Pollutant Emission Notice (APEN) must be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30" 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. 21. Federal regulatory program requirements (i.e. PSD, NANSR) must apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source must not exceed the Federal program threshold until a permit is granted. (Regulation Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS 22. 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. 23. 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- Page 5 of 9 9,... COLORADO 40 Air Pollution Control Division Department of Public Health b Enwonment Dedicated to protecting and improving the health and environment of the people of Colorado 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. 24. 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. 25. 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. 26. 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 must constitute a rejection of the entire permit and upon such occurrence, this permit must 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. 27. 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. 28. 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: Lauraleigh Lakocy Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to HighPoint Operating Corporation Page 6 of 9 Crc: COLORADO 4.40 Air Pollution Control Division Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder must 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 must 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 Uncontrolled Controlled Point Pollutant CAS # Emissions Emissions (Ib/yr) (lb/yr) Benzene 71432 2,576 129 Toluene 108883 1,709 85 008 Xylenes 1330207 445 22 n-Hexane 110543 19,874 994 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. Page 7 of 9 C .,, COLORADO Air Pollution Control Division Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado 5) The emission levels contained in this permit are based on the following emission factors: Point 008: Total actual emissions are obtained from the sum of emissions resulting from the storage vessels and combustion of waste gas from the storage vessels (process 01) and the combustion of pilot light gas (process 02). Process 01: Crude Oil Throughput Uncontrolled Controlled CAS # Pollutant Emission Factors Emission Factors Source lb/bbl lb/bbl CO 4.96E-03 4.96E-03 AP-42, Chapter 13.5 V0C 0.7499 3.75E-02 Site-specific 71432 Benzene 3.31E-03 1.66E-04 flash liberation 108883 Toluene 2.20E-03 1.10E-04 analysis taken 1330207 Xylene 5.7E-04 2.85E-05 10/16/2019 &t Tanks 4.0.9d 110543 n-Hexane 2.556E-02 1.278E-03 Simulation Note: The controlled emissions factors for this point are based on a control efficiency of 95%. Process 02: Combustion of pilot light gas . Uncontrolled Controlled CAS # Pollutant Emission Factors Emission Factors Source lb/MMSCF Ib/MMSCF CO 481.12 481.12 AP-42, Chapter 13.5 Note:The CO emission factors listed in the table above was obtained by multiplying the AP-42 Chapter 13.5 CO emission factor(0.31 lb/MMBtu) by a heat value of 1,552 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the total fuel flow of the pilot gas. Pilot light fuel flow is based on a constant rate of 50 scf/hr. There are a total of two combustors used to control emissions from the crude oil storage vessels. As a result, the total pilot gas fuel flow is 100 scf/hr. Monthly pilot gas throughput shall be determined by multiplying this hourly pilot gas throughput by the enclosed combustor monthly hours of operation. 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 must 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. Page 8 of 9 COLORADO -44161" Department Pollution Control Division Department of Public Heath b Environment Dedicated to protecting and improving the health and environment of the people of Colorado 8) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, n-hexane PSD True Minor Source NANSR Synthetic Minor Source of: VOC 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://www.ecfr.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A - Subpart UUUU 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 Page 9 of 9 C ,,-r•:.�.- COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado CONSTRUCTION PERMIT Permit number: 20WE0132 Issuance: 1 Date issued: Issued to: HighPoint Operating Corporation Facility Name: Anschutz Coffelt 5-61-35_36 NWNW Production Facility Plant AIRS ID: 123/9D9A Physical Location: NWNW SEC 35 T5N R61W County: Weld County General Description: Well Production Facility Equipment or activity subject to this permit: Equipment AIRS Equipment Description Emissions Control ID Point Description Crude Oil 009 Truck loadout of crude oil by Enclosed Combustion Loading submerged fill Device 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 (Division) no later than fifteen days after commencement of operation under this permit by submitting a Notice of Startup (NOS)form to the Division. The Notice of Startup (NOS) form may be downloaded online at https://www.colorado.gov/pacific/cdphe/air/manage-permit. Failure to notify the Division of startup of the permitted source is a violation of AQCC Regulation Number 3, Part B, 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 must 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/cdphe/air- permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) Page 1 of 11 r ;: COLORADO >4.2, Air Pollution Control Division Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado 3. This permit must expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) F.4.) 4. The operator must 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 must not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4) Annual Limits: Equipment ID AIRS Tons per Year Emission Point PM2.5 NO,t VOC CO Type Crude Oil 009 --- --- 2.3 --- Point Loading 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 must not exceed 8.0 tons per year. Facility-wide emissions of total hazardous air pollutants must not exceed 20.0 tons per year. The facility-wide emissions limitation for hazardous air pollutants must apply to all permitted emission units at this facility. Compliance with the annual limits for both criteria and hazardous air pollutants must 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 must 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 owner or operator must use the emission factors found in "Notes to Permit Holder" to calculate emissions and show compliance with the limits. The owner or operator must submit an Air Pollutant Emission Notice (APEN) and receive a modified permit prior to the use of any other method of calculating emissions. 7. The emission points in the table below must 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.) Page 2 of 11 C40 r,Y COLORADO Air Pollution Control Division tUtil Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado Equipment AIRS Control Device Pollutants Controlled ID Point Crude Oil 009 Enclosed Combustion Device VOC and HAP Loading PROCESS LIMITATIONS AND RECORDS 8. This source must be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate must be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, Section II.A.4) Process/Consumption Limits Equipment ID AIRS Process Parameter Annual Limit Point Crude Oil 009 Crude Oil Loaded 777,450 barrels Loading The owner or operator must calculate monthly process rates based on the calendar month. Compliance with the annual throughput limits must 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 must 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. 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. (Regulation Number 1, Section II.A.1. ft 4.) 10. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 11. Hydrocarbon liquids loadout from storage tanks to transport vehicles must be controlled by using (a) submerge fill and (b) a vapor collection and return system and/or air pollution control equipment. Compliance with Section II.C.5. must be achieved in accordance with the following schedule: (Regulation Number 7, Part D, Section II.C.5.a.) • Facilities constructed or modified on or after May 1, 2020, must be in compliance by commencement of operation. • Facilities constructed before May 1, 2020, must be in compliance by May 1, 2021. • Facilities not subject to Sections II.C.5.a.(i)(A) or II.C.5.a.(i)(B) that exceed the hydrocarbon liquids loadout to transport vehicles throughput of greater than or equal to Page 3 of 11 '"Cr•:�: COLORADO Air Pollution Control Division Department of Public Health Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado 5,000 barrels per year on a rolling 12-month basis must control emissions from loadout upon exceeding the loadout threshold. 12. Storage tanks must operate without venting at all times during loadout. (Regulation Number 7, Part D, Section II.C.5.a.(ii)) 13. The owner or operator must, as applicable (Regulation Number 7, Part D, Section II.C.5.a.(iii)): • Install and operate the vapor collection and return equipment to collect vapors during the loadout of hydrocarbon liquids to tank compartments of outbound transport vehicles and to route the vapors to the storage tank or air pollution control equipment. • Include devices to prevent the release of vapor from vapor recovery hoses not in use. • Use operating procedures to ensure that hydrocarbon liquids cannot be transferred to transport vehicles unless the vapor collection and return system is in use. • Operate all recovery and disposal equipment at a back-pressure less than the pressure relief valve setting of transport vehicles. • The owner or operator must inspect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or vapor loss during loadout. These inspections must occur at least monthly, unless loadout occurs less frequently, then as often as loadout is occurring. 14. The owner or operator must perform the following observations and training (Regulation Number 7, Part D, Section II.C.5.a.(iv)): • The owner or operator must observe loadout to confirm that all storage tanks operate without venting when loadout operations are active. These inspections must occur at least monthly, unless loadout occurs less frequently, then as often as loadout is occurring, • If observation of loadout is not feasible, the owner or operator must document the annual loadout frequency and the reason why observation is not feasible and inspect the facility within 24 hours after loadout to confirm that all storage tank thief hatches (or other access point to the tank) are closed and latched. • The owner or operator must install signage at or near the loadout control system that indicates which loadout control method(s) is used and the appropriate and necessary operating procedures for that system. • The owner or operator must develop and implement an annual training program for employees and/or third parties conducting loadout activities subject to Section II.C.5. that includes, at a minimum, operating procedures for each type of loadout control system. 15. The owner or operator must retain the records required by Regulation Number 7, Part D, Section II.C.5.a.(v) for at least two (2) years and make such records available to the Division upon request. Page 4 of 11 Cr�- COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado • Records of the annual facility hydrocarbon liquids loadout to transport vehicles throughput. • Inspections, including a description of any problems found and their resolution, required under Sections II.C.5.a.(iii) and II.C.5.a.(iv) must be documented in a log. • Records of the infeasibility of observation of loadout. • Records of the frequency of loadout. • Records of the annual training program, including the date and names of persons trained. 16. Air pollution control equipment used to comply with this Section II.C.5. must comply with Section II.B., be inspected in accordance with Sections II.C.1.d.(ii) through (v), and achieve a hydrocarbon control efficiency of 95%. (Regulation Number 7, Part D, Section II.C.5.a.(vi)) 17. On or before June 30th, 2021 (and on June 30th each year thereafter), the owner or operator of oil and natural gas operations and equipment at or upstream of a natural gas processing plant in Colorado must submit a single annual report that includes actual emissions and specified information in the Division-approved report format. The information included in the annual report must be in accordance with the general reporting requirements of Regulation Number 7, Part D, Section V.B. Beginning July 1, 2020, and each calendar year thereafter, owners or operators must maintain the information according to Regulation Number 7, Part D, Section V.C. for inclusion in the annual report. (Regulation Number 7, Part D, Section V) OPERATING Ft MAINTENANCE REQUIREMENTS 18. Upon startup of these points, the owner or operator must follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 19. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements 20. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. Page 5 of 11 C41 rYz COLORADO i� Air Pollution Control Division ite Department of Public Health Fr Environment Dedicated to protecting and improving the health and environment of the people of Colorado ADDITIONAL REQUIREMENTS 21. A revised Air Pollutant Emission Notice (APEN) must be filed: (Regulation Number 3, Part A, Section 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,t 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 • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 22. Federal regulatory program requirements (i.e. PSD, NANSR) must apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source must not exceed the Federal program threshold until a permit is granted. (Regulation Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS 23. 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. Page 6 of 11 rC , y.. COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado 24. 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. 25. 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. 26. 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. 27. 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 must constitute a rejection of the entire permit and upon such occurrence, this permit must 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. 28. 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. 29. 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: Lauraleigh Lakocy Permit Engineer Page 7 of 11 Crt. COLORADO C0 Air Pollution Control Division Department of Public Health Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado Permit History Issuance Date Description Issuance 1 This Issuance Issued to HighPoint Operating Corporation Page 8 of 11 COLORADO Air Pollution Control Division Department of Public Health b c Environment Dedicated to protecting and improving the health and environment of the people of Colorado Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder must 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 must 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 Uncontrolled Controlled Point Pollutant CAS # Emissions Emissions (lb/yr) (lb/yr) Benzene 71432 410 21 009 Toluene 108883 272 14 n-Hexane 110543 3,166 158 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. Page 9 of 11 C COLORADO Air Pollution Control Division Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado 5) The emission levels contained in this permit are based on the following emission factors: Uncontrolled Controlled Pollutant CAS # Emission Emission Source Factors Factors lb/bbl lb/bbl VOC 0.1194 5.97E-03 AP-42, Chapter Benzene 71432 0.00053 2.65E-05 5.2, Equation 1 Toluene 108883 0.00035 1.75E-05 Et site specific n-Hexane 110543 0.00407 2.035E-04 sampling taken 10/16/2019 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) = 2.824 psia M (vapor molecular weight) = 69 lb/lb-mol T (temperature of liquid loaded) = 512 °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. 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 must be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, n-hexane PSD True Minor Source Page 10 of 11 COLORADO 410 WI. Air Pollution Control Division Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado NANSR Synthetic Minor Source of: VOC 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://www.ecfr.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A - Subpart UUUU 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 Page 11 of 11 Colorado Air Permitting Project PRELIMINARY ANALYSIS-PROJECT SUMMARY Project Details For Division Use Only Review Engineer: Lauraieigh a.kcy Package 6: 422933 Received Date: 1211/2019 Review Start Date: 15/13/2020 Section 01-Facility Information Company Name: HighPoint Operating Corporation Quadrant Section Township Range County AIRS ID: 123 NWivi'.' 5N 5_ Plant AIRS ID: 9096 r` Facility Name: Anschutz.Caf`_it 5-61-35_36 NWNW Production Facility Physical Address/Location: ,,4a. County: Weld County Type of Facility: Explora;en&Production Well Pad - ;tell, What industry segment?Oil&Natural Gas Produ-.;on&Processing ra .' trei'. Is this facility located in a NAAQS non-attainment area? Yes If yes,for what pollutant? Ozone(NOx&VOO) Section 02-Emissions Units In Permit Application Leave Blank-For Division Use Only AIRs Point if Permit# Emissions (Leave blank unless Issuance Self Cert Engineering (Leave blank unless APCD Emissions Source Type Equipment Name Action Control? APCD has already # Required? Remarks has already assigned) assigned) Permit Initial 008 Storage Tank. Yes 20WE0131 _ Yes Issuance Permit initial 009 Liquid Loading Yes 20WE0132 1 Yes Issuance: Section 03-Description of Project This source is requesting permit coverage from a multi-well production facility located in the ozone nonattainment area.This facility has added seven(7)new wells in addition to their existing well.The new wells began operation on'Septembei 12,2019.This facility has requested that all welipads producing to this facility be aggregated for the oarcoses of NNSR determination as a single stationary source.The source has requested permit coverage for the;rude oil storage tanks and crude oil loadoui,in addition to the produced water storage tank through OPUS coverage.This source is a synthetic minor facility with respect to VOC and n-hexane. Sections 04,05&06-For Division Use Only Section 04-Public Comment Requirements Is Public Comment Required? Yes If yes,why? Requesting,Synthetic Minor Permit Section 05-Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? Na 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? - No Is this stationary source a synthetic minor? Yes If yes,indicate programs and which pollutants: SO2 NOx- CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration(P50) ❑ ❑ ❑ ❑ O ❑ Title V Operating Permits(OP) 0001210 000 Non-Attainment New Source Review(NANSR) ❑ Is this stationary source a major source? No If yes,indicate programs and which pollutants: SO2 NOx CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration(PSD) ❑ 000 ❑ ❑ Title V Operating Permits(OP) ❑ ❑ ❑ ❑ O 000 Non-Attainment New Source Review(NANSR) ❑ ❑ Storage Tank(s)Emissions Inventory Section 01-Administrative Information 123 0093. 008 Facility AIRS ID: County Plant Paint Section 02-Equipment Description Details Storage Tank Liquid la 'LEy; Detailed Emissions Unit " � �z K�,x az Description f v"f.. ...r �� , . Otte rs 7.�:,. ... "P Emission Control Device Enclosed Combustion 1cu (Cimarron Big Hurt) Description: Requested Overall VOC&HAP Control Efficiency%: 35.0 Limited Process Parameter a "x Section 03-Processing Rate Information far Emissions Estimates Primary Emissions-Storage Tank(s) Actual Throughput= 547,875.0 Barrels(bbl)per year 'Requested Permit Limit Throughput= 777,490.0 Barrels(bbl)per year Requested Monthly Throughput= 5„22___ Barrels(hbl)per month Potential to Emit(PTE)Condensate Throughput= 777,410.0 Barrels(hbl)per year Secondary Emissions-Combustion Device(4 Heat content of waste gas= 3199.E Btu/scf Volume of waste gas emitted per BBL of liquids Includes flash GOR and working/breathing GOR produced= 7.0 scf/bbl Actual heat content of waste gas routed to combustion device= 10,840.7 MMBTU per year Requested heat content of waste gas routed to combustion device= ">303.3 MMBTU per year Potential to Emit(PTE)heat content of waste gas routed to combustion device= 13.008 8 MMBTU per year Control Device Pilot Fuel Use Rate: . 1100 scfh 0.4 MMscf/yr Pilot Fuel Gas Heating Value: .^:: :1552.Btu/scf -..3.0.MMBTU/yr Section 04-Emissions Factors&Methodologies S1"o Will this storage tank emit flash emissions? a ..or l2 Emission Factors Crude Oil Tank Uncontrolled Contnolled Pollutant (lb/bbl) (lb/bbl) Emission Factor Source (Crude Oil (Crude Oil Throughput) Throughput) Benzene ...,'s, l 5Q. - Taluene _j' - a §; Ethylbenzene I 5883 r t Xylene ..UOle a5 n-Hexane n ,, - n `�::: ,. ._ k- 224 TMP .v__„ -j, _ _ a Pn , V H.-_ , Control Device Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (Ib/bbl) Emission Factor Source (waste heat (Crude Oil combusted) Throughput) PM10 33075 (.._ PM2.5 1 �a`- SOx .6.03'3, A 'a NOx CO 33540 3-ii _ c R, Pilot Light Emissions Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) )lb/MMscf) Emission Factor Source (Pilot Gas Heat (Pilot Gas Combusted) Throughput) PM10 1 8075 PM2.5 1:07; AP 12'35 14.0)001 s 25) ,." SO> r J6 NOx _ l _ illigVOC _,. - ASR}tk,g Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month) PM10 5.1 3.C 3.3 3 5 3 9.1. PM2.5 0.0 1._ 3 3 0 13333 3.1 500 n.0 0.3 C 7 2 3 --.. p 7 NOx 1.5 0,4 3.8 _.5 5 3 33:9 VOC 2913:5 7x73 235 S 12 2475.4 CO 'el 1E. 2-.1 2.2 378.3 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ibs/year) (lbs/year) (Ibs/year) (Ibs/year) (Ibs/year) Benzene 2573-4 2154.5 _372 2378.4 Toluene 17.10.4 1325.3 .s.3 175.3A 85.5 Ethylbenzene ?2.5.0 157.5 3.4 2%3-.5 • 2 of 13 C:\Users\llakocy\Desktop\Remote Working Docs\Package 422938\20WE0131.CP1 Storage Tank(s)Emissions inventors, xylene 443.1 3799.3 13.5 22.2 n-Hexane 1.9871.9: 1559 7 879.1 15371'o 993 E 224TMP 7.8 €.5 03 '/1 13.7 • • 3 of 13 C:\Users\Ilakocy\Desktop\Remote Working Docs\Package 422938\20WE0131.CP1 Storage'Tank(s)EICI ss'ons Inventory Section 06-Regulatory Summary Analysis Regulation 3,Parts A,B ,.. Regulation 7,Part D,Section I.C,0,E,F Regulation 7,Part D,Section I.G,C Regulation 7,Part D,Section 11.0,C.1,C.3 Regulation 7,Part D,Section II.C.2 Regulation 7,Part D,Section II.C,4.a.(i) Regulation 7,Part D,Section II.C.4.a.(ii) Regulation 6,Part A,NSPS Subpart Kb Regulation 6,Part A,NSPS Subpart 0000 Stcr.,ge'a, not subject to 1-55PS Cl:' NSPS Subpart 0000a Storage tank c net subject t€.I S±'s 01 Regulation 8,Part E,MACE Subpart HH Storage lv,'k"s not subject is MACS'Fl (See regulatory applicability worksheet for detailed analysis) Section 07-Initial and Periodic Sampling and Testing Requirements For condensate or crude oil tanks,does the company use the state default emissions factors to estimate emissions? If yes,are the uncontrolled actual or requested emissions for a crude oil tank estimated to be greater than or equal to 20 tons VOC per year OR are the uncontrolled actual or requested emissions fare condensate storage tank estimated to be greater than or equal to 80 tpy? ,mss If yes,the permit will contain an"Initial Compliance"testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03. 's Sf 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 74 permitted(for produced water tanks,a pressurize liquid sample must be analyzed using flash liberation analysis)?This sample should be considered representative which generally means site-specific and collected within one year of the application received date.However,if the facility has not been modified(e.g.,no new wells brought on-line),then it maybe appropriate to use an .s older site-specific sample, If no,the permit will contain en"Initial Compiance"testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03. Does the company request a control device efficiency greater than 95%for a flare or combustion device? If yes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02 Section 08-Technical Analysis Notes This facility produces from wells at 3-COGCC sites(458008,456779,439471)-see the APEN for point 007 for the list of wells that produce to this facility.The source has claimed that while these well pads are separate wellpad facilities per COGCC,they are requesting that for the purposes of air emissions and SIR determination,that these be considered a single stationary source.Emissions from all of these well pads will be considered under this production facility.Because of this being an aggregated facility,it has been determined the custody transfer has not occured for the purposes of the NSPS Kb determination and these tanks do meet the'pre-custody transfer'exemption per NSPS Kb.Email documentation for this single stationary source request will be maintained in division records. Section 09-SCC Coding and Emissions Factors(For Inventory Use Onlvl Uncontrolled Emissions AIRS Point# Process SCC Code Pollutant Factor Control% Units 008 01 t} r ...f{,�' a ny PM10 0.1') lb/1,000 gallons Crude Oil throughput PM2.5 O.:i _ lb/1,000 gallons Crude Oil throughput SOx m -a lb/1,000 gallons Crude Oil throughput NOx -v,. :2 lb/1,000 gallons Crude Oil throughput VOC 95 lb/1,000 gallons Crude Oil throughput CO 3,1i 4 16/1,000 gallons Crude Oil throughput Benzene 05 16/1,000 gallons Crude Oil throughput Toluene O.'S 9, lb/1,000 gallons Crude Oil throughput Ethylbenzene 3._^-t 5 lb/1,000 gallons Crude Oil throughput Xylene 3_ 16/1,000 gallons Crude Oil throughput n-Hexane I C l 85 lb/1,000 gallons Crude Oil throughput 224 TMP Il v0 90 lb/1,000 gallons Crude Oil throughput 4 of 13 C:\Users\Ilakocy\Desktop\Remote Working Docs\Package 422938\20W E0131.CP1 Source: Flashed Gas from site-specific pressurized oil sample taken 10/16/2019 Tanks 4.0.9d simulation using Gasoline RVP 6 Compound Weight Fraction Emission Factor(lb %of VOC Total (W/B/Flash) Oxygen/Argon 3.502 0.030700 Nitrogen 15.77890 0.138324 CO2 0.332000000 0.002910 CH4 0.19700 0.001727 Ethane 2.6171 0.022943 Propane 18.5270 0.162415 lsobutane 5.3944 0.047289 6.954 Butane 22.9451 0.201146 29.579 Isopentane 7.57860 0.066437 9.770 Pentane 9.7971 0.085885 12.630 Cyclopentane 0.848000 0.007434 1.093 n-Hexane 2.64440 0.023182 2.740 0.025075 Cyclohexane 0.60180 0.005276 0.776 Methylcyclohexane 5.29180 0.046390 6.822 Heptane 1.842200 0.016149 2.375 2,2,4-Trimethylpentane 0.0012000 0.000011 0.002 0.000012 Benzene 0.342700 0.003004 0.442 0.003310 Toluene 0.227400 0.001993 0.293 0.002196 Ethylbenzene 0.0302000 0.000265 0.039 0.000292 m-xylene 0.059200 0.000519 0.076 0.000572 Octane 0.70150 0.006150 0.904 Nonane 0.120700 0.001058 0.156 Decanes+ 0.619600 0.005432 0.799 VOC°s 77.5729 0.680035 0.749 Hours/Year 8760 VOC w/b (lb/bbl) 0.069098051 Gas Water Ratio 6.9 Gas Molar Volume @ 60 F, ' 379 Gas Molecular Weight 48.1517 Storage Tank Regulatory Analysis Worksheet The regulatory requirements below are determined based on requested emissions. Colorado Regulation 3 Parts A and B-APEN and Permit Requirements - r::ircr,ain_.th:n.o.LtpS-ner=t.[tta ATTAINMENT 1. Are uncontrolled actual emission from any criteria pollutants from this Individual source greater than 2TPY(Regulation 3,Part A,Section ll.D.l.al? Source Requires an APEN.Go to 2. Isthe constructiondate prior to4/14/2019 d not modifiedaft 4/14/14 with a storage tank throughput less than 4q W0 gallons per year(SeePS Memo 14-03 for additional guidance on grandfather applicability)? so no next question 3. Aretotal facility uncontrolled VOC emissions greater than 5TPV NOx g t than 10 TPY or CO emissions greater than 10 TPY(Regulation 3,Part e,Section 1lD31? Source Requires a permit NON-ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 11PY(Regulation 3,Part A,Section 11.015)7 - 1`es:.z.,`a`Source Requres an APEN.Go to 2. Is the construction date prior to 4/14/2014 and not modified after 4/14/14 with astorage tank throughput less than 40,000 gallons per year(SeePS Memo 14-03 for additional guidance on grandfather applicabi131,1? to next question 3. Are total facility uncontrolled VOC emissions greater than 2TPY,NOx greater than Si??or CO emissions greater than 10TPY(Regulation 3,Parts,Section 11.0.2)? Ys-,.,,= Source Requires apermit Colorado Regulation 7,Part D.Section I.C-F&G 1. Is this storage tank located in the 8-hr ozone control area orany ozone non-attainment area or attalnment/maintenance area(Regulation 7,Parts,Section 1.0.117 Continue-You have indicated di 2. Is this storage tank located at oil and gas operations that collect,store,or handle hydrocarbon liquids or produced water AND that are located ater upstream of a natural gas processing plant(Regulation 7,Part D,Section lA.1)7 Yr, Continue-You have indicated th 3. Is this storage tank Issued at a natural gas processing plant(Regulation 7,Part 0,Section 1.0)? Storage Tank is not subject to Re 4. Dom this storage tank contain condensate? rt... 5. Does this storage tank exhibit"Flash"leg.storing non-stabilized liquids)emissions(Regulation 7,part D,Section I.G.2)? 6 Are uncontrolled actual emiss[ons of this storage tank equal to or greater than 2 tons per year VOC(Regulation 7,Part D,Section l.D.3.a(Il)l7 yns ii, Part 0,Section l.C.1—General Requiremern for Air Pollution Control Equipment—Prevention of leakage Part s,Section I.C.2—Emission Estimation Procedures Part 0,Section 1.0—Emissions Control Requirements Part 0,Section 1.E—Monitoring Part 0,Section 1.1—Recordkeeping and Reporting Part D,sectionlG2 Emissions C of Requirements • Part D,Section l.C.l.a andb—General Requirements for Air Pollution Control Equipment—Prevention of Leakage Colorado Regulation 7,Part D,Section II 1. Isthis storage tank located at a transmission/storage facility? ii. Continue-You have Indicated th 2. Is this storage tanks located at an oil and gas exploration and production operation,well production facility',natural gas compressor station'or natural gas processing plant'(Regulation 7,Part 0,Section ll.C)?. Go to the next question-You ha 3. Doesthis storage tank havea fixed roof(Regulation 7,Part O.Section ll.A.20)7 Go to the next question 4. Are uncontrolled actual emvslgm of this storage tank equal to or greater than Atone per year VOC(Regulation 7,Part 0,Section ll.C.l.c)7 Source Is subject to parts of Reg, Part 0,Sec5on II.B—General Provisions for Air Pollution Control Equipment and Prevention of Emissions Part e,Section ll.C.1-Emissions Control and Monitoring Prwvions Part O,Section II.C.3-Recordkeeping Requirements 5. Does the storage tank contain only"stabilized"liquids(Regulation],Part 0,Sectionll.C.2.b)? 1 Source is subject.all Provision, Part 0,Section ll.c.2-Capture and Monitoring for Storage Tanks fitted with Alr Pollution Control Equipment Is the controlled storage tank located at a well production faulty,natural gas compressor statIon or natural gas processing plant constructed on car after May 1,2020 or located at a facility that was modified on or after May 1,2020,such 6. that an additional controlled storage vessels constructed to receive an anticipated increase ln throughput of hydrocarbon liquids or produced water(Regulation 7,Part o,Section ll.C.4.a.(i)? Storage Tanks not subject to Re lsthe controlled storage tanklocated at a wellpod facility,naturalgas compressor station,or natural gas processing plant constructed°nor after Januarys,2021 or located at a facility that was modified on or after January 1, - 7. 2021,such that n addaonal controlled storage vessel is constructed to receive an anticipatedincrease in throughput of hydrocarbon liquids or produced water IReevIatiss 7,Part 0,Section llC.4a.()? 40 CFR,Part 60.Subpart Kb,Standards of Performance for Volatile Organic Liquid Storage Vessels 1, Is the Individual storage vessel capacity greaterthan or equal to75 cubic meters(.')1-472 RBIs)(40 CFR 60.110b(a)l7 ,:.Go to the next question 2. Does the storage vessel meet the following exemption in 60.111b(d)(4)7 Storage Tank is not subject NSPS a.Does the vessel has a design capacity less than or equal to 1,589.874 m°[-10,000 BBL)used for petroleum'or condensate stored,processed,or treated prior to custody transfer'as defined In 60.1115? 3. Was this storage vessel constructed,reconstructed,or modified(see definitions 40 CFR,60.2)after July 23,1984(40 CPA 60.110b(a))? 4. Does the tank meet the definition of"storage vessel"'In 60.111b? --- 5. Doesthe storage vessel store a"volatile organic liquid(VOLI'sas defined In 60.111b? 6. Does the storage vessel meet thy one of the following additional exemptions: . a.Is the storage vessel a prmthre vessel designed to operate in excess of 204.9 kPa[-29.7 psi]and without emissions tothe atmosphere(60.110b(d)(2))?;or r.. b.The design capacity isgreater than or equal to 151 ma[-950 BBL]and stores a liquid with amaximum true vapor pressures less than 35 kPa(60.110b(b))7;or c.The design capacity isgreater than or equal to 75 M'['472 BBL]but less than 151 ms[-950 Bell and stares a liquid with a maximum true vapor pressure`less than 15.0 kPa(60.110b(b))7 7. Does the storage tank meet either one ofthefollowngexernptons from control requirements: a.The design capacity isgreater than or equal to 1515'[-950 6B2 and stores a liquid with a maximum true vapor pressure greater that or equal to 3.5 kPa but less than 5.2 kPa?;or tl h.The design capacity isgreater thanequal to 75M°[-472 BBL)but lessthan 151 m3(-950 BBL]and stores a liqudwitha maximum true vapor pressure greater than or equal to 15.0 kPa but less than 27.6 kPa7 40 CFR,Part 60,Subpart 0000/0000a,Standards of Performance for Crude Ill and Natural Gas Production,Transmission and Distribution 1. Is this storage vessel located at a facility in thennshore oil and natural gas production segment,natural gas processing segment or natural gas transmission and storage segment of the industry? mes Continue-You have indicated th 2. Was this storage vessel constructed,reconstructed,or modified(see definitions 40 CFR,60.2)between August 23,2011 and September 18,2015? d,JO Go to the question 4. 3. Was this storage vessel constructed,reconstructed,or modified(see definitions 40 CFR,60.2)after September 18,2015? ,,e o. Tank is not subject NSPS 4. A potential Von emissions'from the individual storage vessel ter than ore equal 6tonsI 'Are pore g v egret qua per year7 -1�."Siy Storage Tank&nolsubject NSPS S. Does the storage vessel meet the definition of"storage vessel"'per 605430/605430a? WA 6 Is the storage vessel subject to and controlled in accordance with requirements for storage vessels In 40 CFR Part 60 Subpart Kb or 40 CFR Part 635ubpa5 HH7 °'5. .,' [Note:If a storage vessel is previously determined to be subjectto NSPS 0000/0000e due to emissions above 6 tons per year VOC on the applicability determination date,It should remain subject to NSPS 0000/00000 per 60.5365fel(2)/60.5365a(e)f21 even if potential VOC emissions drop below 6 tans per year] 90 CFR,Part 63,Subpart MALT NH,011 and Gas Production Facilities 1. Isthe storage tank located at an oil and natural gas production facility that meets either of the following criteria: VP, Continue-You have indicated th a.Afacllity thatprocesses,upgrades or stores hydrocarbon liquids'(63.760fa1(2)II OR b.Afacllity 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 k delivered to a final end user'(63.760(a)(3)1? 2 Is the tank located at a facility that is major"for HAPs7 441K1116.Storage Tank is not subject MAC 3. Doesthe tank meet the definition of"storage vesselx°in 63.7617 flrk3' 4. Doesthe tank meet the definition of"storage vessel with the potential for flash emissions'per 63.761? 5. Is the tank subject to control requirements under 40 CFR Pan 60,Subpart Kb or Subpart 00007 f 4 SIn 3 Subpart A,General provisions per 355.764(a)Table 2 §63.766-Emissions Control Standards §63.773-Monitoring §63.774-Recordkeepng §63.775-Reporting RACT Review RACT review is required if Regulation 7 does not apply AND lithe tank Is in the non-attainment area.If the tank meets both criteria,then review PACT 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 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 lees regulation, r 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„ifs implementing regulations end Air Quality Control Commission regulations,the language of the statute orregulaticn will control.The use of non-mandatory language such as"recommend,""may,"°should,"end ten,"is intended fo 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 end Air Quality Control Commission regulations.but this document does not establish legally binding requirements in end of itself. Hydrocarbon Loadout Emissions Inventory Section 01-Administrative Information 'Facility AIRs ID: County Plant Point Section 02-Equipment Description Details Detailed Emissions Unit Crude:O i teadnci Description: Emission Control Device Description: En Clan„a CatObusklort Opt Is this loadout controlled? Requested Overall VOC&HAP Control Efficiency%: 95 Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Hydrocarbon Loadout Actual Volume Loaded= .547,875:Barrels(bbl)per year Requested Permit Limit Throughput= 777,450:Barrels(661)par year Requested Monthly Throughput= 92010 Barrels(bbl)per month Potential to Emit(PTE)Volume Loaded= 777,450 Barrels(bbl)per year Secondary Emissions-Combustion Device(s4 Heat content of waste gas= 2199.78 Btu/scf Actual Volume of waste gas emitted per year= ... scf/year Requested Volume of waste gas emitted per year= scf/year Actual heat content of waste gas routed to combustion device= _-MMBTU per year Requested heat content of waste gas routed to combustion device= MMBTU per year Potential to Emit(PTE)heat content of waste gas routed to combustion device= ..,c2 MMBTU per year Control Device Included•e,ith crude oil tanks mF 3sZO„��sf,.k °a V .. ' tom:, . . , .,mNTIN EEM 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 at the facility being permitted? o -. .. - =speed cam:ssrnns#attar. Loading Loss Equation L=12.46'S'P°MIT Factor Meaning Value Units Source s Saturation Factor '.: �t11- AP-42e(fep=es.zTa₹rlca ° . .. v P True Vapor Pressure 2B?4 psia Tanks 4.0.9d speci. ap for Gasoline MVP 6) M Molecular Weight of Vapors 51, Ib/Ib-mol Tanks 45:90 spec-4 c y^o.fon stencil.m.(PPP 6) Liquid Temperature SI1Z 2 Rankine Tyaks 4 90 n°yrDeco,.CO Loading Losses ':lb/1000 gallons - - lb/bbl Component Mass Fraction Emission Factor Units Source Benzene `0`0-04417774 a(-4 =-Ib/bbl Toluene 4,002931432 " Ib/hhI Ethylbenzene 0,000389311 i- z lb/bbl Xylene ":0 00016315 ? -.-lb/bbl n-Hexane 0.03408918;. 224 TMP 1.54693E 05 a-0&Ih/661 Hydrocarbon Loadout Uncontrolled Controlled Emission Factor source Pollutant (Ib/bbl) (lb/bbl) (Volume Loaded) (Volume Loaded) izersmi =mum Mall,ttf-ginfga2a4vett; Pollutant Uncontrolled Uncontrolled Emission Factor Source (Ib/MMBtu) (lb/h61) (waste heat combusted) (Volume Loaded) =ELM leia*Mrailatr-MOSA54,445 ®' Iteisomingrignigiarirazamiriztasammismismismamosomeito �yt� , s EFEWEISTMEMENEMENNERVICIREWOMElOgleWIREPOSIVASIONIENI WiNSONSSIggigiangilatigairigarie BSI �� nal IMINENISHIEgargINETWIRNRWISSIRA EINNWPOWN S .. ri ,: 8 of 13 C:\Users\Ilakocy\Desktop\Remote Working Dons\Package 422938\20WE0131.CP1 Hydrocarbon Lot do)t Emissions Inventory Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled - Controlled Uncontrolled Controlled Controlled (tens/year) (tons/year) (eons/year) (tons/year) (tons/year) (lbs/month) PM10 _-__ 0.01 5_. 0.02 [11 PM2.5 rDOI 0.01. _ 5Ox 0.00 ,8_ NOx 0.06 0.77 _1 VOC 4;._ 38.70 2 52 20.14392 CO 0.3_ 0.27 C.32 0531 Potential to Emit Actual Emissions 7 Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year) Benzene 415 17 419 Toluene 272 227 11 272 _4 Ethylbenzene 35 35 2 36 Xylene 71 59 571 n-Hexane '__6 ___ _0 3156 1554 224 TMP _ '0 Section 06-Reeulatory Summary Analysis Regulation 3,Parts A,6 -__- ml, Regulation 7 Part D Section 110.5. 1_ .,dro,' ,214,22j,,6960., Regutat ion 7 Pa;.1>5931:on 023.5. (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 initial and periodic compliance testing in accordance with PS Memo 20-02 Section 08-Technical Analysis Notes Source used the flash analysis for the crude oil(sample taken 10/16/2019)to estimate the HAP emissions and the gas heating value.This flash liberation sample id considered acceptable for developing a site-specific emission factor. The volume of the gas flashed was calculated using the following equation:Flash gas(scf/year(=1/00(tpy)x 2,000 lb/ton/VOC wt%/gas MW(Ib/Ibmol)x molar volume The VOC wt%and the gas MW used to calculate this value were from the flashed gas analysis from the crude oil and yielded more conservative emissions estimates. Section 09-SCC Coding and Emissions Factors(For Inventory Use Only) Uncontrolled Emissions AIRS Point# Process# SCC Code Pollutant Factor Control% Units 009 01 2216-71.32 ...3.2.56-2,326 I..60,21.5 303551 359555 552.522 2. PM10 1 lb/1,000 gallons transferred PM2.5 _,. 0 lb/1,000 gallons transferred SOx 0 lb/1,000 gallons transferred NOx .._. 0 lb/1,000 gallons transferred VOC _ 95 lb/1,000 gallons transferred CO :_- 0 lb/1,000 gallons transferred Benzene _, 35 lb/1,000 gallons transferred Toluene =__ 95 lb/1,000 gallons transferred Ethylbenzene 95 lb/1,000 gallons transferred Xylene 35 lb/1,000 gallons transferred n-Hexane C 75 lb/1,000 gallons transferred 224 TMP G =_ lb/1,000 gallons transferred • 9 of13 C:\Users\llakuvy\Desktop\Remote Working Does\Package 422938\20WE0131.CP1 Hydrocarbon W adout Regulatory Analysis Worksheet The regulertaryrequirements below are determined based on requested emissions and throughput Colorado Regulation 3 Parts A and IS APEN a.Permit Requirements I Moms la the Nca-Asvin ATTAINMENT 1. Are uncontrolled actual emissions any criteria pollutz6(tom this lMividuel same greater than 2 T.'(Regulation,Part A,Smtlon ll.O.l.al, z s the loadouc located at an exploration and production site leg.,well pad)(Regulation 3,Part B,Section n.G.1.02 3. is the Iwdoutoperahon loading less than 10,000 gallons(238 BSA of crude oil per daT on an annual average basis? 4. Is Melwdout operation loading less than 6,]50 bbis per year of Emden..via splash RII?. 5. B the lwdout operation loading less than 16,308 hbis per year of condensate via submergM fill procedure? 6. Are total facility uncontrolled MC emissions greater Man 5 TPY,NOx greater than MIT or CO emissions greater than 10 AT(Regulation 3,Part B,Section 11.0.31? I'M :ha rear.,l.,n._..r,.n.A sismontAka NON-ATTAINMENT h 1. uncontrolled emissions from any[Ikeda pollutants from this Individual source greater than l TPY(R t n bon Ol.a)? " ≥M Go to next mAtian. 2. A the re doutiamtedgran eploradon a161642616126 leg well pad)(Regulation 3,Parte,6ecbm ..I.3 keti4.. Go to the next question 3. Is the toadout operation lo.InglesstMn locum gallons 123S Bats'of crude oil per day on an annual average basis. Ga to next question 4. IS the loadout operation loading less 6,]50 bbls per yearofcondensate via splash fill] - 4261,1 Go next 5. Is the loadout operation loading less 6 bblsp co ndensate to N wedsa submerged till pr re? CARRAMG tion 6, Are total facility uncontrolled oIIVOC emissions from the g Pl,greater than 2T NOx greater than 5TPY or CO emissions greater than to TIM(Regulation 3,Porte,Section 11.0.2l? R�s�}�a The lwdou9srequiresa permit Colorado Regulation 7 Part['Section.C5. 1. h this storage tank hydrwarbon liquids Iwdaut located at a well production facility,natural gas compressor station or natural gas processnilpant? MAREMS9Go to nextquestion. 2. Dom the cility have a throughput&hydrocarbon liquids loadoutta transport vehicles greater M wan or equal to 5,000 hamels? r.,subject...dation]Part OSecb"m II.C.5. Seca. -Compliance hedule Section II.C.ga(ii)•Operation without Venting Section .e,(iiil-lwdout Equipment Operation and Maintenance Section S.adivl•Loadout observations and Operator Training Section S.a.(v)-Records Section II e5.a.lvil-Requirement:for Mr Pdlueon control Equipment Disclaimer TN,document assists oprefers with determining applicability of certain requirements at the Clean Air Act,its Impkmenting regulations,and Air quality Control Commission regulations.This document is not Me orregulation,and he analysis it contains may not apply to a particular situation based upon the ir.evidual facts and circumstances.This d amrent does not change or subsf2ufe krany law,regulation,or any other legally binding requirement and Is not legally enforceable In the event ofany cord/let between the language of this dxwmgnf and the laguage a'the Clean Air Act,.its implementing regulations, and Alr Quality Central Commission regulations,the languages the statute or regulation will cootmt Mersa efnm-mandatory language such as"recommend"Prey.""should"and'tan,"is intended to dechbe APCO interpretations and recommendations.Mandatory temunabgy such as'must"and"required'are Intended to describe controlling requirements anderbse tams afore Clean AirAct arxsAir Quality Control Commission regulations.bat this documentd+es rnf establish legally bind g lequfmtnents inbred d itsey COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION FACILITY EMISSION SUMMARY Company Name Bill Barrett Corporation,Inc. County AIRS ID 123 History File Edit Date 7/23/2020 Plant AIRS ID 909A. Ozone Status Non-Attainment • Facility Name 19036 Coffelt 5-61-35 Last Modified By: Lauraleigh Lakocy EMISSIONS-Uncontrolled(tons per year) EMISSIONS With Controls(tons per year) POINT PERMIT Description PM10 PM2.5 HAS SOz NOx VOC Fug CO Total PM10 PM2.5 HA SO2 NOx VOC Fug CO Total REMARKS AIRS ID VOC HAPs VOC HAPs Previous FACILITY TOTAL 0.5 0.5 0.0 0.0 67.9 533.2 0.0 _ 59.2 20.5 0.5 0.5 0.0 7.0 46.4 0.0 15.4 1.7 From June 2015 Previous Permitted Facility total 0.5 0.5 0.0 0.0 67.8 491.2 0.0 58.7 19.5 0.5 0.5 0.0 0.0 6.9 40.5 0.0 14.9 _ 1.7 001 GP02.CN Cummins G8.3 C118 RICE 0.0 0.0 Point inactive in PTS Cancellation request Recd 05/11/15 002 GP02.CN Cummins KTA 19GC RICE 0.4 0.4 Cancellation recd 12/09/2019(removed) 003 15WE1004.CN Condensate Loadout 0.1 0.1 Cancellation recd 12/11/2019(removed) 004 15WE1004.CN VRU Bypass 17.6 _ 0.9 Cancellation teed 10/30/2018(removed) 005 GP08.CN Two(2)Produced Water Storage 1.0 0.1 Cancellation recd 12/11/2019(removed) Vessels Four(4)Condensate Storage Vessels 006 GP08;CN 1.0 0.0 Cancellation recd 12/11/2019(removed) 007 GP08 Produced Water Tank 1840 bbl) 0.1 19.8 0.3 0.3 0.1 5.9 0.3 _ 0.2 Newly requested emission source 008 20WE0131 Crude Oil Tanks t4-840 bbl tanks) 0.5 291.5 2.2 0.0 0.5 14.6 2.2 0.0 Newly requested emission source 009 20WE0132 Crude Oil Loadout 0.1 46.4 0,3 0.0 0.1 2.3 0.3 0.0 Newly requested emission source 0.0 0.0 APEN Exempt/nsignificanl Sources - 0.0 0.0 External Combustion Sources('10 Heat( 0.3 0.3 3.4 0.2 2.9 0,0 0.3 0.3 3.4 0.2 2.9 0.0 From I-orm APCD-102 Received 112111//8 Fugitive Equipment Leaks 0.3 0.0 0.3 0.0 From Form APCD-102 Received 12;11119 VOC: Syn Minor(NANSR and OP) NOx:True Minor(NANSR and OP) FACILITY TOTAL 0.3 0.3 0.0 0.0 4.1 357.9 0.3 5.7 20.5 0.3 0.3 0.0 4.1 23.0 0.3 5.7 1.7 CO: True Minor(PSD and OP) HAPS: Syn Minor n-Hexane Permitted Facility Total 0.0 0.0 0.0 0.0 0.7 357.7 0.0 2.8 19.5 0.0 0.0 0.0 0.0 0.7 22.8 0.0 2.8 1.7 _Excludes units exempt from permits/APENs (A)Change in Permitted Emissions . -0.5 -0.5 0.0 0.0 -6.2 -17.7 0.0 -12.1 Pubcom required based on synthetic minor limits Total VOC Facility Emissions(point and fugitive) 23.3 Facility is eligible for GPO2 because<90 tpy (A)Change in Total Permitted VOC emissions(point and fugitive) • -17.7 Project emissions greater than 25 tpy On December 2019 tab,the Doosan engine which has TBD listed as the AIRS Point was removed as it does not appear that the engine was ever permitted.It was not on the most recently received Form APCD-102. Note 1 Note 2 • • • • • Page 11 of 13 Printed 7/23/2020. COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY-HAPs Company Name Bill Barrett Corporation,Inc. County AIRS ID . 123 Plant AIRS ID 9D9A Facility Name 19036_Coffelt 5-61-35 Emissions-uncontrolled (lbs per year) POINT'PERMIT (Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n-Hexane McOH 224 TMP H2S TOTAL(tpy) 'Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 GP02.CN Cummins G8.3 C118 RICE 0.0 002 GP02.CN Cummins KTA 19GC RICE 552 75 71 43 15 1 5 30 82 7 0.4 003 15WE1004.CN Condensate Loadout 36 24 3 6 196 30 0.1 004 15WE1004.CN VRU Bypass 3935 3453 640 1148 22111 3971 17.6 005 GP08.CN Two(2)Produced Water Storage 1.0 492 1547 Vessels 006 GP08.CN Four(4)Condensate Storage Vessels 879 '158 23 38 626 192 1.0 007 GP08 Produced Water Tank(840 bbl) 380 52 49 29 10 4 21 57 5 0.3 008 20WE0131 Crude Oil Tanks(4-840 bbl tanks) 0.0 009 20WE0132 Crude Oil Loadout 0.0 0.0 APEN Exempt/Insignificant Sources 0.0 External Combustion Sources(10 Heaters) 0.0 Fugitive Equipment Leaks 2 4 2 5 14 TOTAL(tpy) 0.5 0.1 0.1 2.7 1.8 0.3 0.6 12.3 0.1 2.1 0.0 0.0 20.5 l `Total Reportable=all HAPs where uncontrolled emissions>de minimus values Red Text: uncontrolled omissions<do minimus Emissions with controls (lbs per year) POINT'PERMIT 'Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n-Hexane McOH 224 TMP H2S TOTAL(tpy) (Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 GP02.CN Cummins G8.3 C118 RICE 0.0 002 GP02.CN Cummins KTA 19GC RICE 552 75 71 43 15 'I 5 30 82 7 0.4 003 15WE1004.CN Condensate Loadout 36 24 3 6 196 30 0.1 004 15WE1004.CN VRU Bypass 197 173 32 57 1106 199 0.9 005 GP08.CN Two(2)Produced Water Storage 0.1 25 77 Vessels 006 GP08.CN Four(4)Condensate Storage Vessels 44 8 1 2 31 10 0.0 007 GP08 Produced Water Tank(840 bbl) 91 52 49 29 10 4 21 57 5 0.2 008 20WE0131 Crude Oil Tanks(4-840 bbl tanks) 0.0 009 20WE0132 Crude Oil Loadout 0.0 0.0 12 20WE0131.CP1 7/23/2020 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY-HAPs Company Name Bill Barrett Corporation,Inc. County AIRS ID 123 Plant AIRS ID 9D9A Facility Name 19036_Coffelt 5-61-35 APEN Exempt/Insignificant Sources I 0.0 External Combustion Sources(10 Heaters) 0.0 Fugitive Equipment Leaks 2 4 2 5 14 TOTAL(tpy) 0.3 0.1 0.1 0.2 0.1 0.0 0.0 0.7 0.1 0.1 0.0 0.0 1.7 13 20WE0131.CP1 7/23/2020 Crude Oil Storage Tank(s) APEN arcCDPHE Form APCD-210 '2°'s CO .� 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. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for tanks that store crude oil 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. condensate 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.coloradto.pvlgacificicdDhetair-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: E J 3) MRS ID Number: /2 / t.. } / oc Section 1 - Administrative Information Company Name': HighPoint Operating Corporation Site Name: Anschutz Coffelt 5-61-35_36 NWNW Production Facility Site Location Site Location: NWNW, Section 35, T5N, R61W County: Weld NAICS or SIC Code: 1311 Mailing Address: (Include Zip Code) 555 17th St., Suite 3700 Denver, CO 80202 Contact Person: Marsha Sonderfan Phone Number: 303-312-8524 E-Mail Address2: CDPHE_Corr@hpres.com Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on alt documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 422834 ItIV COLORADO 1 APCD 210 Crude 00 Storu e Tfr,k s7. €:3 P,.3,','on o 20':9 1 AV Permit Number: AIRS ID Number: Section 2 - Requested Action NEW permit OR newly-reported emission source Request coverage under traditional construction permit ❑ Request coverage under General Permit GP0& If General Permit coverage is requested, the General Permit registration fee of$312.50 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit(check each box below that applies) ❑ Change in equipment 0 Change company name3 ❑ Change permit limit ❑ Transfer of ownership ❑ 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& Notes: Production facility consists of one(1)existing well and seven(7)new wells. The existing well previously produced to the recently decommissioned Coffelt 5-61-35_36 NWNW Production Facility. 3 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. 4 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-1(14)must be submitted. Section 3 - General Information General description of equipment and purpose: Crude Oil Tank Battery Company equipment Identification No. (optional): For existing sources, operation began on: 03/10/2015 For new or reconstructed sources, the projected start-up date is: 09/12/2019 Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Storage tank(s) located at: Q Exploration Ft Production(EFtP)site 0 Midstream or Downstream (non EEtP)site Will this equipment be operated in any NAAQS nonattainment area? 0 Yes 0 No Are Flash Emissions anticipated from these storage tanks? Yes 0 No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) ❑ Yes ❑✓ No 805 series rules? If so, submit Form APCD-105. Are you requesting≥6 ton/yr VOC emissions(per storage tank), or are uncontrolled actual (] Yes ❑ No emissions≥6 ton/yr(per storage tank)? cocoa.00 Fo; f PCD 21C CrLif`,e O1 S _ Tanks) APE4 3."2,01c, 21 ��, Permit Number: AIRS ID Number: Section 4 - Storage Tank(s) Information Actual Annual Amount Requested Annual Permit Limits (bb(/year) (bbl/year) Crude Oil Throughput: 647,875 777,450 From what year is the actual annual amount? 2019 Average API gravity of sales oil: 36.0 degrees RVP of sales oil: 5.3 Tank design: ❑✓ Fixed roof 0 Internal floating roof ❑External floating roof Storage #of Liquid Manifold Storage Total Volume of Installation Date of Most Date of First Tank ID Vessels in Storage Tank Storage Tank Recent Storage Vessel in Production (bbl) Storage Tank(month/year) (month/year) Crude TKs 4 3360 5/2019 09/2019 Wells Serviced by this Storage Tank or Tank Battery6(E&P Sites Only) API Number Name of Well Newly Reported Well See attached well list(Addendum) 0 - ❑ - ❑ - ❑ 5 Requested values will become permit limitations. Requested limit(s)should consider future growth. 6 The EftP 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 or UTM) 40.360528/-104.184358 Operator Stack Discharge Height Above Temp. Flow Rate Velocity ID No. Ground Level(feet) (°F) (ACFM) (ft/sec) ECD TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑✓ Upward - ❑Downward ❑Upward with obstructing raincap ❑Horizontal 0 Other(describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter(inches): 84 ❑Square/rectangle Interior stack width(inches): Interior stack depth (inches): ❑Other(describe): COLORADO Form APCD 2,- Coil tor_ i a u1-. ,AFr:J Revisiorf 3 2019 3 I Permit Number: AIRS ID Number: Section 6 - Control Device Information O Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor Size: Make/Modet: O Recovery Unit(VRU): Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): % Pollutants Controlled: VOC, HAPs Rating: TBD MMBtu/hr Type: ECD Make/Modet:Cimarron/Big Hurt ❑✓ Combustion Requested Control Efficiency: 95 Device: Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: N/A Waste Gas Heat Content: 2,199.78 Btu/scf Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating: 0.16 MMBtu/hr Description of the closed loop system: ❑ Closed Loop System Pollutants Controlled: ❑ Other: Description: Control Efficiency Requested: Section 7 - Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? -5,5 psig Describe the separation process between the welt and the storage tanks: Crude oil from the 3-phase inlet separators go to the heated flash gas separator(heater treater), then to the vapor recovery tower(VRT), and then to the storage tanks. OLORADo Form :7_ '1G Crodo rStoF3se Tankisl AltE31 Pe. 3 '3,219 4 Permit Number: AIRS ID Number: / I Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. 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): Overall Requested Control Pollutant Description of Control Method(s) Efficiency (%reduction in emissions) VOC ECD 95% NOx CO HAPs ECD 95% Other: From what year is the following reported actual annual emissions data? 201 9 Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor7 Actual Annual Emissions Emission Limit(s)5 Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions8 Emissions Emissions Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year) VOC 0.7499 lb/bbl Eng.Est. 242.92 12.15 291.50 14.58 NOx 0.068 Ib/MMBtu AP-42 0.42 0.49 CO 0.31 Ib/MMBtu AP-42 1.89 2.23 Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions Abstract Chemical Name Service(CAS) Uncontrolled Units Source Uncontrolled Controlled Number Basis (AP•42, Emissions Emissions8 Mfg.,etc.) (pounds/year) (pounds/year) Benzene 71432 0.003 lb/bbl Eng.Est. 2,146 . 107 Toluene 108883 0.002 lb/bbl Eng.Est. 1,424 71 Ethylbenzene 100414 Xylene 1330207 0.0006 lb/bbl Eng.Est. 371 19 n-Hexane 110543 0.0256 lb/bbl Eng.Est. 16,562 828 2,2,4- 540841 Trimethylpentane 5 Requested values will become permit limitations. Requested limit(s)should consider future growth. 7 Attach crude oil 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. 8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. COLORADO Earn APCD 21L) ...,lade OIL Storage Taro(,) AP Er---1 - Revision 3 219 5 1 4 .. Permit Number: AIRS ID Number: 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 GP08, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP08. 1 Signature of Legally Authorized P on (not a vendor or consultant) Date Marsha Sonderfan Senior EHS Specialist Name(print) Title Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance 0✓ 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 $191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https:i/wvrw.colorado.covIcdphe'apcd cLORADO FO . . . ;mot) 210C-ucle ._31 St.O % TR.^ :(N)a.PE.. 3'2(21% 6 1 k,_ .... cDPHE Hydrocarbon Liquid Loading APEN © c ' / 2019 Form APCD-208 CO 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. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. 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(e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks, 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,govlccp_Oetapcd. 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: E[ / 3Z AIRS ID Number: JZ, 19p714/ &C Section 1 - Administrative Information Company Name': HighPoint Operating Corporation Site Name: Anschutz Coffelt 5-61-35_36 NWNW Production Facility Site Location Site Location: NWNW, Section 35, T5N, R61W County: Weld NAICS or SIC Code: 1311 Mailing Address: (Include Zip Code) 555 17th St., Suite 3700 Denver, CO 80202 Contact Person: Marsha Sonderfan Phone Number: 303-312-8524 E-Mail Address': CDPHE_Corr@hpres.com 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 the APCD via e-mail to the address provided. 422935 COLORADO -, A`a'F) ?1;ii I,C.I Lc,acj]1Q ADFii Pc;ic lr; i ?0i9 I1311VK... Permit Number: AIRS ID Number: 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$312.50 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment O Change company name3 ❑ Change permit limit O Transfer of ownership' O Other(describe below) -OR- ❑ APEN submittal for update only(Note 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 Et Notes: Production facility consists of one(1)existing well and seven(7) new wells. The existing well previously produced to the recently decommissioned Coffelt 5-61-35_36 NWNW Production Facility. 3 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. '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: Crude Oil Loading Company equipment Identification No. (optional): For existing sources, operation began on: 03/10/2015 For new or reconstructed sources, the projected start-up date is: 09/12/2019 Will this equipment be operated in any NAAQS nonattainment area? 0 Yes O No Is this equipment located at a stationary source that is considered a Major Source of(HAP) O Yes No emissions? Does this source load gasoline into transport vehicles? ❑. Yes 0 No Is this source located at an oil and gas exploration and production site? 0 Yes O No If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual ❑ Yes 0 No average? Does this source splash fill less than 6750 bbl of condensate per year? O Yes 0 No Does this source submerge fill less than 16308 bbl of condensate per year? O Yes 0 No COLORADO ._ ... 'ln(iy 206 u [ ti Ii�;- ir� ��<i�:j;r at'th, � „lull S'Li.)iC. 2 1 -r,.. . .. .,. , Permit Number: AIRS ID Number: / / Section 4 - Process Equipment Information Product Loaded: O Condensate ❑✓ Crude Oil ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: 777,450 bbl/year Actual Volume Loaded: 647,875 bbl/year This product is loaded from tanks at this facility into: Tank Trucks (e.g. "rail tank cars"or"tank trucks") If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: Average temperature of F 0.6 bulk liquid loading: 52.45 True Vapor Pressure: p Psia®60 'F Molecular weight of �� lb/lb-mol 2.824 displaced vapors: If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: bbl/year Actual Volume Loaded: bbl/year Product Density: lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume: ft3/truckload 5 Requested values will become permit limitations.Requested limit(s)should consider future process growth. co ORnoo F Yr! �4,.. f'i f�i:�v_'"L/ T __'(} )ci !? 1. l AP E1 E„s.J Lu ly 3 � r ..... ...... Permit Number: AIRS ID Number: Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.360528/-104.184358 Discharge Height Above Operator Temp. Flow Rate Velocity Stack ID No. Ground Level ('F) (ACFM) (ft/sec) (feet) ECD TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) Q Upward O Downward 0 Upward with obstructing raincap ❑ Horizontal 0 Other(describe): Indicate the stack opening and size: (check one) ❑Circular Interior stack diameter(inches): 84 ❑Other(describe): 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. ❑ Loading occurs using a vapor balance system: Requested Control Efficiency: Used for control of: VOC,HAPs Rating: TBD MMBtu/hr Type: ECD Make/Model:Cimarron/Big Hurt Combustion Device: Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: N/A `F Waste Gas Heat Content: 2,199.78 Btu/scf Constant Pilot Light: ❑r Yes 0 No Pilot Burner Rating: 0.16 MMBtu/hr Pollutants Controlled: ❑ Other: Description: Requested Control Efficiency: ADCE, 20,13iit,_:,m 'C:;tt Load,ng ADEr 3 2C 9 4 I „, V Permit Number: AIRS ID Number: / / Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. 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): Overall Requested Pollutant Description of Control Method(s) Control Efficiency (%reduction in emissions) PM SO. NOx CO VOC ECD 95% HAPs ECD 95% Other: O Using State Emission Factors(Required for GP07) VOC Benzene n-Hexane ❑Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL ❑Crude 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? 201 9 Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor Actual Annual Emissions Emission Limit(s)5 Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Units (AP-42, Emissions Emissions6 Emissions Emissions Basis Mfg.,etc.) tons/ ear tons/ ear (tons/year) (tons/year) ( Y ) (tons/year) ) PM SOX NO. 0.068 lb/MMBtu AP-42 0.06 0.07 CO 0.31 lb/MMBtu AP-42 0.27 0.32 VOC 0.1194 lb/bbl AP-42 38.68 1.93 46.41 2.32 Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions6 Basis Mfg.,etc.) (pounds/year) (pounds/year) Benzene 71432 0.00053 lb/bbl Eng.Est. 342 17 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n-Hexane 110543 0.00407 lb/bbl Eng.Est. 2637 132 2,2,4- Trimethylpentane 540841 Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. A® caLoRnaa for _ APCD 206 Hp,' s_�icbor �i��14 L��l�ing APEN Revtsi�rs'Z019 5 1 r��. ,. Permit Number: AIRS ID Number: / / 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 General Permit GP07. Signature of Legally Authorized Pe son (not a vendor or consultant) Date Marsha Sonderfan Senior EHS Specialist Name(print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance Ej 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 $191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.cotorado.govicdphelapcd COLORADO 2.):3i .)�l� l Li 'l ,�i lfl '�.. 4 u,_y eSfl L 3' i�i�: 6 1 y "_... Hello