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Home My WebLink About20210201.tiffCOLORADO Department of Public Health ft Environment Weld County - Clerk to the Board 1150 O St PO Box 758 Greeley, CO 80632 January 11, 2021 Dear Sir or Madam: RECEIVED JAN 15 2021 WELD COUNTY COMMISSIONERS On January 12, 2021, the Air Pollution Control Division will begin a 30 -day public notice period for Crestone Peak Resources Operating LLC - Regnier Farms. 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 a 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 wwwr.colorado.gov/cdphe Jared Polis, Governor I Jill Hunsaker Ryan, MPH, Executive Director Pvbr.c Ke>l,eW o f /ao/V-I cc: FLCTp) HMO, PW(3H /�N /ERkt‹) oG (AM) , O l /15/21 2021-0201 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Crestone Peak Resources Operating LLC - Regnier Farms - Weld County Notice Period Begins: January 12, 2021 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Crestone Peak Resources Operating LLC Facility: Regnier Farms Existing synthetic minor oil and gas exploration and production facility SWNE SEC 19 T2N R68W Weld County The proposed project or activity is as follows: Source is lowering permitted emissions to remain synthetic minor in the new serious non -attainment area The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 19WE0334 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Comments may be submitted using the following options: • Use the web form at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. This page also includes guidance for public participation • Send an email to cdphe.commentsapcd@state.co.us • Send comments to our mailing address: Christopher Kester Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 ICOLORADO Department of Public Health Et Environment !COLORADO Air Pollution Control Division Departr000t of Pubtto rfoolthL Er iro nlent Dedicated to protecting and improving the health and environment of the people of Colorado Permit number: Date issued: Issued to: CONSTRUCTION PERMIT 19WE0334 Issuance: 2 J Crestone Peak Resources Operating, LLC Facility Name: Regnier Farms Plant AIRS ID: 123/A037 Physical Location: SWNE SEC 19 T2N R68W County: Weld County Description: Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description TANKS 001 Eight (8) 750 bbl fixed roof condensate storage tanks. Enclosed Combustor PW 002 Two (2) 750 bbl fixed roof produced water storage tanks. Enclosed Combustor LOAD -1 003 Truck loadout of condensate from tanks Enclosed Combustor BUFFER 004 Low-pressure separator emissions during VRU downtime. This point does not include emissions from the downstream Vapor Recovery Tower. Enclosed Combustor 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. Page 1 of 13 COLORADO Air Pollution Control Division I Dep,rtme� * of Pub Etc , f-ie lth v Erwiru mart Dedicated to protecting and improving the health and environment of the people of Colorado REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self -certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air- permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 2. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months 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. ) 3. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 4. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section I I.A.4. ) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO TANKS 001 --- -=- 18.5 3.0 Point PW 002 --- --- 0.4 --- Point LOAD -1 003 --- --- 3.9 --- Point BUFFER 004 --- --- 17.2 2.8 Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Page 2 of 13 COLORADO Air Pollution Control Division Departrre t Of .'_<b;tc Heap!? J Env ro^^:er: Dedicated to protecting and improving the health and environment of the people of Colorado Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 5. 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. 6. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled TANKS 001 Enclosed Combustor VOC and HAP PW 002 Enclosed Combustor VOC and HAP LOAD -1 003 Enclosed Combustor VOC and HAP BUFFER 004 Enclosed Combustor VOC and HAP PROCESS LIMITATIONS AND RECORDS 7. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit TANKS 001 Condensate Throughput 1,277,500 barrels PW 002 Produced Water Throughput 730,000 barrels LOAD -1 003 Condensate Loaded 1,277,500 barrels BUFFER 004 Natural Gas Routed to Combustor 6.3 MMscf Page 3 of 13 COLORADO Air Pollution Control Division Department of PLANK: Health E; Environment Dedicated to protecting and improving the health and environment of the people of Colorado The owner or operator shall monitor monthly process rates based on the calendar month. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 8. Point 004: Upon commencement of operation, the owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from the separator(s) using the flow meter. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 9. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 10. This source is subject to the odor requirements_ of Regulation Number 2. (State only enforceable) 11. Point 003: This source is located in an ozone non -attainment or attainment -maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill and emissions shall ,be controlled by an enclosed combustor. (Reference: Regulation 3, Part B, III.D.2) 12. Point 001: 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. Points 001, 002, 003 Et 004: 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 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. Page 4 of 13 COLORADO Air Pollution Control Division Department o. ?ut?. - Heai;h b Environment Dedicated to protecting and improving the health and environment of the people of Colorado 14. Points 001 Et 002: 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. Points 001 Et 002: 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. Point 003: 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.) a. Facilities constructed or modified on or after May 1, 2020, must be in compliance by commencement of operation. b. Facilities constructed before May 1, 2020, must be in compliance by May 1, 2021. c. 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 5,000 barrels per year on a rolling 12 -month basis must control emissions from loadout upon exceeding the loadout threshold. 17. Point 003: Storage tanks must operate without venting at all times during loadout. (Regulation Number 7, Part D, Section II.C.5.a.(ii)) 18. Point 003: The owner or operator must, as applicable (Regulation Number 7, Part D, Section II.C.5.a.(iii)): a. 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. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Use operating procedures to ensure that hydrocarbon liquids cannot be transferred to transport vehicles unless the vapor collection and return system is in use. d. Operate all recovery and disposal equipment at a back -pressure less than the pressure relief valve setting of transport vehicles. e. 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 Page 5 of 13 COLORADO Air Pollution Control Division DepartrretAt Est Pubttc Efeaith Environment Dedicated to protecting and improving the health and environment of the people of Colorado vapor loss during loadout. These inspections must occur at least monthly, unless loadout occurs less frequently, then as often as loadout is occurring. 19. Point 003: The owner or operator must perform the following observations and training (Regulation Number 7, Part D, Section II.C.5.a.(iv)): a. 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, b. 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. c. 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. d. 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. 20. Point 003: 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. a. Records of the annual facility hydrocarbon liquids loadout to transport vehicles throughput. b. 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. c. Records of the infeasibility of observation of loadout. d. Records of the frequency of loadout. e. Records of the annual training program, including the date and names of persons trained. 21. Point 003: 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 hydrocarboncontrol efficiency of 95%. (Regulation Number 7, Part D, Section II.C.5.a.(vi)) 22. Point 004: The separator covered by this permit is subject to Regulation 7, Part D, Section II.F. On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the commencement of operation by air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If Page 6 of 13 COLORADO Air Pollution Control Division I Depaitmew HeathErwirelmerit Dedicated to protecting and improving the health and environment of the people of Colorado a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. 23. 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 24. Points 001 - 004: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEtM) plan and record keepingformat approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 25. This source is not required to conduct initial testing, ,unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements 26. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal'; requirement. ADDITIONAL REQUIREMENTS 27. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOx) in ozone nonattainment areas emitting less than 100 tons of VOC or NOx per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or Page 7 of 13 COLORADO Air Pollution Control Division 4 Department t Pubitc Hinititin £s Environment Dedicated to protecting and improving the health and environment of the people of Colorado For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. GENERAL TERMS AND CONDITIONS 28. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II. B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 29. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 30. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operators agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 31. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 32. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a Page 8 of 13 COLORADO Air Pollution Control Division DkTartmer r .'.+bht y _ rzh q Environnlent Dedicated to protecting and improving the health and environment of the people of Colorado permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 33. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 34. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Christopher Kester Permit Engineer Permit History Issuance Date Description Issuance 1 September 9, 2019 Issued to Crestone Peak Resources Operating, LLC Issuance 2 This Issuance Issued to Crestone Peak Resources Operating, LLC Updated points 001-004 to reflect new process limits and emission factors Point 005 removed from permit Page 9 of 13 COLORADO Air Pollution Control Division Department of Pubiic Health E; 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 shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II. E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/agcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (Ib/yr) 001 Benzene 71432 1,165 58 Toluene 108883 1,129 56 Xylenes 1330207 381 19 n -Hexane 110543 11,284 564 002 Benzene 71432 315 16 Toluene 108883 257 13 n -Hexane 110543 609 30 003 n -Hexane 110543 2,350 117 004 Benzene 71432 1,813 91 Toluene 108883 1,566 78 Xylenes 1330207 435 22 n -Hexane 110543 19,068 953 Note: All non -criteria reportable po lutants 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 10 of 13 COLORADO Air Pollution Control Division Depal trr erA of .bac Health Et Fr it mien: 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 001: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 0.068 (lb/MMBtu) 0.068 (lb/MMBtu) AP -42 CO 0.31 (lb/MMBtu) 0.31 (lb/MMBtu) AP -42 VOC 0.5793 0.028965 Promax 71432 Benzene 0.000912 0.000046 Promax 108883 Toluene 0.000884 0.000044 Promax 1330207 Xylene 0.000298 0.000015 Promax 110543 n -Hexane 0.00883 0.000442 Promax Note: The controlled emissions factors for this point are based on a control efficiency of 95%. Point 002: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 0.068 (lb/,MMBtu) 0.068 (lb/MMBtu) AP -42 CO 0.31 (lb/MMBtu) 0.31 (lb/MMBtu) AP -42 VOC 0.0182 0.0009 Flash liberation 71432 Benzene 0.000432 0.000022 Flash liberation 108883 Toluene 0.000353 0.000018 Flash liberation 110543 n -Hexane 0.000834 0.000042 Flash liberation Note: The controlled emissions factors for this point are based on a control efficiency of 95%. Point 003: CAS #_, Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 0.068 (lb/MMBtu) 0.068 (lb/MMBtu) AP -42 CO 0.31 (lb/MMBtu) 0.31 (lb/MMBtu) AP -42 VOC 0.1206 0.00603 AP -42 110543 n -Hexane 0.00184 0.000092 AP -42 Note: The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46*S*P*M/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 4.0 psia M (vapor molecular weight) = 50.34 lb/lb-mot T (temperature of liquid loaded) = 524.15°R Page 11 of 13 COLORADO Air Pollution Control Division Department of Pub]K: Neait''n b En ironn!rt Dedicated to protecting and improving the health and environment of the people of Colorado 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 V0C emission factor. The controlled emissions factors for this point are based on a control efficiency of 95%. Point 004: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Controlled Emission Factors lb/MMscf Source N0x 0.068 (lb/MMBtu) 0.068 (lb/MMBtu) AP -42 CO 0.31 (lb/MMBtu) 0.31 (lb/MMBtu) AP -42 V0C 108,835.15 5441.76 Gas Analysis 71432 Benzene 287.77 14.39 Gas Analysis 108883 Toluene 248.53 12.43 Gas Analysis 1330207 Xylene 69.03 3.45 Gas Analysis 110543 n -Hexane 3,026.66 151.33 Gas Analysis Note: The controlled emissions factors for this point are based on a control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: V0C and HAP NANSR Synthetic Minor Source of: V0C 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Page 12 of 13 COLORADO Air Pollution Control Division Department of F ubitc Heait = & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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 X 0000( Page 13 of 13 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Package #: Received Date: Review Start Date: For Division Use Only Christopher Kester 433352 1.213/2020 1/4/2020 e Section 01- Facility Information Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Location: County: Type of Facility: ';Exploration & Production: `x.+eFl Pad What industry segment? ':O€1 & Natural Gas Production &Processing Is this facility located in a NAAQS non -attainment area? If yes, for what pollutant? -Crestone Peak Resource 123 A037 r Farms 19H-6266 Weld County ng LLC Section 02 - Emissions Units In Permit Application Yes Ozone (Nag & VOQ:. Quadrant Section Township Range SWNE 18 2N 62 Leave Blank- For Division Use Orly AIRS Point # (Leave blank unless APCD has already assigned) Emissions Source Type Equipment Name Emissions Control? Permit # (Leave blank unless APCD has already assigned) Issuance it Self Cer[ Required? Action Engineering Remarks 001 - Storage Tank TANKS Yes 19WE0334 2 yes Permit initial Issuance 002 Produced Water Tan PW - Yes 19WE0334 2 Yes Permit Cnitial Issuance .,. 003 Liquid Loading ._. - LOAD -1 Yes JE0334 2 - yes Permit initial issuance 001 Separator Venting BUFFER' Yes 1SWE0334 2 - - yes - Permit Initial Issuance Section 03 - Description of Project Revising process 7 ..ts. and emission factors to rernainsythetic minor in new non -attainment area Sections 04, 05 & 06 - For Division Use Only Section 04 - Public Comment Requirements Is Public Comment Required? Yes If yes, why? Requesting Synthetic Minot Permit Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? No If yes, for what pollutants? y , If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification — Is this stationary sources true minor? No . Is this stationary source a synthetic minor? Yes ,! If yes, indicate programs and which pollutants: SO2 NOx CO VOC Prevention of Significant Deterioration (PSD) ❑ ❑ ❑ ❑ Title V Operating Permits (OP) ❑ ❑ ❑ ® Non -Attainment New Source Review (NANSR) ❑ lil Is this stationary source a major source? No _ If yes, indicate programs and which pollutants: SO2 NOx CO VOC Prevention of Significant Deterioration (PSD) ❑ ❑ ❑ ❑ Title V Operating Permits (OP) ❑ ❑ ❑ ❑ Non -Attainment New Source Review (NANSR) 0 0 PM2.5 ❑ ❑ PM2.5 ❑ ❑ PM10 TSP ❑ ❑ ❑ PM10 TSP ❑ ❑ ❑ HAPs HAPs ❑ Storage Tap; (s) Emissions Inventory Section 01 -Administrative Information Facility AIRS ID:' County A037 Plant Point Section 02 - Equipment Description Details Storage Tank Liquid k._u.' Detailed Emissions Unit Eight(8)750 bb; fixed toot condensate storage tan Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter r Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Throughput = (Requested Permit Limit Throughput= Barrels (bbl) per year 1,277,500.0 Barrels (bbl) per year Requested Monthly Throughput= 108500.0 Barrels (bbl) per month i Potential to Emit (PTE) Condensate Throughput = .;277;500:0 Barrels (bbl( per year Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquids produced = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = 283S.0 Btu/scf 4.3 scf/bbl Potential to Emit (PTE) heat content of waste gas routed to combustion device = Control Device 0.0 MMBTU per year 17.511.4 MMBTU per year 17.511A MMBTU per year Pilot Fuel Use Rate: Pilot Fuel Gas Heating Value: 200 salt 1000 Btu/scf 1.8 MMscf/yr 1752.0 MMBTU/yr Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Emission Factors Condensate Tank Pollutant Uncontrolled - Controlled (Ib/hbl) pb/bbq (Condensate Throughput) (Condensate Throughput) Emission Factor Source VOC 0.579 0.00091Wrat moo8840 - 0.0000404 s' 0.00000-042 0.0058300... 0.00001 9 0.02139650 0.0000456 0.0000442 0.0000020 0.0000149 0.0004415 5.0000008 Benzene Toluene Ethylbenzene xylene n -Hexane 224 TMP Pollutant Control Device Emission Factor Source Uncontrolled Uncontrolled (Ib/MMBM) (lb/bbl) (waste heat combusted) (Condensate Throughput) PM10 PM2.5 0.0075 0.007'5 0.0001 0.0001 0.0000 0.0009 0.0042 SOx NOx CO 0.0630:-: 0.3:1. G0 Pollutant Pilot Light Emissions Uncontrolled Uncontrolled (Ib/MMBtu) (Ib/MMscf) (Pilot Gas Heat Combusted) (Pilot Gas Throughput) PM10 PM2.5 0.0075 7.4510 7.4510 5.0000 i 1000 SOx NOx VOC CO 0.0.80 0-0000 0.3100 310,0000 Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year( (tans/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (Ibs/month) PM10 PM2.5 50x NOx VOC CO , 0.1 0.0 ',; 0.1 _.1 12.2 0.1 0.9 0,0 0.1 J... 12.2 0.0 0.0 0,6 0.0 __. 00 0,7 0.1 0-1 0.7 -, : 111,3 370.0 0.0 0.0 370.0 _:._ 314_7 3.0 0.3 0.3 3.0 =.: 507.2 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions - Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (Ibs/year) Benzene Toluene Ethylbenzene __65.1 0.0 0.0 1165.1 53.3 117.9.3 0.0 0.0 1,29.3 55.5 51.."0 0.0 0.0 51.6 2.6 2 of 18 K:\PA\2019\19 W E0334.CP2 Storage Tank(s) Emissions Inventory Xylene n -Hexane 224 TMP 380.7 0.0 9.0 0.0 0.0 0.0 9.9 380.7 19.9 564.0 11280.3 11280.3 20,3 20.3 1.0 3 of 18 KAPA\2019\19WE9334.0P2 Storage Tank(s) EnT'Issoons Inventory Section 06 -. Regulatory Summary Analysis Regulation 3, Parts A, B Source ce requires a permit . Regulation 7, Part D,Section I.C, D, E, F Storage tank is subject to Regulation. 7, Part D, Section I.C-F , Regulation 7, Part D,Section I.G, C ,_arage Tank is not sulaject to Regulation 7,Section I.G Regulation 7, Part D,Section II.B, C.1, C.3 Storage rank is sub)ect to Reg[_ -Ron 7, Part D, Section i:, B, C,1 &C,3 Regulation 7, Part D,Section II.C.2 Storage tank is subiact to Regulation 7, Part D, Section il.C2 Regulation 7, Part D,Section II.C.4.a.(i) Storage Tank is not subject to Reg_lat€on 7, Part D, Section il. 4.ali) Regulation 7, Part D,Section ll.C.4.a.(ii). Storage Tank is not .subj-e,'.Regulation 7, Part O, Section ll.C.4.a(ii), b - f Regulation 6, Part A, NSPS Subpart Kb Storage Tank is not subject to flSPS';b Regulation 6, Part A, NSPS Subpart 0000 Storage tank is not subject to NSPS 0000. NSPS Subpart 0000a Storage Tank is not subject to `,Sos 0000a Regulation 8, Part E, MACE Subpart HH Storage Tank is not subject to MAC- HH 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 t 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 for a condensate storage tank estimated to be greater than or equal to 80 tpy? 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. Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted (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 may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in 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 Section 09 -SCC Coding and Emissions Factors (For Inventory Use Only), AIRS Point # D0'1 Process tf 01 SCC Code Uncontrolled Emi s Pollutant Fact Control % Units PM10 _.vim B lb/1,000 gallons Condensate throughput PM2.5 B.Sla 0 lb/1,000 gallons Condensate throughput SOx -. 0 lb/1,000 gallons Condensate throughput NOx X12 0 lb/1,000 gallons Condensate throughput VOC 13.79 95 lb/1,000 gallons Condensate throughput CO 0.11 0 16/1,000 gallons Condensate throughput Benzene o02 95 lb/1,000 gallons Condensate throughput Toluene 0-02 95 lb/1,000 gallons Condensate throughput Ethylbenzene 0:00 95 lb/1,000 gallons Condensate throughput Xylene 6.61 95 lb/1,000 gallons Condensate throughput n -Hexane 0.21 95 lb/1,000 gallons Condensate throughput 224 TMP 0.00 95 lb/1,000 gallons Condensate throughput 4 of 18 ICAPA\2019\19WE0334.CP2 Storage Tank Regulatory Analysis Worksheet The regulatory requirements below ore determined based on requested emissions. Colorado Reeuation 3 Parts A and B -APEN and Permit Reouirements ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section 11.0.1.a)] 2. Is the consruction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definition 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3 Are total faddy uncontrolledVOC emissions greater h 5TPV NOx greater than 10 TPY or C0 emissions greater than 10 TPY [Regulation 3, Part B, Section 11.0.3)7 !Source Requires an APEN. Go to NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than )TPY (Regulation 3, Part A,Section tiara)? 2. is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See P5 Memo o5-01 Definitions 1.12 and1.14 and Section 2for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than WY or CO emissionsgreater than 10 TPY (Regulation 3, Part B, Section 11.0.2)? In: -_ mmom aparr,h Colorado Regulation], Part D. Section l.C-F 3 G 1. Is this storage -tank located in the 8 -hr ozone control area or any oz neuron -attainment area or attainment/maintenance area (Regulation 7, Part 0, Section l.A.1)? 2. Is this storage tank located at oil and gas operationsthat collect, store, or handle hydrocarbon liquids or produced water AND that are located at or upstream of a natural gas processing plant (Regulation 7, Part D, Section I.A1)? 3. Istho storagetank located at a natural gas processing plant (Regulation 7, Part D, Section Le)? 4. Does this storage tank contain condensate? 5. does this storage tank exhibit "Flash"(e.g. storing non -stabilized liquids) emissions (Regulation 7, part 3 Section l.G.2)? 6. Are uncontrolled actual emissions of this rtorage tank equalto or greater than 2tons per year VOC(Reguhtion 7, Part D, Section 1.133.001? L, e Part D, Section I.C.1 —General Requirements for Air Pollution Control Equipment— Prevention of Leakage Part D, Sectian3C.2—Emission Estimation Procedures Part D, sectionILD —Emissions Control Requirements Part!), Sectionl.E—Monitoring Part D,Sectionll.F—Recordkeeping and Reporting 'ank fs av51`-rt to',A-'=slur. ?.Sete Part 0, Sectond.G.2- Emissions Control Requirements Part D, Section I.C.1.a and h —General Requirements for Air Pollution Control Equipment —Prevention of Leakage Colorado Regulation], Part D, Section II 1. Is this storage tank located at a transmission/storage facility? 2. Is this storage tank' located at an oil and gas exploration and production operation , well production facility', natural gas compressor stations or natural gas processing plant°(Regulation 7, Part D, Section IC)? 3. Does this storage tank have a fixed roof (Regulation 7, Part 0, Section ll.A.20)? 4 'Are uncontrolled actual emissions of this storagetank equalt greater than 2tons per year VOC(ReguEtion 7, Part D, Section ll.Gl.c)? ITT: 11,5 -.121 T.i Part 0, Section. —General Provisions for Air Pollution Control Equipment and Prevention of Emissions Part D, Section II.C.1- Emissions Control and Monitoring Provisions Part D, Section II.C.3 - Recordkeeping Requirements 5. Does the storage tank contain only "stabilized" liquids (Regulation ], Part D, Section ll.C2.6)? Part D, Sectlortll.C.2-Capture and Monitoring for Storage Tanksfhted with Air Pollution Control Equipment is the controlled storage tank located at a well production facility, natural gas compressor nation, or natural gas processing plant constructed on or 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 vessel is constructed to receive an anticipated increase in throughput of hydrocarbon liquids or produced water (Regulation 7, Part 13, Section ll.C.4.a.(i)? Ica s _<> sot eFegt _,- _ issfiks, Is the controlled Soragetank located at a well production facility, natural gas compressor station, or natural gas processing plant constructed on or after -January 1,2021 or located at a facility that was modified on er after January 1, 7. 2021, such that an additional controlled storage vessel is constructed to receive an anticipated increase lnthroughput of hydrocarbon liquids or produced water (Regulation ], Part D, Section ll.C.4.a.(ii)? 40 CFR. Part 60, Subpart Kb, Standards of Performance for Volatile Organic Uquid Storage Vessels 1. Is the individual storage vessel capacity grea₹erthan or equal to 75 cubic meters (m) (`472 BBLs] (40 CFR 60.11ob(a))? 2. Does the storage vessel meet the following exemption in 60.111b(d)(4)7 .a a. Does the vessel has a design capacity less than or equal to 1,589.874 m'(`10,000 BBLI used for petroleum' or condensate stored,processed, or treated prior to custody transfer' as defined in 60.111b? 3. Was this storage vessel constructed, reconstructed, or modified (see definitions 4o CFR, 60.2) after July 23,1984(40 CFR60.1106(a))7 4. Does the tank meet the definition of"storage vessel"' in 613.1116? S. Does the storage vessel store a"volatile organic liquid(VOL)"'as defined in 60.111b7 6. Does Me storage vessel meet any one of the following additional exemptions: a. Is the storage vessel a pressure vessel designed to operate imexcess of 204.9 kPa [`29.7 psi] and without emissions tothe atmosphere (6o.11ob(d)(2))7; or b. Thedesign capacity is greater than or equalto 151 ms (-950 BBL] and stores a liquid with a maximum true vapor pressure` less than 35 kPa (60.1106(b))?; or c. Thedesign capacity is greater than or equal to 75 M' ["4]2 BBL) but less than 151 m' [-950 BBL] and stores a liquid with a maximum true vapor pressure' less than 15.0 kPa(60.110b(b))? 7. Does the storage tank meet either one of the following exemptions from control requirements: a. Thedesign capacity is greater than or equal to 151 m' [-950 BBL] and stores a liquid with a maximum true vapor pressure greater than or equal to 3.5 kna but less than 5.2 kna?; or b. Thedesign capacity is greater than or equalto 75 01,72 BBL] but Ims than 151 m' (-950 BBL] and stores a liquid with a maximum true vapor pressure greater than or equalto 15A kna but less than 27.6 kna7 Sisssass, Tat, sstb.isl MSS, KU 40 CFR Part 60 Subpart 0000/0000o Standards of Performance for Crude OII and Natural Gas Production. Transmission and Oirtribution 1. Is this storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas pro sing segment or natural gastransmission and storage segment of the industry? 2. Was this storage vessel constructed,reconstructed, or modified (see definitions 40 CFI, 60.2) between August 23, 2011 and September 18, 20157 3. Wasthis storage vessel constructed,reconstructed, or modified (see definitions 40 CFR, 60.2) after September 18, 2015? 4. Are potential MC emissions' from the individual rtorage vessel greater than or equal to 6 tons per year? 5. Does this rtorage vessel meet the definition of"storage vessel"' per 60.5430/60.5430a? 6. Is the storage vessel subjectto and controlled In accordance with requirements. for...age vessels in 40 CFR Part 60 Subpart Kb or. CFR Part 53 Subpart NH? Go to next question Source Requires a permit Source Requires an APEN. Go to Go to next question Source Requires a permit Continue -You have indiatedth Continue -You have indicated th Storage Tank is not subject to Re Continue -You have indicated try Go to the next question You ha Go bathe next question Source Is subject to parts. of Regi IISource is subject to all provision: Continue - You have indicated th StorageTank is not subject NSPS Go to the next question Storage Tank Is not subject NSPS key INWe: If a storage vessel is previously determined to be subject to NSPS 0000/0000a due. emissions above 6 tons per year VOC on the applicability determination date, Rshould remain subject. NSPS 0000/0000a per 60.5365(e)(21/80.5365a(e)(2) even if potential VOC emissions drop below 6tons per year] 40 CFR, Part 63, Subpart MALT HH, 011 and Gas Production Facilities 1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. A facility that procrose, upgrades or stores hydrocarbon liquids"(63.760(a)(2)); OR b. A facility that procm , upgrades or stores natural gas prior mthe point at which natural gasenters the natural gas transmission and storage source category or is delivered to a final end user' (63.760(a)(3))? 2. Is the tank located at a facility thatismajor' for HAPs7 3. Does the tank meet the definition of"storage vesseft"in 63.]61? 4. Does the tank meet the definition of"storage vessel with the potential for flash emissions"' per 63.7617 5. Is the tank sub" ct to control requirements under 40 CFR Part 60, Subpart Kb or Subpart 0000? IS`-drag»Tank is nr_^wl*stto MA, Rla SubpartA, General provisions per 463.]64 (a) Table 2 463366- Emissions Control Standards 463.]]3 -Monitoring 463]]4-Recordkeeping 463]]5 -Reporting RACT Review RACT review isrequired If Regulation 7 does not apply AND if the tank is in the non -attainment area. If thetank meets both criteria, then review RACT requirements. Disclaimer Stu rage Tank is not subject to Rs Storage Tank 6 not subject NSPS Continue- You have indicated th Storage Tank is not subject MAC This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementingregulations, and Air Qualify Control Commission regulations. This document is not a rule or regulation, and theanalysisit contains may not apply to a particularsituation based upon the individual facts and circumstances. This document does not change &substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Qd 1'ty Control Commission regulations, the language of the statute g 1 ton will control The use of noremandatory language h as "recommend,""may,""should," and "can," is intended to describe APCC integretations and recommendation Mandatory terminology such as"must" and °required"are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not rksfeblish legally binding requirements in and &itself. f Storage Tank(s) Emissions Inventory Section 01- Administrative Information IFaciliN AIRS ID: 123 County Section 02 - Equipment Description Details Storage Tank Liquid Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter y, Section 03 - Processing Rate Information far Emissions Estimates Primary Emissions - Storage Tanks) Actual Throughput= 'Requested Perrnit Limit Throughput= 4037 Plant 002553t1,501 Point Barrels (bbl) per year u Barrels (hbl) per year Requested Monthly Throughput= £2000.0 Barrels (bbl) per month Potential to Emit (PTE) Condensate Throughput = ,730„000.0 Barrels (bbl) per year Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquids produced = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = .0 Btu/scf 0._ scf/bbl Potential to Emit (PTE) heat content of waste gas routed tocombustiondevice = Control Device 0 U MMBTU per year 1.035.9 MMBTU per year 1,035.9 MMBTU per year Section 04 - Emissions Factors & Methodologies Will this storage tank emit flash emissions? Attributed to Condensate tanks Pollutant Produced Water Tank Uncontrolled Controlled Ilb/bbl) (Ib/bbl) (Produced Water Throughput) (Produced Water Throughput) =ETRINIIIMII=111== MEMMEMIIIMMIIMEMMIIMEMEM Emission Factor Source Pollutant Pilot Light Emissions Pollutant Control Device Uncontrolled (Ib/MMBtu) (waste heat combusted) Uncontrolled (Ib/bbl) (Produced Water Throughput) Uncontrolled (Ib/MMBtu) Uncontrolled (Ib/MMscf) (Pilot Gas Throughput) (Pilot Gas Heat Combusted) Emission Factor Source Emission Factor Source Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year( Requested Monthly Limits Controlled (Ibs/month) _ PM10 PM2.5 SOx NOx VOC CO 0.0 0.0 0.0 OA ... 0.7 0.0 0,0 .,... 0,0 0.7 0.0 0.0 _.., 0,0 0.0 0,1 0.0 0.0 .,-_ OA 0.0 6.0 6.6 0.0 0.0 6.6 0.3 .566.4 0,2 0.0 0.0 0.2 2.2 27.3 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (Hors/year) (Ibs/year) Benzene Toluene Ethylbenzene 315.4 0.0 .._ �... 257.7 ... ..._ __:.. 9,2 0.A 0.0 9.2 .. 7 of 18 KVA\2019\19 W E0334.CP2 Storage Tank(s) Emissions inventory xyiene n.Hexane 224 TMP 64.3 608.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 64.3 608.8 3.2 30.4 0.0 0.0 8 of 18 KAPA\2019\19WE0334.CP2 Storage Tai k(_s) Emissions Inventory/ Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Sourca requires a permit Regulation 7, Part D,Section I.C, D, E, F Storage' tank is wbject to Regulation ;, Pant D, Section I.C-F Regulation 7, Part D,Section I.G, C Storaga Tank is not subject to Regulation 7, Sageon I.G Regulation 7, Part D,Section II.B,.C.1, C.3 Stowee tank is subject to Reeitation'7, ?art u, Section II, e, C.1 & c< Regulation 7,Part D,Section lLC2 Storage tanks subject to Regulation 7. Dart D, S:pctian N.C.? Regulation 7, Part D,Section II.C.4.a.(i) Storage Tank is not subject to RegulatoD, Section il.C.4.a't Regulation 7, Part D,Section ll.C.4.a.(ii) Storage Tan-..., not subject to Re,,..,,n 7. Part O, Section ll.C -_ p -f Regulation 6, Part A, NSPS Subpart Kb 'storage Tank is not subject to NSDS ab Regulation 6, Part A, NSPS Subpart 0000 Storage tank is not subject to NSPS 0000. NSPS Subpart 0000a Stowea Tank is not subject to NSPS 0€ 00a _ Regulation 8, Part E, MAR Subpart HH Produced Seater Storage tank is not subject tc MACt HH ' (See regulatory applicahility 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 V0C per year OR are the uncontrolled actual or requested emissions for a condensate storage tank estimated to be greater than or equal to 80 tpy? 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. Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted (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 may be appropriate to use an older site -specific sample, - If no, the permit will contain an 'Initial Compliance" 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 AIRS Point # 602 Section 09 -SCC Coding and Emissions Factors (For Inventory Use Only) Process # O1 SCC Code Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.60 0 lb/1,000 gallons Produced Water throughput PM2.5 0.00 G lb/1,000 gallons Produced Water through put S0x «Rift 0 lb/1,000 gallons Produced Water throughput NOx 0."_0 9 lb/1,000 gallons Produced Water throughput V0C 0.73 As lb/1,000 gallons Produced Water throughput CO t.-.._ 0 lb/1,000 gallons Produced Water throughput Benzene 0-G1 95 lb/1,000 gallons Produced Water throughput Toluene 0.01 95 lb/1,000 gallons Produced Water throughput Ethylbenzene v-_.. ._ lb/1,000 gallons Produced Water throughput Xylene 0.00 95 lb/1,000 gallons Produced Water throughput n -Hexane 0.02 05 lb/1,000 gallons Produced Water throughput 224 TMP 0.00 95 lb/1,000 gallons Produced Water throughput 9 of 18 KAPA\2019\19WE0334.CP2 Storage Tank Regulatory Analysis Worksheet The regulatory requirements below are determined based on requested emissions. Colorado Re ulatlon 3 Parts A and H-APEN and Permit Requirements Soor.e is In the Nun=Atteinment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this Individual source greater than 2 TPY (Regulation 3, Part A, Section Pala)? ®Source Requires an APED. Go. to 2. Produced Water Tanks have no grandfathering provisions 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10TPY or CO emissions greater than to TPY(Regulation 3, Pat B, Section ll.D.3)? IYotrhave Indicated titatvowceis inthe Non -Attainment NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than I TPY (Regulation 3, Part A, Section ILD.l.a)? 2. Produced Water Tanks have no grandfathering provisions 3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10TPY(Regulation 3, Part B, Section ll.D.2)? Colorado Peculation], Part D. Section I.C-F &G 1. Is this storage tank located in the B -hr ozone control area or any ozone non -attainment area or attainment/maintenance area (Regulation 7, Part D, Section LAI)? 2. Is this storage tank located at oll and gas operations that collect, store, or handle hydrocarbon liquids or produced water AND that are located ator upstream of a natural gas processing plant (Regulation ], Part D, Section I.A.1)? 3. Is this storage tank locoed at a Natural gas processing plant (Regulation?, Part D, Section I.G)? 4. Does this storage tank contain condensate? S. Does this storage tank exhibit "Flash"le.g. storing non-stabilzed liquids) emissions (Regulation], part D, Section 1.621? 6 Are uncontrolled actual emissionsf this storage k equalto org'eater than 2tons per year VOC Re ulatlon 7, Part D,Section l.D3alii117 ISteekige tank iv kuhit-crottionl.C-F Part D, Section I.C.1 —General Requirements for Air Pollution Control Equipment —Prevention of Leakage Part D, Section I.C.2—Emission Estimation Procedures Part O, Section IA —Emissions Control Requirements Part D, Section LE —Monitoring Part D, Section I.F—Recordkeeping and Reporting Part D, Secfion I.G.2- EmissionsControl Part D, Section I.C.1.a and b —General Requirements for Air Pollution Control Equipment —Prevention of Leakage Colorado Peculation 7. Part D, Section II 1. Is this storage tank located at atranmission/storagefacllky? 2. Is thb sorage tanks located at an ail and gas exploration and production operation, well production facility', natural gas compressor station' or natural gas processing plane(Regulation ], Part 0, Section RC)? 3. Does this storage tank have a fined roof (Regulation 7, Part 0, Section ll.A.10)? 4. Are uncontrolled actual emissions of this storage tank equal to or greater than 2 tons per year VOC (Regulation 7, Part 0,Section ll.Cl.c)? jqicrage lErblEE:a ? Part O. Seetion II. B C..1 'C.3 Part D, Section II.B—General Provisions for Air Pollution Control Equipment and Prevention of Emissions Part D, Section I I.C.1- Emissions Control and Monitoring Provisions Part O, Section II.C.3- Recordkeeping Requirements 5. Does the storage tank contain only "stabilized.liquids (Regulation 7, Part D, Section ll.C.2.b)? Yes Tim ? No 9gMf Go to next question Source Requires a permit Source Requires an APEN. Go to Source Requires a permit Continue- You have Indicated th Cmdinue- You have indicated th Storage Tank is not subject to Re Continue - You have indicated th Go to the next question -You ha Go to the next question Source is subject to parts of Reg, Part O, Section II.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment Is the controlled storage tank hated at a well production facility, natural gas compressorstation, or natural gas processing plain constructed onor after May 1, 2020 or located at a facility thrt was modified on or after May 1, 2020, such 6. that an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of hydrocarbon liquids or produced water (Regulation], Part D, section ll.C.9.a.(I)? Storage Tank is not subject to Re Is the controlled storage tank located at a well production facility, natural gas compressor station, or natural gas processing plant constructed oa or after January 1, 2021 or located at a facility that was modified on or after January 1, 7. 2021, such that an additional controlled storage vessel -s constructed to receive an anticipated Increase in throughput of hydrocarbon liquids or produced water (Regulation ], Part D, Section II C.4.a.(b)7 • 'storage Tnk is note. ., D, 5ectlo 40 CFR, Part 60, Subpart Kb, Standards of Performance for Volatile °manic Liquid Storage: Vessels I. is the individual storage vessel capacity greater than or equal to 75 cubic meters (m) [-412 BBB] (40 CFR 60.1106(a))? 2. Does the storage vessel meet the following exemption In 60.1316(d)(4)? a. Does the vessel has a design capacity less than or equal to 1,589.8]4m'(-10,000 BBL] used for petroleum' or condensate stored,processed, or treated prior to custody transfer' as defined in 60.1116? 3. Was this storage vessel constructed,reconstructed, or modified (see definitions 40CFR, 60.2) after July 23, 1984(40 CFR 60.1106(a))? 4. Does the tank meet the definition of"storage vessel' in 60.111b? 5. Does the storage vessel store '"volatile organic liquid(Vol)"'as defined in 60.1116? 6. Does the storage vessel meet any one of thefollowing additional exemptions: a. Is the storage vessela pressure vessel designed to operate In excess of 204.9 kPa [-29.7 psi) and without emissions to the atmosphese (60.110b(d)(2))?; or b. The design capacity is greater than or equal to 151 m' (-950 BBL) and stores a liquid with a maximum true vapor pressure` less than 3.5 kna (60.1106(b))?; or c. The design capacity is greaterthan or equal to 75 M' 1-972 BBL] but less than 151 ms (^950 BBL] and stores a liquid with a maximum -true vapor pressures less than 15.0 kna(60.110b(b))? 7. Does the storage tank meet either one of the following exemptions from control requirements: a. The design capacity is greaterthan or equal to 151 m' ('950 BBL) and stores a liquid with a maximum true vapor pressure greater than or equal to 3.5 kna but less than 5.2 kPa?; or b. The design capacity is greater than or equal to 75 M' ['472 BBL] but less than 151 m' (^950 BBL) and stores a liquid with a maximum[rue vapor pressure greater than or equal to 15.0 kPa but less than 27.6 kPa? Stp,age Tank fsnut Storage Tank is not subject NSPS 90 CFR, Part.. Subpart 0000/0000a, Standards of Performance for Cmde Oil and Natural Gas Production, Transmission and Distribution 1. Is tha storage vessel located at a facility in the onshore oil and natural gas productionsegment, naural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this storage vessel constructed,reconstructed, or modified (see definitions 40 CFR, 60.2)between August 23, 2011 and September 18, 2015? 3. Was this storage vessel constructed, recanstrurted, or modified (see definitions 40 CFR, 60.2) after September 18, 2015? 4. Are potential VOCemissions' from the ind Nidual storage vessel greater than or equalto 6 tons per year? 5. Does this storage vessel meet the definition of"storage vessel.' per 60.5430/60.5430'2 6. Is the storage vessel subjectto and controlled in accordance with requirements for storage vessels in 90 CFR Part 60 Subpart Kb or. CFR Part 63 Subpart HH? ISTor ;e lank is not suhiect a o;5P4 OONCin [Note: If a storage vessel is previously determined to be subject to NSPS 0000/0000a due m emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS 0000/0000a per 60.5365(e)(21/60.5365a(e)(2) even if potential VOC emissions drop below 6 tons per year] 40 CFR, Part 63, Subpart MALT HH, Oil and Gas Production FacllltIm 1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. Afacility that processes, upgrades erstorm hydrocarbon liquids' (63.76o(a)(2)); OR b. A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end user' (63.760(a)(3))? 2. Is the tank located at a facility that's major' for HAPs? 3. Does the tank meet the definition of"storage vessel"' In 63.]61? 4. Does the 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 Part 60, Subpart Kb or subpart 0000? H d Wah Yea Subpart A, General provisions per 463.]64 (a) Table 2 §63.766 - Emissions Control Standards 463.773-Monkoring §63.]74-Recordkeeping §63.775 -Reporting RACE Review RACT review is required If Regulation ] does not apply AND if the tank Is in the non -attainment area. lithe tank meets bath criteria, then review RACT requirements. Disclaimer Continue - You have Indicated th Storage Tank is not subject NSPS_ Go to the next question Storage Tank is not subject NSPS Gain. -You have indicated th Storage Tank b not subject MAC Separator Venting Regulatory Analysis Worksheet The regulatory requirements below are determined based on requested emissions. [olerzdo Re ulation3 Parts Aand B-APENend Perm it Re• ulrements --�o�ce is In the NomA?.arrnent Fraa ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section ll.D.l.a)7 2. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOP greater than SO TPY or CO emissions greater than 10 TPY (Regulation 3, Part%Section 110.3)7 You have indicated that source is in the Non.Attenunent A ex NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section ll.D.l.a)? 2. Are total facility uncontrolled V0C emissions from the greater than 2 TPY, NOz greater than 5 TPY or CO emissions greater than 30 TPY (Regulation 3, Part R, Section ll.D.2)?- 'Not enough information Colorado Regulation 7. Part D, Section 11 1. Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1,2x14? 'Not noon& informerion Section 11.8.2— General Provisions for Air Pollution Control Equipment Used to Comply with Section II Section ILE- Control of emissions from well production facilities Alternative Emissions Control (Optional Section), a. Is this separator controlled by a hack -up or alternate combustion device (Le., not the primary control device) that is not enclosed? Section II.B.2.e —Alternative emissions control equipment Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Glean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend,"'may,"'should,"and "can,"is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must"and 'required" are intended to describe controlling requirements under the terms of the C/ean Air Ad and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in end of itself Separator ‘./nting Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Using Gas Throughput to Monitor Compliance Does the company use site specific emission factors based on a gas sample to estimate emissions? This sample should represent the gas outlet of the equipment covered under this AlRs ID, and should have been 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 may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. Are facility -wide permitted emissions of VOC greater than or equal to 40 tons per year in the ozone nonattainment area OR are emissions greater than or equal to 90 tons per year in the ozone attainment area? If yes, the permit will contain: -An "Initial Testing Requirement" to collect a site -specific gas sa mple from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. -A "Periodic Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application on an annual basis. Will the operator have a meter installed and operational upon startup of this point? `le If no, the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational (not to exceed 180 days). This condition will use the "Volume of waste gas emitted per BBL of liquids throughput" (scf/bbl) value in section 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 -al s Section 08 -Technical Analysis Notes AIRS Point # 004 Section 09 - SCC Coding and Emissions Factors (For Inventory Use Only) Process # SCC Code 01 3-10-001-60 Flares Pollutant Uncontrolled Emissions Factor Control % Units PM10 0 M(ASCF PM2.5 211 0 011ISCF 50x 1.6 0 ISCF NOX. 189.1 0 lb/,1F{ 0CP VOC '08835.1 95 Ibjfs"M5CF CO 862.1 0 :b,' at;`xt5CF Benzene 287.8 95 ib/1/116SCF Toluene 248.5 95 tbNWISCF Ethylbenzene 8.7 95 • 10141 SCF Xylene 69.0 95 ib/611MSCP n -Hexane 3026.7 9S ibiNIN9SCF 224 TMP 0.0 SS iblmms F 17 of 18 K:\PA\2019\19WE0334.CP2 Separator Venting Emissions Inventory - Emission Factors Separator Venting Emission Factor Source Pollutant Uncontrolled Controlled (Ib/MMscf) (Ib/MMscf) (Gas Throughput) (Gas Throughput) VOC 108835.15 S44'.76 y y it I a�anaIY�f. �$o ' `FxtenS¢ga , ,.ed sus erJec. yob w.: 1`.='=s Exters('tj ma's nn lyass: Benzene 287.77 25.39 Toluene 248.53 12.43 Ethylbenzene 8.69 0.43 Xylene 69..00 3,44 n -Hexane 3026.66 t1S1.8.3 224 TMP 0.00 0.00 Pollutant Primary Control Device Emission Factor Source Uncontrolled Uncontrolled (Ib/MMBtu) Ib/MMscf (Waste Heat Combusted) . (Gas Throughput) PM10 0.0075 20.721 2 e_ _ Ox) PM2.5 0.0075. 20,7212 SOx 0.0006 1 .6359 _ NOx 00080 3.89.108F CO 0.310 2611100 Pollutant Pilot Light Emissions Emission Factor Source Uncontrolled Uncontrolled (Ib/M MBtu) Ib/MMscf (Waste Heat Combusted) (Pilot Gas Throughput) PM10 q. r _. PM2.5 0,0000 SOx 0.6000 NOx 0.0000 VOC 0.0000 CO 0.0000 Section OS - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tans/year) (tons/year) Requested Monthly Limits Controlled (Ihs/month) PM10 PM2.5 SOx NOx VOC CO 0.1 0,0 0.0 0.1 0.1 i1 0.1 0.0 t.=., 0.1 0.1 i1 0.0 0.0 0.0 0.0 0.0 b 0.6 0.0 0.0 0.6 0.6 101 342.8 0.0, 0.0 342.8 17.1 2912 2.7 0.0 0.0 2.7 2.7 461 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled - Controlled (Ibs/year) (Ihs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (Ihs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TM 1813 0 0 1813 91 15.56 0 0 1566 78 55 0 0 55 3 435 0 0 435 22 19068 0 ,. 19068 953 0 0 0 0 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Part D, Section ILB, F Regulation 7, Part D, Section II.B.2.e (See regulatory applicability worksheet for detailed analysis) ?acuah information .;e:zatgh Information. 16 of 18 KAPA\2019\19WE0334.CP2 Separator Venting Emissions Inventory Section 01- Administrative Information Facility AIRS ID: Coun y Plant Poin Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter Gas meter Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Separator Actual Throughput = MMscf per year Requested Permit Limit Throughput= 6,3 MMscf per year Requested Monthly Throughput= 0.5 MMscf per month Potential to Emit (PTE) Throughput = MMscf per year Secondary Emissions - Combustion Device(s) for Air Pollution Control Separator Gas Heating Value: Volume of waste gas emitted per BBL liquids throughput: Control Device Pilot Fuel Use Rate: Pilot Fuel Gas Heating Value: Section 04- Emissions Factors & Methodologies Description MW 48 Weight Helium C02 N2 methane ethane propane isobutane n-hutane isopentane n -pentane cyclopentane n -Hexane 2.4 cyclohexane Other hexanes heptanes methylryclohexane 224-TMP Benzene .,._ Toluene 0..2 Ethylbenzene 0.0 Xylenes Q:I C8+ Heavies Total VOC Wt h/Ih-mol Displacement Equation Ex=Q• MW `Xx/C 15 of 18 K:\PA\2019\19WE0334.CP2 Hydrocarbon Landaus Regulatory Analysis Worksheet The regulatory requirements below are determined based on requested emissions and throughput. Colorado Regulation 3 Mt.A and a -AMEN and Permit Requirements l» we is in the Nen _tiontinent.Ares ATTAINMENT 2 Are polled actual emissionsany criteria pollutants � from Nisi ter Nan 2TPti(Regulation 3, Pan A, Section ll.0.1.a17 . Is the loadout located atanexploration and production site (e.g., well pad) IReeulatlun 3, Part8,Secdon 11.0,1.11? 3. Is the loadout operation loading less than 10000 gallons 1238 881:1 of crude oil per day on an annual average basis, 4. Is the loadout operation loading less than 6,750 UM per year of condense. via splash ND 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure, 6. Are to facility uncontrolled vole emissions greater than 611M, NC. greater than to TPT a CU emissions greater Man 10 TM (Regulation 3, Part 8,seceonll.o.31? dl fao tae You have rndio:ter Mat co.,c. ,tie son•AnaM_tnt area. NOMASTAINMSNT 1. rtrolled emissions irons any criteria pollutants from this individual source greater than l TPT (Regulation 3, Part A, Section 11.0.1,17 Are loadout located at an exploration and production site (e.g., well peal lflegulation 3, Part e, section II.Q.l.11i Is Me loadout operation loading less than 10,000 gallons (238 Rfils) of nude olI per day an an annual average basis, Is the Madoutoperation loading less than 6,750 bbls per year of condensate via splash fill? Is the loadout operation loading less Nan IAN. bhis Per Mar of condensate via submerged RII procedure] 6. Arc total facility meant°lied VOC emissions from the greater Nan 2 TM, Nog greater Nan sr, or CO emissions greater than 10 TM' RRegulation 3, Pm B, SeN'on 11.0.21, Colorado Regulation 7 tart O Section . Is this condensate storage Nnk llydroarbon liquids loadout located at well production facility, natural gas compressor station a natural gas processing plant? 2 d.,'Fa h t of hydrocarbon liquids loadout M transport vehiNm greater Manor equal to 6,000 ban., spume N subject s-eFulm .n pact gc?r....__ Section .a.11l-C Schedule Secgon l[Cs,.ilil-Operation without venting Section 11[.s.a.liiil-loadout Equipment Operation and Maintenance section .a.livlhtoaaoutob serrations and OpemmrTraining Section II.C.S.a(v).. Records section II.e5,.lvil-Requirements for Air Pollution Control Equipment Disclaimer This dzumarirRAN,'N °AMA.. With detemdnug Magi ubifdydmtain requirements dd. Clean Air Act its implementing regulations, earl Air Quality Control Commission regulations. This document is Cola mleeregulation, and the enag'sis it contains may not apply foe particularsdiation bused upon the indidud facts d circumstarces. This dcement-does net change orsubatltute for enylaw regdeton.a any other legally bindrg requirement and is not legally enforceable. In the evert deny conflict between the language of this document and the language tithe Clean Air Act, its Implementing regulations, ed Alr Quality Control Commission regulations, the language ofthestate. or regulation will control The use ornmmandatoy language such as "recommerd,""may,""ahoud," and ton," is intended to describe APCO interpretatbns and recommendations. Mandatory harmlnol gy such as "must" and "required are intended b describe controlling requirements under 'Interns of the Clean Air Act and Air Quality Contra Commission regulations, bolt)* document does not establish legegy binNng regd....is in end dawn. yRS"v'rf'ke7. idiaMe ntikii5AOn CW.WAS *WARM 1isi3S Go to nett Go to the next tumeon Coto newt question GO co ti question Go to next question The loadout req.. a permit Source issubject to Regulation 7 Part05eclion II.C.5. carbon Loadout �s Inventory Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncmtrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (Ibs/month) PM10 PM2.5 SOx NOx VOC - . ... .._ Ol';-, 0.0'_. r'i'.01 ] ,:': .:.. 2,21. 0,08 6.01 5,23 2660 2.56 0.12 622 26 M 66 3.85 21 05 5,25 666 Hazardous. Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (Ibs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 225 .r. ...- 1_.. fl1 225 215 ,_ ..._. 21 _3 .., ,.- 1 Ta 4 37 1626 _253 _15 2122 _13 Section 06 - Reeulatory Summary Analvsis Regulation 3;Parts A, B Sonece reenni es a permit Regulation.7 Part D Section II.C.5. (See regulatory applicability worksheet for detailed analysis) an hydrocarbon llqui& Ie=.-er.1t so...c - _u.*g a 11 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 Section 09 - SCC Coding and Emissions Factors IFor Inventory Use Only), AIRS Point # 003 Process # 01 SCC Code 4-06.001-32 Crud OW Submerged Lodding Normal mal Semde ,_-0.'0) Uncontrolled Emissions Pollutant Factor Control %. Units PM10 .262 2 lb/1,000 gallons transferred PM2.5 0.00 v lb/1,000 gallons transferred 50x 2.90 _ lb/1,000 gallons transferred NOx 0.00 _n lb/1,000 gallons transferred VOC 2.9 0.0. lb/1,000 gallons transferred CO 0.02 ., lb/1,000 gallons transferred Benzene 0.00 >., lb/1,000 gallons transferred Toluene ii.99 :5 lb/1,000 gallons transferred Ethylbenzene i?a:CO 5 lb/1,000 gallons transferred Xylene CiC0 95 lb/1,000 gallons transferred n -Hexane 0.,14 lb/1,000 gallons transferred 224 TMP 000 .._ lb/1,000 gallons transferred 13 of 18 K:\PA\2019\19WE0334.CP2 Hydrocarbon Loadout Ertes,ioos inventory Section 01- Administrative Information 'Facility AIRS ID: County Plant Point Section 02- Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Is this loadout controlled? Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Hydrocarbon Loadout Actual Volume Loaded = 'Requested Permit Limit Throughput= Potential to Emit (PTE) Volume Loaded = Barrels (bbl) per year 3 Barrels (lb') per year Requested Monthly Throughput= 138530 Barrels (bbl) per month Secondary Emissions - Combustion Device(s) Heat content of waste gas = Actual Volume of waste gas emitted per year= Requested Volume of waste gas emitted per year = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion devire = Barrels (bbl) per year 3$, Btu/scf ":..'d scf/year 1.33:2:1:t scf/year Potential to Emit (PTE) heat content of waste gas routed to combustion device= ,.7? MMBTU per year 333 MMBTU per year 3,393 MMBTU per year Control Device Pilot Fuel Use Rate: Pilot Fuel Gas Heating Value: cfh Btu/scf MMscf/yr .t MMBTU/yr Section 04 -Emissions Factors & Methodologies Does the company use the state default emissions factors to estimate emissions? Are the emissions factors based an a stabilized hydrocarbon liquid sample drawn at the facility being permitted? Loading Loss Equation L =12.46"5'P'M/T Factor Meaning Value Units Source 5 Saturation Factor =— � MI"O f P True Vapor Pressure „..q:,s E, ,''. psia M Molecular Weight of Vapors ,u''v+".'" ',4¢ T?t lb/Ib-mol .T Liquid Temperature ..T:412)4/1353Y.,:,,33 Rankine L Loading Losses 2£7291331 Ib/1000 gallons .. 4120624582 lb/bbl Component Mass Fraction Emission Factor Units Source Benzene i� d u{.s '2k�}�f+ 34 .. <i^ 0.000158815 lb/bbl Toluene ;,, BFa. t* «flG 0.000155875 1b/bbl .� :.2: Ethylbenzene d._0425.5s lb/bbl XYlene 0;ilr; 5:03123205 lb/bbl n -Hexane c "$_-'-<2^-• 0.0013422:. lb/bbl 224TMP :. ., .. 0 lb/bbl "' - - : s-,'• Pollutant Hydrocarbon Loadout Uncontrolled Controlled (Ib/bbq (Ib/bbl) (Volume Loaded) (Volume Loaded) =M1= riEVEN!M=IM Pollutant Pilot Light Emissions Pollutant Uncontrolled (Ib/MMBtu) Uncontrolled (Ib/bbl) (waste heat combusted) (Volume Loaded) Uncontrolled (Ib/MMBtu) Uncontrolled (Ib/MMscf) (Pilot Gas Throughput) Maste Heat Combusted) Emission Factor Source Emission Factor Source Emission Factor Source 12 of 18 K:\PA\2019\19 W E0334. CP2 This document assists operators with determining applicability of certain requirements of the Clean AirAct, its implementing regulations, and Air Quality Control Commission regu/edans This document'is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its. implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as'recommend,""may,""should," and "cen,"is intended to describe APCD interpretations and recommendations. Mandatary terminology such as "must" and "required" are Intended to. describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself CRESTONE PEAK RESOURCES December 03, 2020 Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-61 4300 Cherry Creek Drive South Denver, CO 80246 Submitted by email to: cdphe apcd ssp application@state.co.us SUBJECT: Regnier Farms 19H -B268 Battery (123-A037) Crestone Peak Resources Operating, LLC APEN/Permit Modifications Crestone Peak Resources Operating, LLC (Crestone) is submitting the enclosed application for the Regnier Farms 19H-8268 Battery facility (123-A037), located in SWSE Section 18 T2N R68W and NWNE Section 19 T2N R68W. This facility is currently permitted under Construction Permit No. 19WE0334, issued on 09/09/2019. With this submittal, Crestone is doing the following: • Requesting a modification to the following sources, each with a revised throughput and site -specific emission factor: o The Condensate Tanks (AIRS ID 123-A037-001) o The Produced Water Tanks (AIRS ID 123-A037-002) o The Truck Loadout (AIRS ID 123-A037-003) o The Low -Pressure Separator (AIRS ID 123-A037-004) • Providing six APEN cancellation requests for engines that no longer exist at this facility. This application is not a major modification, therefore does not constitute a Non -Attainment New Source Review. Included in this submittal are all required APEN and permitting forms, APEN fees, and all other required documentation. Should there be any questions, I can be contacted directly by phone at (303) 774-3923, or by e-mail at sabrina.pryor@crestonepr.com. Sincerely, Sabrina M. Pryor Air Quality Engineer 10188 EAST 125 FRONTAGE ROAD 1 FIRESTONE, CO 80504 1303.774.3900 I WWW.CRESTONEPEAKRESOURCES.COM Form APCD-100 COLORADO Department of Public Health & Environment Oil & Gas Industry Construction Permit Application Completeness Checklist Company Name: Source Name: Date: Ver. November 29, 2012 Crestone Peak Resources Operating, LLC Regnier Farms 19H -B268 (123-A037) 12/03/2020 Are you requesting a facility wide permit for multiple emissions points? Yes No ❑' El In order to have a complete application, the following attachments must be provided, unless stated otherwise. If application is incomplete, it will be returned to sender and filing fees will not be refunded. Attachment Application Element Applicant APCD A APEN Filing Fees d ■ B Air Pollutant Emission Notice(s) (APENs) & Application(s) for Construction Permit(s) — APCD Form Series 200 C Emissions Calculations and Supporting Documentation a a D Company Contact Information - Form APCD-101 a E Ambient Air Impact Analysis nCheck here if source emits only VOC (Attachment E not required) a F Facility Emissions Inventory — Form APCD-102 )� Check here if single emissions point source (Attachment F not required) G Process description, flow diagram and plot plan of emissions unit and/or facility d InCheck here if single emissions point source (Attachment G not required) H Operating & Maintenance (O&M) Plan — APCD Form Series 300 a ■ NI Check here if true minor emissions source or application is for a general permit (Attachment H not required) I Regulatory Analysis ■ U i Check here to request APCD to complete regulatory analysis (Attachment I not required) J Colorado Oil and Gas Conservation Commission (COGCC) 805 Series Rule Requirements— Form APCD-105 Check here if is p source not subject to COGCC 805 Series requirements II (Attachment J not required) Send Complete Application to: Colorado Department of Public Health & Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Check box if facility is an existing Title V source: n Send an additional application copy Check box if refined modeling analysis included: n Send an additional application copy Check box if application is for major NA NSR or PSD permit: n Send eight (8) total application copies Page 1 of 101 FormAPCD- 1 00-AppCompleteCheckl i st-Ver. l 1-29-20 1 2.docx Attachment A 4 APEN Filing Fees — 4 x $216.00 = $864.00 Total = $864.00 Page 2 of 101 COLORADO Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado AUTHORIZATION TO CHARGE A CREDIT CARD Date: 12/03/2020 Customer Information Company/Individual Name: Crestone Peak Resources Operating, LLC Company/Individual Address: 10188 East 1-25 Frontage Road City: Firestone State: Telephone Number: 303-774-3923 CO Zip: 80504 Name and Telephone number of person calling Sabrina Pryor 303-774-3923 Fax number Payment Information Payment Amount: $ 864.00 Email Address sabrina.pryor@crestonepr.com Payment is for (eg: Site or name for APEN or Asbestos permit/certification etc.) Regnier Farms 19H-8268 (123-A037) 4 APENS: AIRS (123-A037-001, 002, 003, and 004) Modifications Printed Name of Person On Card: Sabrina M. Pryor Cardholder Signature: (' !''` :17 - Credit Card Number (Only if called/sent in or if magnetic strip doesn't work) Given over the phone ( Expiration Date 3 -digit Cod PUBLIC HEALTHENVIR-AP 4300 CHERRY CREEK DR S DENVER, CO 80246 12/03;2020 11:31:49 MID: XXXXXXXXXXXX554 1ID: XXXXX161 CREDIT CARD MC SALE Card # Token XXXXXXXXXXXX4698 SEQ #: 4 Batch #: 446 INVOICE 4 Approval Code: 048}60 Entry Method: Manual Mode: Odle Tax amount: $0,00 Cust Code: 208 Avs Code: NNN Card Code: M SALE AMOUNT $864,00 X I agree to pay above total amount according to card issuer agreement. (Merchant agreement if Credit Voucher) MERCHANT COPY (for office use only) Asb Permit Asb Demo Asb Ld Permit Ld Cert APEN/GP CEC Forms Cert/Class 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer Type of Fee (Circle): Page 3 of 101 Attachment B APEN Forms: APEN Form APCD-205 — Condensate Tanks — AIRS 123-A037-001 (with Form APCD-212) APEN Form APCD-207—Produced Water — AIRS 123-A037-002 (with Form APCD-212) APEN Form APCD-208 — Hydrocarbon Liquid Loading — AIRS 123-A037-003 APEN Form APCD-211— Gas Venting — AIRS 123-A037-004 Emissions Permit/APEN Cancellation Request— Form APCD-107 — Engine —AIRS 123-A037-014 Emissions Permit/APEN Cancellation Request— Form APCD-107 — Engine —AIRS 123-A037-015 Emissions Permit/APEN Cancellation Request — Form APCD-107 — Engine — AIRS 123-A037-016 Emissions Permit/APEN Cancellation Request— Form APCD-107 — Engine —AIRS 123-A037-017 Emissions Permit/APEN Cancellation Request — Form APCD-107 — Engine — AIRS 123-A037-018 Emissions Permit/APEN Cancellation Request — Form APCD-107 — Engine — AIRS 123-A037-019 Page 4 of 101 CDPHE' Condensate Storage Tank(s) APEN Form APCD-205 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. 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 condensate associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website. 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: 19WE0334 AIRS ID Number: 123 / A037 / 001 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Crestone Peak Resources Operating, LLC Site Name: Regnier Farms 19H -B268 Battery Site Location: SWSE Section 18 T2N R68W and NWNE Section 19 T2N R68W Mailing Address: (Include Zip Code) 10188 East I-25 Frontage Road Firestone, CO 80504 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Phone Number: E -Mail Address2: Sabrina Pryor (303) 774-3923 sabrina.pryor@crestonepr.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-205 - Condensate Storage Tank(s) APEN Revision 07/2020 1 , a COLORADO Department of Public ms Hea lth Envitonment Page 5 of 101 Permit Number: 19WE0334 AIRS ID Number: 123 /A037/001 [Leave blank unless APCD has already assigned a permit # and AIRS ID; Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source ❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP01 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $353.13 must be submitted along with the APEN filing fee. OR ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name3 O Change permit limit ❑ Transfer of ownership4 ❑ 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 Et Notes: Providing revised throughput and a site -specific emission factor. 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-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Condensate storage tanks Company equipment Identification No. (optional): TANKS For existing sources, operation began on: 02/23/2020 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 hours/day 7 days/week 52 Storage tank(s) located at: weeks/year ❑✓ Exploration Et Production (EftP) site ❑ Midstream or Downstream (non EftP) site Will this equipment be operated in any NAAQS nonattainment area? O Yes ■ No Are Flash Emissions anticipated from these storage tanks? SI Yes ■ No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? p Yes ■ No If "yes", identify the stock tank gas -to -oil ratio: 0.0009 m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No 0 ■ Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No ■ p Form APCD-205 Condensate Storage Tank(s) APEN - Revision 07/2020 yy�!��►. (COLORADO Henn.. Environment Page 6 of 101 ❑ Upward ❑ Horizontal Permit Number: 19WE0334 AIRS ID Number: 123 /A037/001 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/year) Requested Annual Permit Limits (bbl/year) Condensate Throughput: -- 1,277,500 From what year is the actual annual amount? N/A Average API gravity of sales oil: 48.2 degrees ❑ Internal floating roof Tank design: ❑✓ Fixed roof RVP of sales oil: 7.8 ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of first Production (month/year) TANKS 8 6,000 02/2020 02/2020 Wells Serviced by this Storage Tank or Tank Battery6 (E&P Sites On y) API Number Name of Well Newly Reported Well 05 - 123 - 44943 Regnier Farms 1A -19H -B268 ■ 05 - 123 - 44947 Regnier Farms 1B -19H -B268 ■ 05 - 123 - 44938 Regnier Farms 1C -19H -B268 ■ 05 - 123 - 44942 Regnier Farms 1D -19H -B268 • 05 - 123 - 44940 Regnier Farms 1E -19H -B268 ■ 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. 6 The EP 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 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.131197; -105.043308 ❑✓ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack ID No. Discharge Height. Above Ground Level (Feet) Temp. (°F) Flow Rate (AEFM) Velocity (ft/sec) , Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular ❑ Square/rectangle ❑ Other (describe): Interior stack diameter (inches): Interior stack width (inches): ❑ Upward with obstructing raincap Interior stack depth (inches): Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2020 3 (COLORADO Departmental Public xeatm b EMonmone Page 7 of 101 Permit Number: 19WE0334 AIRS ID Number: 123 /A037/ 001 [Leave blank unless APCD has already assigned a permit tt and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section . Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: ❑ Combustion Device: Pollutants Controlled: VOCs, HAPs Rating: NA MMBtu/hr Type: Enclosed Combustor Make/Model: Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: Minimum Temperature: NA 98 NA Waste Gas Heat Content: Constant Pilot Light: ❑✓ Yes ❑ No Pilot Burner Rating: 2,838 0.025 Btu /scf MMBtu / hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: % Section 7 - Gas/Liquids Separation Technology Information (EttP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 2 psig Describe the separation process between the well and the storage tanks: Wellhead production to high -low pressure three-phase separator, high-pressure gas to sales, low-pressure gas to sales through VRU or enclosed combustor during VRU downtime. Bulk condensate from separators to VRT and then to storage tanks battery. Produced water to storage tank battery. Form APCD-205 Condensate Storage Tank(s) APEN - Revision 07/2020 jee COLORADO 4 ; e°`� f a;.".a m. Page 8 of 101 Benzene VOC VOC Permit Number: 19WE0334 AIRS ID Number: 123 /A037/001 [Lea -Ye blank unless APCD has already assigned a permit and A RS IDj Section 8 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the requested control efficiencies (report the overall, or combined, values if multiple emission control methods were identified in Section 6): Overall Requested_ Control Efficiency (1reduction in emissions) Enclosed Combustor (ECD) 95 NOx CO HAPs Enclosed Combustor (ECD) 95% Other: From what year is the following reported actual annual emissions data? NIA Use the following table to report the criteria pollutant emissions from source: mission Factor/ Actual Annual Emissions Requested Annual Permit ;Emission Limit(s)5 ncontrolled ass lb/bbl Source (AP -42, Mfg.; etc.) Uncontrolled Emissions (tons/year) Controlled Emissions. Mons/year):, Uncontrolled Emissions (fionsiyear) Controlled Emissions (tonslyyear) 0.5793 Site Specific 370 18.50 NO,, CO 0.068 Ib/MMBtu AP -42 0.66 0.31 Ib/MMBtu AP -42 2.99 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. 7 Attach condensate liquid 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 emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Section 9 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑� Yes ❑ No Chemical Abstract Service (CAS) Number Emission Factor Actual Annua l Emissions ncontrolled Basis lb/bbl Source Mfg., etc ), Uncontrolled �.,Emissions -- �� :(Ibslyear) Controlled Emissions (lbsiyeOr) 71432 9.12E-04 Site Specific 1,165 58.23 Toluene 108883 8.84E-04 lb/bbl Site Specific 1,129 56.44 Ethylbenzene Xylene n -Hexane 100414 4.04E-05 lb/bbl Site Specific 51.59 2.58 1330207 2.98E-04 lb/bbl Site Specific 381 19.06 110543 8.83E-03 lb/bbl Site Specific 11,284 564 2, 2,4-Trimethylpentane 540841 1.59E-05 lb/bbl Site Specific 20.35 1.02 7 Attach condensate liquid 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 emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Form APCD-205 Condensate Storage Tank(s) APEN - Revision 07/2020 COLORADO E6oatV�b E11MIO mmi Page 9 of 101 Permit Number: 19WE0334 AIRS ID Number: 123 /A037/001 [Leave blank unless APCD has already assigned a permit # and AIRS ID; Section 10 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. � �.L:r c" ` t, i � � 12/03/2020 Signature of Legally Authorized Person (not a vendor or consultant) Date Sabrina M. Pryor Air Quality Engineer Name (print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance ❑r 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 $216.00 and the General For more information or assistance call: Permit registration fee of $353.13, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Small Business Assistance Program (303)692-3175 OR (303)692-3148 APCD Main Phone Number (303)692-3150 Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2020 ailibCOLORADO 6 /\i/ l xisa monment Page 10 of 101 E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Forml Company Name: Crestone Peak Resources Operating, LLC Source Name: Regnier Farms 19H -B268 Condensate Tanks Emissions Source AIRS ID2: 123 / A037 / 001 Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 — 44945 Regnier Farms 1F -19H -B268 ❑ 05 - 123 - 44941 Regnier Farms 1G -19H -B268 ❑ 05 - 123 - 44944 Regnier Farms 1H -19H -B268 ❑ 05 - 123 - 44937 Regnier Farms 1I -19H -B268 ❑ 05 - 123 - 44946 Regnier Farms 1J -19H -B268 ❑ 05 - 123 - 44936 Regnier Farms 1K -19H -B268 ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ Footnotes: 1 Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 Bl.b.-APEN FORM 212 - Wellsite Addendum Page 11 of 101 Produced Water Storage Tank(s) APEN Form APCD-207 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. 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 produced water associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, condensate storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website. 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: 19WE0334 AIRS ID Number: 123 / A037 / 002 [Leave blank unless APCD has aready assigned a permit i and AIRS ID] Section 1 - Administrative Information Company Name: Site Name: Crestone Peak Resources Operating, LLC Regnier Farms 19H -B268 Battery Site Location: SWSE Section 18 T2N R68W and NWNE Section 19 T2N R68W Mailing Address: (Include Zip Code) 10188 East I-25 Frontage Road Firestone, CO 80504 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Phone Number: E -Mail Addressz: Sabrina Pryor (303) 774-3923 sabrina.pryor@crestonepr.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2020 ��//��►► COLORADO xwu, s=oomene Page 12 of 101 Permit Number: 19WE0334 AIRS ID Number: 123 /A037/002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source ❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP05 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $353.13 must be submitted along with the APEN filing fee. OR ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company 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 a Notes: Providing a revised site -specific emission factor. 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: Company equipment Identification No. (optional): For existing sources, operation began on: Produced Water PW 02/23/2020 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 hours/day 7 days/week Storage tank(s) located at: ❑✓ Exploration 8 Production (EftP) site 52 weeks/year ❑ Midstream or Downstream (non EftP) site Will this equipment be operated in any NAAQS nonattainment area? Yes No 12 ■ Are Flash Emissions anticipated from these storage tanks? Yes No GI ■ Are these storage tanks located at a commercial facility that accepts oil production wastewater for processing? Yes No ■ p Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? Yes No ■ GI Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No O ■ Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No ■ p Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2020 COLORADO zDepartment at Mee. 1Heater Environment Page 13 of 101 Permit Number: 19WE0334 AIRS ID Number: 123 /A037/002 [Leave blank unless APCD has already assigned a permit y and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/year) Requested Annual Permit Limits (bbUyear) Produced Water Throughput: -- 730,000 From what year is the actual annual amount? Tank design: ❑✓ Fixed roof N/A ❑ Internal floating roof ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank, Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) PW 2 1,500 02/2020 02/2020 Wells Serviced by this Storage Tank or Tank Battery° (E&P Sites On y) API Number! Name of Well Newly Reported Well 05 - 123 - 44943 Regnier Farms 1A -19H -B268 ■ 05 - 123 - 44947 Regnier Farms 1B -19H -B268 ■ 05 - 123 - 44938 Regnier Farms 1C -19H -B268 ■ 05 - 123 - 44942 Regnier Farms 1D -19H -B268 ■ 05 - 123 - 44940 Regnier Farms 1E -19H -B268 ■ 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. •6 The E&P 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 - Geographical/Stack Information Geographical Coordinates' (Latitude/Longitude or UTM) 40.131197; -105.043308 ❑✓ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp,. (°F); Flow Rate (ACFM) Velocity (ft/sec) Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular ❑ Square/rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack width (inches): Interior stack depth (inches): Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2020 3 IGOLORADO = v o '>Ma�e Page 14 of 101 Permit Number: 19WE0334 AIRS ID Number: 123 /A037/OO2 [Leave blank unless APCD has already assigned a permit 11 and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: ❑ Combustion Device: Pollutants Controlled: VOCS, HAPs Rating: NA MMBtu/hr Type: Enclosed Combustor Make/Model: Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 % Minimum Temperature: NA NA Waste Gas Heat Content: Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating: 2,838 0.025 Btu/scf MMBtu / hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 - Gas/Liquids Separation Technology Information (E£tP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 50 psig Describe the separation process between the welt and the storage tanks: Wellhead production to high -low pressure three-phase separator, high-pressure gas to sales, low-pressure gas to sales through VRU or enclosed combustor during VRU downtime. Bulk condensate from separators to VRT and then to storage tanks battery. Produced water to storage tank battery. Form APCD-207 Produced Water Storage Tank(s) APEN - Revision 07/2020 4 COLORADO newKmenead Public Health EtEn..enmene Page 15 of 101 Permit Number: 1 gWE0334 AIRS ID Number: 123 /A037/002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form7. Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑ No If yes, describe the control equipment AND state the requested control efficiencies (report the overall, or combined, values if multiple emission control methods were identified in Section 6): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) VOC Enclosed Combustor (ECD) 95% NOx CO HAPs Enclosed Combustor (ECD) 95% Other: From what year is the following reported actual annual emissions data? N/A Use the following table to report the criteria pollutant emissions from source: Pollutant Emission Factor7 Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissions$ (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) VOC 0.0182 lb/bbl Site Specific -- -- 6.65 0.33 NO. 0.068 Ib/MMBtu AP -42 — 1.18E-02 CO 0.31 Ib/MMBtu AP -42 5.39E-02 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. 7 Attach produced water laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Section 9 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name Chemical Abstract Service (CAS) Number Emission'Factor7 Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (lbs)year) Controlled Emissions $ (tbs/year) Benzene 71432 4.32E-04 lb/bbl Site Specific 315 15.77 Toluene 108883 3.53E-04 lb/bbl Site Specific 257 12.87 Ethylbenzene 100414 1.26E-05 lb/bbl Site Specific 9.19 0.46 Xylene 1330207 8.81E-05 lb/bbl Site Specific 64.28 3.21 n -Hexane 110543 8.34E-04 lb/bbl Site Specific 609 30.46 2,2,4-Trimethylpentane 540841 lb/bbl Site Specific -- ❑✓ Yes ❑ No 7 Attach produced water laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Form APCD-207 - Produced Water Storage Tank(s) ADEN - Revision 07/2020 5 Page 16 of 101 Permit Number: 19WE0334 AIRS ID Number: 123 /A037/002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 10 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP05 or GP08, I further certify that this source is acid will be operated in full compliance with each condition of the applicable General Permit. l \, 12/03/2020 Signature of Legally Authorized Person (not a vendor or consultant) Date Sabrina M. Pryor Air Quality Engineer Name (print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $216.00 and the General For more information or assistance call: Permit registration fee of $353.13, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-61 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Small Business Assistance Program (303)692-3175 OR (303)692-3148 APCD Main Phone Number (303)692-3150 COLORADO Form APCD-2O7 Produced Water Storage Tank(s) APEN - Revision 07/2020 6 I Page 17 of 101 E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Forml Company Name: Crestone Peak Resources Operating, LLC Source Name: Regnier Farms 19H -B268 Produced Water Tanks Emissions Source AIRS ID2: 123 / A037 / 002 Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 — 44945 Regnier Farms 1F -19H -B268 ❑ 05 - 123 - 44941 Regnier Farms 1G -19H -B268 ❑ 05 - 123 - 44944 Regnier Farms 1H -19H -B268 ❑ 05 - 123 - 44937 Regnier Farms 1I -19H -B268 ❑ 05 - 123 - 44946 Regnier Farms 1J -19H -B268 ❑ 05 - 123 - 44936 Regnier Farms 1K -19H -B268 ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ Footnotes: I Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 B2.b.-APEN FORM 212 - Wellsite Addendum Page 18 of 101 Hydrocarbon Liquid Loading APEN Form APCD-208 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. 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. 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: 19WE0334 AIRS ID Number: 123 / A037 /003 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Crestone Peak Resources Operating, LLC Site Name: Regnier Farms 19H -B268 Battery Site Location: SWSE Section 18 T2N R68W and NWNE Section 19 T2N R68W Mailing Address: (Include Zip Code) 10188 East I-25 Frontage Road Firestone, CO 80504 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Phone Number: E -Mail Addressz: Sabrina Pryor (303) 774-3923 sabrina.pryor@crestonepr.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the. APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 07/2020 ,lag COLORADO Department <4Pula Health b Enebonmene Page 19 of 101 Permit Number: 19WE0334 AIRS ID Number: 123 /A037/003 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source ❑ Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $353.13 must be submitted along with the APEN filing fee. -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑✓ Change permit limit ❑ Transfer of ownership4 ❑ 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 & Notes: Providing revised throughput and a site -specific emission factor. 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-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Truck loadout of condensate from tanks Company equipment Identification No. (optional): LOAD -1 For existing sources, operation began on: 02/23/2020 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? Yes No O ■ Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Yes No ■ D Does this source load gasoline into transport vehicles? Yes No ■ GI Is this source located at an oil and gas exploration and production site? Yes No I9 ■ If yes: Does this source load less than 10,000 gallons of crude oil per day on an annualSI average? Yes No ■ Does this source splash fill less than 6,750 bbl of condensate per year? Yes No GI ■ Does this source submerge fill less than 16,308 bbl of condensate per year? Yes No ■ l7 Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 07/2020 21 giSICOII.ORADO Hall. D EnCt Publk annen I Department a en uanmme Page 20 of 101 ❑ Upward ❑ Horizontal Permit Number: 19WE0334 AIRS ID Number: 123 /A037/003 iL eave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: ❑✓ Condensate ❑ Crude Oil ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: 1,277,500 bbl/year Actual Volume Loaded: This product is loaded from tanks at this facility into: Tank Trucks (e.g. "rail tank cars" or "tank trucks") bbl/year If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: 0.60 Average temperature of bulk liquid loading: 64.48 °F True Vapor Pressure: 4,.00 Psia @ 60 °F Molecular weight of displaced vapors: 50.34 lb/lb mol 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 or will be evaluated for exempt status, as applicable, and should consider future. process growth. Requested values are required on all APENs, including APEN updates. Section 5 - Geographical/Stack Information Geographical Coordinates' (Latitude/Longitude or UTM) 40.131197; -105.043308 ❑✓ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. btZer for iakiD No >_, Discharge leg. i bo;01 tzCt�u)iti es l`lov�i[�at Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular ❑ Square/rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack width (inches): Interior stack depth (inches): Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 07/2020 COLORADO 3 I Deparan Page 21 of 101 Permit Number: 19WE0334 AIRS ID Number: 123 /A037/003 [Leave blank unless APCD has already assigned a permit R and AIRS ID Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. ❑ Loading occurs using a vapor balance system: Requested Control Efficiency: ❑ Combustion Device: Used for control of: vocs, HAPs Rating: NA MMBtu/hr Type: Enclosed Combustor Make/Model: NA Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: NA ° F Waste Gas Heat Content: 2,838 Btu/scf Constant Pilot Light: ❑✓ Yes ❑ No Pilot Burner Rating: 0.025 MMBtu/hr ❑ Other: Pollutants Controlled: Description: Requested Control Efficiency: Section 7 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the requested control efficiencies (report the overall, or combined, values if multiple emission control methods were identified in Section 6): PoiCutant Control Equipment Description Overall Requester) Control Efficiency (% reduction in emissions) PM SOX NO„ CO VOC Enclosed Combustor (ECD) 95% HAPs Enclosed Combustor (ECD) 95% Other: ❑ 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? _ N/A Use the following table to report the criteria pollutant emissions from source: Pollutant PM EmissionFactor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled'' Basis Ib/M M Btu Source (AP -42, Mfg., etc.); Uncontrolled Emissions (tons/year) Controlled Emissionsb (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions ;(tonslyear) SOX NO), CO 0.068 AP -42 0.14 0.31 Ib/MMBtu AP -42 0.62 VOC 0.121 lb/bbl AP -42 77.05 3.85 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 07/2020 4 [COLORADO ,a=pnea HR*1140 vimn _ a Page 22 of 101 Permit Number: 19WE0334 AIRS ID Number: 123 /A037/003 [Leave blank unless APCD has already assigned a permit N and AIRS ID] Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? 0 Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name Chemical : Abstract Service (CAS) Number ' Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (Ibslyear) '�Controlled Emissions6 abslyear) Benzene 71432 1.90E-04 lb/bbl AP -42 242 12.12 Toluene 108883 1.84E-04 lb/bbl AP -42 235 11.75 Ethylbenzene 100414 8.41E-06 lb/bbl AP -42 10.74 0.54 Xylene 1330207 6.21E-05 lb/bbl AP -42 79.36 3.97 n -Hexane 110543 1.84E-03 lb/bbl AP -42 2,350 117 2,2,4-Trimethylpentane 540841 3.32E-06 lb/bbl AP -42 4.24 0.21 Other: 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. 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 GP07, I further certify that this source is and wilt be gperated in full compliance with each condition of General Permit GP07. 12/03/2020 Signature of Legally Authorized Person (not a vendor or consultant) Date Sabrina M. Pryor Air Quality Engineer Name (print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $216.00 and the General For more information or assistance call: Permit registration fee of $353.13, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Small Business Assistance Program (303)692-3175 OR (303)692-3148 APCD Main Phone Number (303)692-3150 Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 07/2020 5 [COLORADO DePartmen:atP ttic Ifeslth 6 Cnvuonrtcrnt Page 23 of 101 Gas Venting APEN - Form APCD-211 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. 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 locks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, 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. 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: 19WE0334 AIRS ID Number: 123 /A037 /004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Crestone Peak Resources Operating, LLC Site Name: Site Location: Regnier Farms 19H -B268 Battery SWSE Section 18 T2N R68W and NWNE Section 19 T2N R68W Mailing Address: 10188 East I-25 Fronts a Road (Include Zip Code) g Firestone, CO 80504 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Sabrina Pryor Phone Number: (303) 774-3923 E -Mail Addressz: sabrina.pryor@crestonepr.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-211 - Gas Venting APEN - Revision 07/2020 Arl iCOLORADO 1 I Depatrm.nr«w6l6 MP H WM 6 Emermm. Page 24 of 101 Permit Number: 19WE0334 AIRS ID Number: 123 / ao37 / 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) - OR ▪ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info It Notes: Providing revised throughput and a site -specific emission factor. 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-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Low -Pressure separator emissions during VRU downtime controlled by enclosed combustor. Company equipment Identification No. (optional): For existing sources, operation began on: Buffer 02/23/2020 For new, modified, or reconstructed sources, the projected start-up date is: ID Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area? Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions? Is this equipment subject to Colorado Regulation No. 7, Section XVII.G? Form APCD-211 - Gas Venting APEN - Revision 07/2020 days/week weeks/year ❑✓ Yes ❑ Yes ❑✓ Yes ❑ No ❑✓ No ❑ No geCOLORADO 2 I 'Ikp"ter"mdPublic Him. 6 environment Page 25 of 101 Permit Number: 19WE0334 AIRS ID Number: 123 /A037/004 [Leave blank unless APCD has already assigned a permit x and AIRS ID] Section 4 - Process Equipment Information ❑� Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: ❑ Other Description: Serial #: Capacity: gal/min # of Pistons: Leak Rate: Scf/hr/pist Volume per event: MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑✓ Yes Gas Venting Process Parameters5: Liquid Throughput Process Parameters 5: Vented Gas Properties: ❑ No Vent Gas Heating Value: 2 781 BTU/SCF Requested: 6.30 MMSCF/year Actual: __ MMSCF/year -OR- Requested: bbl/year Actual: __ bbl/year Molecular Weight: 48.4522 VOC (weight %) 85.1324 Benzene (Weight %) 0.2251 Toluene (Weight %) 0.1944 Ethylbenzene (Weight %) 0.0068 Xylene (Weight %) 0.0540 n -Hexane (Weight %) 2,3675 2,2,4-Trimethylpentane (Weight %) 0.0010 Additional Required Documentation: ❑✓ Attach a representative gas analysis (including BTEX £t n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX £t n -Hexane, temperature, and pressure) 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. Form APCD-211 Gas Venting APEN - Revision 07/2020 Page 26 of 101 3 I CC[COLORADO ratinten� a wa�c i H�6�� Permit Number: 1 9 y y E0334 AIRS ID Number: 123 / A037 / 004 [Leave. dank unless APCD has already assigned a permit and AIRS ID] Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.131197; -105.043308 O Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack [l? No l7ascharg Height Aiavee deel 7 em p { Fiov� Rateeloctty CfM ift/sec} Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular ❑ Square/rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack width (inches): Interior stack depth (inches): 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. ❑ VRU: Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed: Make/Model: ❑ Combustion Device: Pollutants Controlled: VOCs, HAPs Rating: NSA MMBtu/hr Type: Enclosed Combustor Make/Model: N/A Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 95 Minimum Temperature: NSA Waste Gas Heat Content: Constant Pilot Light: ❑✓ Yes ❑ No Pilot, burner Rating: 2,781 0.025 Btu/scf MMBtu/hr Other: Pollutants Controlled: Description: Requested Control Efficiency: Form APCD-211 Gas Venting ADEN - Revision 07/2020 4I COLORADO llep.zfent of Public xeai,aenrivaneenl Page 27 of 101 Permit Number: 19 9WE0334 E0334 AIRS ID Number: 123 /A037/ 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the requested control efficiencies (report the overall, or combined, values if multiple emission control methods were identified in Section 6): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SOX NO. CO VOC Enclosed Combustor 95 HAPs Enclosed Combustor 95 Other: From what year is the following reported actual annual emissions data? N/A Use the following table to report the criteria pollutant emissions from source: Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (AP 42, Mfg., etc.) Uncontrolled Emissions (tons/year), Controlled Emissions° (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/Year) PM SOx NOx 0.068 Ib/MMBtu AP -42 -- 0.60 CO 0.31 Ib/MMBtu AP -42 2.72 VOC 108,835 Ib/MMscf Site specific 343 17.14 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg,, etc. Uncontrolled Emissions tbs/ ear ( Y ) Controlled Emissions° abs/year) Benzene 71432 288 Ib/MMscf Site specific 1,813 90.65 Toluene 108883 248 Ib/MMscf Site specific 1,566 78.28 Ethylbenzene 100414 8.71 Ib/MMscf Site specific 54.90 2.74 Xylene 1330207 69.08 Ib/MMscf Site specific 435 21.76 n -Hexane 110543 3,027 Ib/MMscf Site specific 19,068 953 2,2,4-Trimethylpentane 540841 129 Ib/MMscf Site specific 8.12 0.41 Other: ❑✓ Yes ❑ No 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Form APCD-211 - Gas Venting APEN - Revision 07/2020 Page 28 of 101 5I ORAu® ;t rwaic ummment Permit Number: 1 9WE0334 AIRS ID Number: 123 /A037/004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. 12/03/2020 Signature of Legally Authorized Person (not a vendor or consultant) Date Sabrina M. Pryor Air Quality Engineer Name (print) Title Check the appropriate box to request a copy of the: ✓� Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $216.00 to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 OR (303) 692-3148 APCD Main Phone Number Make check payable to: (303) 692-3150 Colorado Department of Public Health and Environment Form APCD-211 - Gas Venting APEN - Revision 07/2020 6 icaLoeauo Department mPutlic Healfh 6 Bm3santnarte Page 29 of 101 Emissions Permit/APEN Cancellation Request - Form APCD-107 Air Pollution Control Division Stationary Sources Program All sections of this Emissions Permit/APEN Cancellation Request must be completed for any request to cancel an Emissions Permit or APEN and submitted to the Colorado Department of Public Health and Environment's Air Pollution Control Division (APCD). A cancellation request with missing information may be determined incomplete and may be returned or result in a longer cancellation processing time. Section 1 - Administrative Information Please note, specific facility information needed for this section can be found on your facility's emissions permit on the bottom left corner of each page, in the facility's emissions permit equipment description(s), or on your most recent Annual Emission Fee Invoice. AIRS ID(s): Equipment Description: Owner or Operator of Permit: Facility or Equipment Address: 123-A037-014 Permit Number(s): 19WE0347.XP Compression Engine (Comp -9), Make: Compressco, Model: GJ230, S/N: TBD Crestone Peak Resources Operating, LLC Regnier Farms 19H -B268 Battery SWSE Section 18 T2N R68W and NWNE Section 19 T2N R68W Permit Contact: Sabrina Pryor Mailing Address: 10188 East 125 Frontage Road Firestone, CO 80504 Phone Number: (303) 774-3923 Email Address: Date Facility or Equipment Ceased or Went Below Reporting Thresholds: 11 / 30 / 2020 Section 2 - Reason for Emissions Permit/APEN Cancellation ✓❑ The facility or equipment addressed by the permit or APEN no longer exists. The facility or equipment has been sold to another party and I do not wish to transfer the permit. The facility or equipment has dropped below reporting thresholds. The permit was previously required solely because the emissions unit was subject to NSPS or MACT/NESHAP requirements that were adopted into Colorado Regulations (see PS Memo 14-01 for more info). This cancellation request is for (check appropriate box): ❑ Permit Only (The unit is still active. The permit will be cancelled, but the APEN will remain active because emissions are above APEN- reporting thresholds. The emissions unit is now subject to one of the general exemption letters found on the following page of the APCD website: https: //www.colorado.Qov/pacific/cdphe/air-permitting-cancellation-exempt-sources) ❑ Permit Et APEN (Both the permit and the APEN will be cancelled. The unit is still active, but emissions are below APEN-reporting thresholds.) Please review the information on the following page of the APCD website before selecting this option: https: / /www.colorado.gov/pacific/cdphe/air-permitting-cancellation-exempt-sources Section 3 - Owner or Operator Certification I have reviewed this cancellation request in its entirety and I hereby certify that all information contained herein is true, accurate, and _.._plot. C � 1.-(1 - 'l 12/03/2020 Signature of Legally Authorized Person (not a vendor or consultant) Date Sabrina Pryor Name (please print) Air Quality Engineer Title Send completed form to: CDPHE - Air Pollution Control Division APCD-SS-61 4300 Cherry Creek Drive South Denver, CO 80246-1530 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/pacific/cdphe/apcd Form APCD-107 - Cancellation Request - Revision 02/2017 Page 30 of 101 COLORADO 1 I �� f,„V era �„nmt, Emissions Permit/APEN Cancellation Request - Form APCD-107 Air Pollution Control Division Stationary Sources Program All sections of this Emissions Permit/APEN Cancellation Request must be completed for any request to cancel an Emissions Permit or APEN and submitted to the Colorado Department of Public Health and Environment's Air Pollution Control Division (APCD). A cancellation request with missing information may be determined incomplete and may be returned or result in a longer cancellation processing time. Section 1 - Administrative Information Please note, specific facility information needed for this section can be found on your facility's emissions permit on the bottom left corner of each page, in the facility's emissions permit equipment description(s), or on your most recent Annual Emission Fee Invoice. AIRS ID(s): 123-A037-015 Permit Number(s): 19WE0348.XP Equipment Description: Owner or Operator of Permit: Facility or Equipment Address: Compression Engine (Comp -10), Make: Compressco, Model: GJ230, S/N: TBD Crestone Peak Resources Operating, LLC Regnier Farms 19H -B268 Battery SWSE Section 18 T2N R68W and NWNE Section 19 T2N R68W Permit Contact: Sabrina Pryor Mailing Address: 10188 East 125 Frontage Road Firestone, CO 80504 Phone Number: (303) 774-3923 Email Address: Date Facility or Equipment Ceased or Went Below Reporting Thresholds: 11 / 30 / 2020 Section 2 - Reason for Emissions Permit/APEN Cancellation ❑� The facility or equipment addressed by the permit or APEN no longer exists. ❑ The facility or equipment has been sold to another party and I do not wish to transfer the permit. ❑ The facility or equipment has dropped below reporting thresholds. ❑ ' The permit was previously required solely because the emissions unit was subject to NSPS or MACT/NESHAP requirements that were adopted into Colorado Regulations (see PS Memo 14-01 for more info). This cancellation request is for (check appropriate box): ❑ Permit Only (The unit is still active. The permit will be cancelled, but the APEN will remain active because emissions are above APEN- reporting thresholds. The emissions unit is now subject to one of the general exemption letters found on the following page of the APCD website: https: //www.colorado.gov/pacific/cdphe/air-permitting-cancellation-exempt-sources) ❑ Permit It APEN (Both the permit and the APEN will be cancelled. The unit is still active, but emissions are below APEN-reporting thresholds.) Please review the information on the following page of the APCD website before selecting this option: https: / /www.colorado.gov/pacific/cdphe/air-permitting-cancellation-exempt-sources Section 3 - Owner or Operator Certification I have reviewed this cancellation request in its entirety and I hereby certify that all information contained herein is true, accurate, and complete. i '' a 1 12/03/2020 Signature of Legally Authorized Person (not a vendor or consultant) Sabrina Pryor Name (please print) Date Air Quality Engineer Title Send completed form to: CDPHE - Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/pacific/cdphe/apcd Form APCD-107 - Cancellation Request - Revision 02/2017 Page 31 of 101 COLORADO „. Emissions Permit/APEN Cancellation Request - Form APCD-107 Air Pollution Control Division Stationary Sources Program All sections of this Emissions Permit/APEN Cancellation Request must be completed for any request to cancel an Emissions Permit or APEN and submitted to the Colorado Department of Public Health and Environment's Air Pollution Control Division (APCD). A cancellation request with missing information may be determined incomplete and may be returned or result in a longer cancellation processing time. Section 1 - Administrative Information Please note, specific facility information needed for this section can be found on your facility's emissions permit on the bottom left corner of each page, in the facility's emissions permit equipment description(s), or on your most recent Annual Emission Fee Invoice. AIRS ID(s): 123-A037-016 Permit Number(s): 20WE0324.XP Equipment Description: Owner or Operator of Permit: Facility or Equipment Address: COMPRESSCO GJ230 INTERNAL COMBUSTION ENGINE (COMP -11) SN: TBD Crestone Peak Resources Operating, LLC Regnier Farms 19H -B268 Battery SWSE Section 18 T2N R68W and NWNE Section 19 T2N R68W Permit Contact: Sabrina Pryor Mailing Address: 10188 East 125 Frontage Road Firestone, CO 80504 Phone Number: (303) 774-3923 Email Address: Date Facility or Equipment Ceased or Went Below Reporting Thresholds: 11 / 30 / 2020 Section 2 - Reason for Emissions Permit/APEN Cancellation ❑� The facility or equipment addressed by the permit or APEN no longer exists. ❑ The facility or equipment has been sold to another party and 1 do not wish to transfer the permit. ❑ The facility or equipment has dropped below reporting thresholds. ❑i The permit was previously required solely because the emissions unit was subject to NSPS or MACT/NESHAP requirements that were adopted into Colorado Regulations (see PS Memo 14-01 for more info). This cancellation request is for (check appropriate box): ❑ Permit Only (The unit is still active. The permit will be cancelled, but the APEN will remain active because emissions are above APEN- reporting thresholds. The emissions unit is now subject to one of the general exemption letters found on the following page of the APCD website: https: //www.colorado.gov/pacific/cdphe/air-permitting-cancellation-exempt-sources) ❑ Permit Et APEN (Both the permit and the APEN will be cancelled. The unit is still active, but emissions are below APEN-reporting thresholds.) Please review the information on the following page of the APCD website before selecting this option: https: //www.colorado.gov/pacific/cdphe/air-permitting-cancellation-exempt-sources Section 3 - Owner or Operator Certification I have reviewed this cancgllation request in its entirety and I hereby certify that all information contained herein is true, accurate, and complete. C\ � r' 12/03/2020 Signature of Legally Authorized Person (not a vendor or consultant) Date Sabrina Pryor Name (please print) Air Quality Engineer Title Send completed form to: CDPHE - Air Pollution Control Division APCD-SS-61 4300 Cherry Creek Drive South Denver, CO 80246-1530 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/pacific/cdphetapcd Form APCD-107 - Cancellation Request - Revision 02/2017 Page 32 of 101 1i 1ryy: COLORADO Orcaum.nt ',`.°ri, Emissions Permit/APEN Cancellation Request - Form APCD-107 Air Pollution Control Division Stationary Sources Program All sections of this Emissions Permit/APEN Cancellation Request must be completed for any request to cancel an Emissions Permit or APEN and submitted to the Colorado Department of Public Health and Environment's Air Pollution Control Division (APCD). A cancellation request with missing information may be determined incomplete and may be returned or result in a longer cancellation processing time. Section 1 - Administrative Information Please note, specific facility information needed for this section can be found on your facility's emissions permit on the bottom left corner of each page, in the facility's emissions permit equipment description(s), or on your most recent Annual Emission Fee Invoice. AIRS ID(s): 123-A037-017 Permit Number(s): 20WE0325.XP Equipment Description: COMPRESSCO GJ230 INTERNAL COMBUSTION ENGINE (COMP -12) SN: TBD Owner or Operator of Permit: Facility or Equipment Address: Crestone Peak Resources Operating, LLC Regnier Farms 19H -B268 Battery SWSE Section 18 T2N R68W and NWNE Section 19 T2N R68W Permit Contact: Sabrina Pryor Mailing Address: 10188 East 125 Frontage Road Firestone, CO 80504 Phone Number: (303) 774-3923 Email Address: Date Facility or Equipment Ceased or Went Below Reporting Thresholds: 11 / 30 / 2020 Section 2 - Reason for Emissions Permit/APEN Cancellation ❑r The facility or equipment addressed by the permit or APEN no longer exists. ❑ The facility or equipment has been sold to another party and I do not wish to transfer the permit. ❑ The facility or equipment has dropped below reporting thresholds. ❑i The permit was previously required solely because the emissions unit was subject to NSPS or MACT/NESHAP requirements that were adopted into Colorado Regulations (see PS Memo 14-01 for more info). This cancellation request is for (check appropriate box): ❑ Permit Only (The unit is still active. The permit will be cancelled, but the APEN will remain active because emissions are above APEN- reporting thresholds. The emissions unit is now subject to one of the general exemption letters found on the following page of the APCD website: https: / /www.colorado.gov/pacific/cdphe/air-permitting-cancellation-exempt-sources) ❑ Permit Et APEN (Both the permit and the APEN will be cancelled. The unit is still active, but emissions are below APEN-reporting thresholds.) Please review the information on the following page of the APCD website before selecting this option: https: / /www.cotorado.8ov/pacific/cdphe/air-permitting-cancellation-exempt-sources Section 3 - Owner or Operator Certification I have reviewed this cancellation request in its entirety and I hereby certify that all information contained herein is true, accurate, and complete. ' 1 ) ,,----‘r— C (, `,l. 41 y . X t �/ Signature of Legally Authorized Person (not a vendor or consultant) Sabrina Pryor Name (please print) 12/03/2020 Date Air Quality Engineer Title Send completed form to: CDPHE - Air Pollution Control Division APCD-55-61 4300 Cherry Creek Drive South Denver, CO 80246-1530 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.cotorado.gov/pacific/cdphe/apcd Form APCD-107 - Cancellation Request - Revision 02/2017 Page 33 of 101 ttc COLORADO K Emissions Permit/APEN Cancellation Request - Form APCD-107 Air Pollution Control Division Stationary Sources Program All sections of this Emissions Permit/APEN Cancellation Request must be completed for any request to cancel an Emissions Permit or APEN and submitted to the Colorado Department of Public Health and Environment's Air Pollution Control Division (APCD). A cancellation request with missing information may be determined incomplete and may be returned or result in a longer cancellation processing time. Section 1 - Administrative Information Please note, specific facility information needed for this section can be found on your facility's emissions permit on the bottom left corner of each page, in the facility's emissions permit equipment description(s), or on your most recent Annual Emission Fee Invoice. AIRS ID(s): 123-A037-018 Permit Number(s): 20WE0326.XP Equipment Description: COMPRESSCO GJ230 INTERNAL COMBUSTION ENGINE (COMP -13) SN: TBD Owner or Operator of Permit: Crestone Peak Resources Operating, LLC Facility or Equipment Address: Regnier Farms 19H -B268 Battery SWSE Section 18 T2N R68W and NWNE Section 19 T2N R68W Permit Contact: Sabrina Pryor Mailing Address: 10188 East 125 Frontage Road Firestone, CO 80504 Phone Number: (303) 774-3923 Email Address: Date Facility or Equipment Ceased or Went Below Reporting Thresholds: 11 / 30 / 2020 Section 2 - Reason for Emissions Permit/APEN Cancellation ❑✓ The facility or equipment addressed by the permit or APEN no longer exists. ❑ The facility or equipment has been sold to another party and 1 do not wish to transfer the permit. ❑ The facility or equipment has dropped below reporting thresholds. ❑' The permit was previously required solely because the emissions unit was subject to NSPS or MACT/NESHAP requirements that were adopted into Colorado Regulations (see PS Memo 14-01 for more info). This cancellation request is for (check appropriate box): ❑ Permit Only (The unit is still active. The permit will be cancelled, but the APEN will remain active because emissions are above APEN- reporting thresholds. The emissions unit is now subject to one of the general exemption letters found on the following page of the APCD website: https: / /www.colorado.aovfpacific/cdphe/air-permitting-canceltation-exempt-sources) ❑ Permit Et APEN (Both the permit and the APEN will be cancelled. The unit is still active, but emissions are below APEN-reporting thresholds.) Please review the information on the following page of the APCD website before selecting this option: https: / /www.colorado4ov/pacific/cdphe/air-permitting-cancellation-exempt-sources Section 3 - Owner or Operator Certification I have reviewed this cancellation request in its entirety and I hereby certify that all information contained herein is true, accurate, and complete. C /: 9 >e- -�/�%�r 12/03/2020 r Signature of Legally Authorized Person (not a vendor or consultant) Sabrina Pryor Name (please print) Date Air Quality Engineer Title Send completed form to: CDPHE - Air Pollution Control Division APCD-SS-61 4300 Cherry Creek Drive South Denver, CO 80246-1530 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/pacific/cdphe/apcd Form APCD-107 - Cancellation Request - Revision 02/2017 Page 34 of 101 11 P COLORADO Emissions Permit/APEN Cancellation Request - Form APCD-107 Air Pollution Control Division Stationary Sources Program All sections of this Emissions Permit/APEN Cancellation Request must be completed for any request to cancel an Emissions Permit or APEN and submitted to the Colorado Department of Public Health and Environment's Air Pollution Control Division (APCD). A cancellation request with missing information may be determined incomplete and may be returned or result in a longer cancellation processing time. Section 1 - Administrative Information Please note, specific facility information needed for this section can be found on your facility's emissions permit on the bottom left corner of each page, in the facility's emissions permit equipment description(s), or on your most recent Annual Emission Fee Invoice. AIRS ID(s): 123-A037-019 Permit Number(s): 20WE0335.XP Equipment Description: Owner or Operator of Permit: Facility or Equipment Address: COMPRESSCO GJ230 INTERNAL COMBUSTION ENGINE (ID: COMP -14) S/N: TBD Crestone Peak Resources Operating, LLC Regnier Farms 19H-8268 Battery SWSE Section 18 T2N R68W and NWNE Section 19 T2N R68W Permit Contact: Sabrina Pryor Mailing Address: 10188 East 125 Frontage Road Firestone, CO 80504 Phone Number: (303) 774-3923 Email Address: Date Facility or Equipment Ceased or Went Below Reporting Thresholds: 11 / 30 / 2020 Section 2 - Reason for Emissions Permit/APEN Cancellation ❑✓ The facility or equipment addressed by the permit or APEN no longer exists. ❑ The facility or equipment has been sold to another party and I do not wish to transfer the permit. ❑ The facility or equipment has dropped below reporting thresholds. ❑ i The permit was previously required solely because the emissions unit was subject to NSPS or MACT/NESHAP requirements that were adopted into Colorado Regulations (see PS Memo 14-01 for more info). This cancellation request is for (check appropriate box): ❑ Permit Only (The unit is still active. The permit will be cancelled, but the APEN will remain active because emissions are above APEN- reporting thresholds. The emissions unit is now subject to one of the general exemption letters found on the following page of the APCD website: https: / / www.colorado.gov/pacific/cdphe/air-permitting,-cancellation-exempt-sources) ❑ Permit Et APEN (Both the permit and the APEN will be cancelled. The unit is still active, but emissions are below APEN-reporting thresholds.) Please review the information on the following page of the APCD website before selecting this option: https: //www.colorado.gov/pacific/cdphe/air-permitting-cancellation-exempt-sources Section 3 - Owner or Operator Certification and complete. � r % n (/ j ar, / /l I have reviewed this cancellation request in its entirety and I hereby certify that all information contained herein is true, accurate, jf 12/03/2020 Signature of Legally Authorized Person (not a vendor or consultant) Sabrina Pryor Name (please print) Date Air Quality Engineer Title Send completed form to: CDPHE - Air Pollution Control Division APCD-SS-61 4300 Cherry Creek Drive South Denver, CO 80246-1530 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/pacific/cdphe/apcd Form APCD-107 - Cancellation Request - Revision 02/2017 Page 35 of 101 t� COLORADO Attachment C Emission Calculations and Supporting Documentation Page 36 of 101 Crestone Peak Resources Operating, LLC Condensate Storage Tanks - Detailed Emissions Calculations Equipment Information Facility: Regnier Farms 19H B268 Source ID: TANKS AIRS ID: 001 Potential operation: 8,760 hr/yr 1,277,500 bbl/yr Storage Tank Potential 8:' Tanks Throughput: 95% Control efficiency Combustion Source - Pilot Gas Fuel Heat Value: 1,000 Btu/scf Pilot Flow Rate: a 200 scf/hr Pilot Heat Input: 0.200 MMBtu/hr Pilot Potential Operation: 8,760 hr/yr Pilot Potential Fuel Usage: a 1.75 MMscf/yr 1752 MMBtu/yr a Pilot gas fuel usage is based on 8 ECD with a 25 scf/hr pilot Potential Emission Calculations Combustion Source - Waste Gas Flash Gas Ratio: 4.83 scf/bbl 0.0009 m3/L HC Vapor: 16.92 Mscf/day Flash Heat Value: 2,838 Btu/scf Pollutant Component E.F. Uncontrolled Emissions Controlled Emissions Source of Emission Factor wt% flb/bblla lb/yr ton/yr lb/yr ton/yr VOC 90.36% 0.5793 740,056 370 37,003 18.50 Promax Benzene 0.14%, 9.12E-04 1,165 0.58 58.23 2.91E-02 Eng Calc Toluene 0.14% 8.84E-04 1,129 0.56 56.44 2.82E-02 Eng Calc Ethylbenzene 0.01/0 4.04E-05 51.59 2.58E-02 2.58 1.29E-03 Eng Calc Xylene 0.05% 2.98E-04 381 0.19 19.06 9.53E-03 Eng Calc n -Hexane 1.38"/x, 8.83Ei-03 11,284 5.64 564 0.28 Eng Calc 2,2,4-TMP 0.00% 1.59E-05 20.35 1.02E-02 1.02 5.09E-04 Eng Calc Component wt% and VOC emission factor taken from representative Promax Model Enclosed Combustor Emissionsa Combustion Pollutant E.F. Uncontrolled Emissions Controlled Emissions Source of Emission Factor (lb/MMBtu) lb/yr ton/yr lb/yr ton/yr NOx 0.068 — -- 1,311 0.66 AP -42 Table 13.5-1 CO 0.31 — -- 5,975 2.99 AP -42 Table 13.5-2 a Control device emissions account for combustion of both pilot gas and waste gas Crestone Peak Resources Operating, LLC Page 37 of 101 12/3/2020 Crestone Peak Resources Operating, LLC Produced Water Storage Tanks - Detailed Emissions Calculations Equipment Information Facility: Regnier Farms 19H-8268 Source ID: PW AIRS ID: 002 Potential operation: 8,760 hr/yr 730,000 bbl/yr Produced Water Potential Throughput: 2 Tanks 950/0 Control efficiency Combustion Source - Pilot Gas' Fuel Heat Value: 1,000 Btu/scf Pilot Flow Rate: scf/hr Pilot Heat Input: 0.000 MMBtu/hr Pilot Potential Operation: 8,760 hr/yr Pilot Potential Fuel Usage: 0.00 MMscf/yr 0 MMBtu/yr a Pilot gas emissions are estimated with Condensate Storage Tanks. Flash Liberation Analysis - Emission Factor Calculations Gas Water Ratio 0.500 SCF flashed gas/bbl stock tank liquid Gas Molar Volume @60 F, 14.7 psi 379.3 scf/mol Gas Molecular Weight 33.47 Ib/lbmol VOC - Flash Liberation 1.71E-02 lb/bbl Workint3 and Breathins Loss - Emission Factor Calculations Total Emissions 406.74 Ibs/yr/tank TANKS 4.0.9d Throughput 15,330,000 gallons/yr/tank TANKS 4.0.9d VOC - W&B 0.0011 lb/bbl Storage Tank Emission Calculations Pollutant Component E.F. Uncontrolled Emissions Controlled Emissions Source of Emission Factor wt°/o (lb/bbl) Ib/yr ton/yr 16/yr ton/yr VOC 38.78'% 1.82E-02 13,305 6.65 665 0.33 Flash -Liberation EF Calc. Benzene 0.921 4.32E-04 315 0.16 15.77 7.88E-03 Flash -Liberation EF Calc. Toluene 0.75'0 3.53E-04 257 0.13 12.87 6.44E-03 Flash -Liberation EF Calc. Ethylbenzene 0.03')/6 1.26E-05 9.19 4.60E-03 0.46 2.30E-04 Flash -Liberation EF Calc. Xylene 0.19% 8.81E-05 64.28 3.21E-02 3.21 1.61E-03 Flash -Liberation EF Calc. n -Hexane 1.78% 8.34E-04 609 0.30 30.46 1.52E-02 Flash -Liberation EF Calc. 2,2,4-TMP 0.000 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 Flash -Liberation EF Calc. Component wt% and VOCemission factor taken from Flash Liberation Analysis Combustion Source - Waste Gas Molecular Weight: 50.34 Ib/Ib-mol Waste Gas Temperature: 64.48 deg F 524.15 deg R Waste Gas Pressure: 12.12 psia Waste Gas Heat Value: 2,838 Btu/scf Gas Constant: 10,73 scf-psia/lb-mol-deg R Enclosed Combustor Emissions' Combustion Pollutant E.F. Uncontrolled Emissions Controlled Emissions Source of Emission Factor (lb/MMBtu) Ib/yr ton/yr Ib/yr ton/yr NOx 0.068 -- 23.67 1.18E-02 AP -42 Table 13.5-1 CO 0.31 -- - 108 5.39E-02 AP -42 Table 13.5-2 Control device emissions account for combustion of both pilot gas and waste gas Flash Liberation Emission Factor Calculation: lb/bbl = Gas Water Ratio (scf/bbl) / Gas Molar Volume (scf/Ib-mol) * Gas Molecular Weight (lb / lb-mol)* Component wt% Crestone Peak Resources Operating, LLC Page 38 of 101 12/3/2020 Crestone Peak Resources Operating, LLC Truck Loadout of Condensate - Detailed Emissions Calculations Equipment Information Facility: Regnier Farms 19H -B268 Source ID: LOAD -1 AIRS ID: 003 Potential operation: 8,760Ihr/yr Truck Loadout Potential Throughput: 1,277,500 bbl/yr Control 95% efficiency Combustion Source - Pilot Gas' Fuel Heat Value: 1,000 Btu/scf Pilot Flow Rate: scf/hr Pilot Heat Input: 0.000 MMBtu/hr Pilot Potential Operation: 8,760 hr/yr Pilot Potential Fuel Usage: 0.00 MMscf/yr 0 MMBtu/yr a Pilot gas emissions are estimated wzth Condensate Storage Tanks. Site Specific Emission Factor Equation Loading Loss (16/1000 gal) _ (12.46*S*P*M)/ T (AP -42 Section S = Saturation Factor = dedicated normal service P = True Vapor Pressure of liquid loaded*, psia M = Molecular Weight of Vapors, lb/lb-mole T = Temp. of bulk liquid loaded, deg. R = (deg. F + 460) Potential Emission Calculations 5.2 (1/95)) where: Combustion Source - Waste Gas Molecular Weight: 50.34 Ib/lb-mol Waste Gas Temperature: 64.48 deg F 524.15 deg R Waste Gas Pressure: 12.12 psia Waste Gas Heat Value: 2,838 Btu/scf Gas Constant: 10.73 scf-psia/lb- mol-deg R 0.60 AP -42: Section 5.2, Table 5.2-1 4.00 psia Permit Notes 50.34 lb/lb-mol Promax Model 524.15 deg R Promax Model 2.87 lb/1000 gal 0.121 lb/bbl Pollutant Component Loading Loss Uncontrolled Emissions Controlled Emissions Source of Emission Factor wt% (lb/bbl) lb/yr ton/yr 16/yr ton/yr VOC 90.36% 0.121 154,100 77.05 7,705 3.85 AP -42 Section 5.2 Benzene 0.14% 1.90E-04 242 0.12 12.12 6.06E-03 AP -42 Section 5.2 Toluene 0.14%, 1.84E-04 235 0.12 11.75 5.88E-03 AP -42 Section 5.2 Ethylbenzene 0.01% 8.41E-06 10.74 5.37E-03 0.54 2.69E-04 AP -42 Section 5.2 Xylene 0.05%, 6.21E-05 79.36 3.97E-02 3.97 1.98E-03 AP -42 Section 5.2 n -Hexane 1.38% 1.84E-03 2,350 1.17 117 5.87E-02 AP -42 Section 5.2 2,2,4-TMP 0.00% 3.32E-06 4.24 2.12E-03 0.21 1.06E-04 AP -42 Section 5.2 Enclosed Combustor Emissions' Combustion Pollutant Emission Factor (Ib/MMBtu) Uncontrolled Emissions Controlled Emissions Source of Emission Factor lb/yr ton/yr Ib/yr ton/yr NOx 0.068 -- -- 274 0.14 AP -42 Table 13.5-1 CO 0.31 -- -- 1,250 0.62 AP -42 Table 13.5-2 Control device emissions account for combustion of both pilotgas and waste gas Crestone Peak Resources Operating, LLC Page 39 of 101 12/3/2020 Crestone Peak Resources Operating, LLC Low Pressure Gas Venting and Control - Detailed Emissions Calculations Equipment Information Facility: Regnier Farms 19H -B268 Source ID: Buffer AIRS ID: 004 Potential operation: 8,760 hr/yr Buffer Gas Potential Throughput: -- bbl/yr - Separator condensate throughput -- scf/bbl - Condensate Dash factor (Promax) 6.30 MMscf/yr - Waste Gas Throughput 95% Control efficiency Combustion Source - Pilot Gas a Fuel Heat Value: 1,000 Btu/scf Pilot Flow Rate: 0 scf/hr Pilot Heatlnput: 0.000 MMBtu/hr Pilot Potential Operation: 8,760 hr/yr Pilot Potential Fuel Usage: 0.00 MMscf/yr 0 MMBtu/yr Pilotgas emissions are estimated with Condensate Storage Tanks. Potential Gas Venting Emissions Pollutant Component E.F. Uncontrolled Emissions Controlled Emissions Source of Emission Factor wt% (Ib/MMscf) Ib/yr ton/yr Ib/yr ton/yr VOC 85.1324% 108,835 685,662 343 34,283 17.14 Eng Cale Benzene 0.2251/0 288 1,813 0.91 90.65 4.53E-02 Eng Calc Toluene 0.1944% 248 1,566 0.78 78.28 3.91E-02 Eng Calc Ethylbenzene 0.0068/0 8.71 54.90 2.74E-02 2.74 1.37E-03 Eng Calc Xylene 0.05540% 69.08 435 0.22 21.76 1.09E-02 Eng Calc n hexane 2.3675% 3,027 19,068 9.53 953 0.48 Eng Calc 2,2,4-TMP 0.0010% 1.29 8.12 4.06E-03 0.41 2.03E-04 Eng Calc Combustion Source - Waste Gas Molecular Weight: 48.45 lb /Ib-mol Waste Gas Heat Value: 2,781 Btu/scf Waste Gas Heat Input: 17,520 MMbtu/yr Enclosed Combustor Emissions' Combustion Pollutant Emission Factor (lb/MMBtu) Uncontrolled Emissions Controlled Emissions Source of Emission Factor 16/yr ton/yr lb/yr ton/yr NOx 0.068 -- 1,191 0.60 AP -42 Table 13.5-1 CO 0.31 5,431 2.72 AP -42 Table 13.5-2 Control device emissions account for combustion of both pilot gas and waste gas • Emission Calculations Uncontrolled VOC (Ib/yr) = Gas to Flare (MMscf/yr) *1,000,000 (scf/ MMscf) / 379 (scf/ lb-mol) * MW of Gas (lb / lb-mol) * wt% VOC Crestone Peak Resources Operating, LLC 12/3/2020 Page 40 of 101 Simulation Initiated on 11/18/2020 3:04:26 PM Regnier Farms 19H-8268_2 psig_SSOTEF_11.18.2020.pmx Page 1 of 1 Facility Operations Plant Schematic Client Name: Crestone Peak Resources Job: Site Specific Oil Tank Emissions Factor Estimate 2 psig _ Location: Reigner Farms 19H-6268 Flowsheet: Facility Operations Crestone Peak Resources Regnier Farms 19H -B268 Site Specific Oil Tank Emission Alliance Source Testing Analysis: Extended Natural Gas Liquids VRT Pressure at 2 psig 2 5/21/2020 Buffer 't Factor Gas - -► Buffer House c 'q Properties Oil Tank Vapors ".� 1 Molecular Weight(Totah I 50:34 I lb/Ibmol C 2 XCHG-100 1 Pressurized Liquid Sample LP Gas to Buffer Buffer Scrubber VRTGas--1r pump Oil tank flash gas-- . . 4 Oil Tank p rub:;-��-1-IPto LPi� ,i SAT -1 O-' . porsJ MIX -701 LP to VRT ► Buffer Gas Sample LP Separator / i � VRT .� O.{._. �„ Working & Breathing Oas Properties LP to VRT Oil to Tank Oil Storage Tanks Temperature( f ". -,MIX-102 Pressure(Total)e(Total) � 22 22" psig LLPJQ Properties Oil to Tanks Pressure(Totah 2' psig . Properties LP Oil Temperature(Totah 75.8 °F Std Liquid Volumetric Flow (Total) 13500 I bbVd Annual tank loss calculations for "LP Oil". —Oil Working Gas Total breathing losses 111.7 ton/yr. —Oil Breathing Gas working and are • Only Non -Exempt VOCs are reported. Sales Oil Tank 1 Total Oil Tank VOC Emissions PStreams "Oil Tank Vapors"/LP Oil" VOCs EF= 0.5793 lb/bbl Oil Tank Flash VOC Emissions PStreams "Oil tank flash gas /"LP Oil" VOCs EF= 0.4044 lb/bbl Oil Tank Working & Breathing VOC Emissions PStreams "Working & Breathing Gas"/"LP Oil" VOCs EF= 0.1748 lb/bbl Buffer House Flash Factor PStreams "Buffer Gas"/"LP Oil" Entire Vapor Stream EF= 335 SCF/bbl Oil Tank Flash Factor PStreams "Oil Tank Vapors"/'LP Oil' Entire Vapor Stream EF= 4.833 SCF/bbl User Specified Values ? Extrapolated or Approximate Values ProMax 5.0:20034.0 Copyright © 2002-2020 BRE Group, Ltd. Licensed to SLR International Corporation and Affiliates Page 41 of 101 Simulation Initiated on 11/18/2020 3:04:26 PM Regnier Farms 19H -B268_2 psig_SSOTEF_11.18.2020.pmx Page 1 of 8 Process Streams Report All Streams Tabulated by Total Phase Client Name:" Crestone"Peak Resources Job`. Site Specific Oil Tank Emissions Factor - Estimate 2 psig Location: Reigner Farms 19H -B268 Flawsheet: ' Facility Operations Connections Buffer Gas Buffer Gas Sample LP Gas to Buffer LP Oil Oil tank flash gas From Block Buffer House -- LP Separator Oil Storage Tanks Oil Storage Tanks To Block SAT -1 XCHG-100 MIX -101 Stream Composition Mole Fraction Buffer Gas % Buffer Gas Sample % LP Gas to Buffer % LP Oil % Oil tank flash gas % Hydrogen Sulfide 0 0* 0 0 0 Sulfur 0 0* 0 0 0 Helium 0 0* 0 0 0 Hydrogen 0 0* 0 0 0 Carbon Dioxide 1.09726 0.7575 * 1.05774 0.00395459 0.284762 Nitrogen 0.0669842 0.0201 * 0.0644772 2.08438E-06 0.00150971 Methane 12.3486 8.2492 * 11.8915 0.00561095 1.15994 Ethane 27.3904 18.4229 * 26.4665 0.447983 14.3258 Propane 32.7 29.9371 * 31.9351 4.87175 37.8845 Isobutane 5.9609 6.9653 * 5.96187 2.62201 9.04736 n -Butane 13.9706 19.0173 * 14.2647 9.90884 23.1809 Isopentane 2.51509 5.1535 * 2.79426 5.42522 4.83174 n -Pentane 2.49481 5.8455 * 2.90278 7.5464 4.99287 Cyclopentane 0.138343 0.3064 * 0.172216 0.590544 0.30022 n -Hexane 0.309703 1.3311 * 0.532626 4.64138 0.868258 Cyclohexane 0.0972085 0.3293 * 0.182611 1.85744 0.301197 Isohexane 0.700245 2.2295 * 1.03092 6.38393 1.73801 Heptane 0.0894729 0.5978 * 0.308798 7.85041 0.459613 Methylcyclohexane • 0.0398554 0.2461 * 0.137994 3.38348 0.210436 2,2,4-Trimethylpentane 0.000245843 0.0004 * 0.000793803 0.0193019 0.00120772 Benzene 0.0415086 0.1396 * 0.0673802 0.559809 0.111319 Toluene 0.0166765 0.1022 * 0.0605026 1.67895 0.0912663 Ethylbenzene 0.000263325 0.0031 * 0.00265416 0.219464 0.00361305 o-Xylene 0.00159627 0.0247 * 0.0203428 2.12082 0.0272817 Octane 0.0112256 0.1881 * 0.104126 8.06614 0.139901 Nonane 0.000706604 0.054 * 0.022849 5.45953 0.0279056 Decane 7.56259E-05 0.0739 * 0.00725566 5.03499 0.00799889 C11 4.3135E-06 0 * 0.00146425 3.08356 0.00144851 C12 3.77365E-07 0 * 0.000390178 2.31705 0.000350009 C13 3.7041E-08 0 * 0.000125499 2.16283 0.000102885 C14 3.62898E-09 0 * 3.80367E-05 1.83297 2.85108E-05 C15 4.02392E-10 0 * 1.16894E-05 1.48113 8.05654E-06 C16 2.56835E-11 0 * 2.97307E-06 1.14388 1.8815E-06 C17 3.90233E-12 0 * 1.0593E-06 1.05972 6.0757E-07 C18 3.29656E-13 0 * 3.55227E-07 1.01808 1.88396E-07 C19 1.07817E-14 0 * 7.95919E-08 0.821566 3.80104E-08 C20 3.28089E-15 0 * 3.19562E-08 0.715701 1.37208E-08 C21 2.57491E-16 0 * 8.67614E-09 0.535908 3.49517E-09 C22 3.42504E-17 0 * 3.50705E-09 0.583681 1.28278E-09 C23 2.76493E-18 0 * 9.26022E-10 0.444277 3.10017E-10 C24 1.13316E-19 0 * 2.9926E-10 0.411984 9.74805E-11 C25 5.06608E-20 0 * 1.29985E-10 0.379068 3.78844E-11 C26 7.75559E-21 0 * 4.77885E-11 0.311812 1.32421E-11 C27 6.83545E-22 0 * 1.51553E-11 0.30256 3.84114E-12 C28 3.32732E-23 0 * 3.52853E-12 0.240465 8.11606E-13 C29 4.01996E-24 0 * 1.16179E-12 0.211018 2.32384E-13 C30 2.64855E-24 0 * 3.39281E-12 2.24478 5.93419E-13 Water 0 0* 0 0 0 C10+ 0 0* 0 0 0 Argon 0.00814009 0.0054 * 0.0078367 9.67127E-07 0.00038168 * User Specified Values ? Extrapolated or Approximate Values ProMax 5.0.20034.0 Copyright © 2002-2020 BRE Group, Ltd. Licensed to SLR International Corporation and Affiliates Page 42 of 101 Simulation Initiated on 11/18/2020 3:04:26 PM Regnier Farms 19H-6268_2 psig_SSOTEF_11.18.2020.pmx Page 2 of 8 Process Streams Report All Streams Tabulated by Total Phase Client Name: Crestone Peak Resources Job: Site Specific Oil Tank Emissions Factor Estimate 2 psig ; Location: Reigner Farms 19H -B268 '- Flowsheet: Facility Operations Mass Fraction Buffer Gas % Buffer Gas Sample % LP Gas to Buffer % LP Oil % Oil tank flash gas % Hydrogen Sulfide 0 0* 0 0 0 Sulfur 0 0* 0 0 0 Helium 0 0* 0 0 0 Hydrogen 0 0* 0 0 0 Carbon Dioxide 1.16131 0.687849 * 1.09112 0.00142498 0.246031 Nitrogen 0.0451263 0.0116179 * 0.0423366 4.78084E-07 0.000830274 Methane 4.76411 2.73053 * 4.4715 0.000737002 0.365315 Ethane 19.8066 11.4299 * 18.6535 0.110292 8.45669 Propane 34.6765 27.2376 * 33.0072 1.7589 32.7958 Isobutane 8.33192 8.35307 * 8.12211 1.24778 10.3235 n -Butane 19.5276 22.8063 * 19.4335 4.71549 26.4505 Isopentane 4.36389 7.67177 * 4.72542 3.20485 6.84375 n -Pentane 4.32871 8.70191 * 4.90893 4.4579 7.07196 Cyclopentane 0.23333 0.443379 * 0.2831 0.339106 0.413355 n -Hexane 0.641829 2.36678 * 1.07584 3.27485 1.4689 Cyclohexane 0.196743 0.571819 * 0.360225 1.27991 0.497639 Isohexane 1.45119 3.96419 * 2.08234 4.50435 2.94033 Heptane 0.215605 1.23594 * 0.725262 6.44065 0.904128 Methylcyclohexane 0.0941084 0.498569 * 0.317581 2.72004 0.40563 2,2,4-Trimethylpentane 0.000675343 0.000942755 * 0.00212535 0.0180524 0.00270832 Benzene 0.0779734 0.224992 * 0.123365 0.358029 0.170706 Toluene 0.0369519 0.194292 * 0.130665 1.2666 0.165087 Ethylbenzene 0.000672304 0.00679059 * 0.00660469 0.190769 0.00753038 o-Xylene 0.00407548 0.0541056 * 0.0506217 1.84351 0.0568608 Octane 0.0308372 0.44333 * 0.278789 7.544 0.31373 Nonane 0.00217943 0.1429 * 0.0686887 5.73312 0.070263 Decane 0.000258768 0.216949 * 0.0241975 5.86555 0.0223429 C11 1.62145E-05 0 * 0.00536465 3.94635 0.00444494 C12 1.54581E-06 0 * 0.0015578 3.23147 0.00117043 C13 1.64227E-07 0 * 0.000542317 3.26478 0.000372376 C14 1.73138E-08 0 * 0.000176874 2.97737 0.000111042 C15 2.05554E-09 0 * 5.81999E-05 2.57596 3.35965E-05 C16 1.39862E-10 0 * 1.57799E-05 2.12078 8.36412E-06 C17 2.25669E-11 0 * 5.97062E-06 2.08645 2.86823E-06 C18 2.01758E-12 0 * 2.11899E-06 2.1214 9.41264E-07 C19 6.96239E-14 0 * 5.00946E-07 1.80627 2.00374E-07 C20 2.22933E-14 0 * 2.11636E-07 1.65571 7.61083E-08 C21 1.83648E-15 0 * 6.0312E-08 1.30132 2.03499E-08 C22 2.55835E-16 0 * 2.55322E-08 1.48436 7.82198E-09 C23 2.15854E-17 0 * 7.04613E-09 1.18087 1.97575E-09 C24 9.22866E-19 0 * 2.37547E-09 1.14235 6.48089E-10 C25 4.2968E-19 0 * 1.07453E-09 1.09461 2.62303E-10 C26 6.83952E-20 0 * 4.10759E-10 0.936212 9.53319E-11 C27 6.25864E-21 0 * 1.35248E-10 0.94318 2.87106E-11 C28 3.15878E-22 0 * 3.26491E-11 0.777224 6.28984E-12 C29 3.95194E-23 0 * 1.11319E-11 0.706282 1.86493E-12 C30 2.69308E-23 0 * 3.36242E-11 7.77113 4.92574E-12 Water 0 0* 0 0 0 C10+ 0 0* 0 0 0 Argon 0.00782016 0.00445095 * 0.00733791 3.1633E-07 0.000299333 Mass Flaw Buffer Gas Ib/h Buffer Gas Sample lb/h LP Gas to Buffer lb/h LP Oil Ib/h Oil tank flash gas Iblh Hydrogen Sulfide 0 0* 0 0 0 Sulfur 0 0* 0 0 0 Helium 0 0* 0 0 0 Hydrogen 0 0* 0 0 0 * User Specified Values ? Extrapolated or Approximate Values ProMax 5.0.20034.0 Copyright@ 2002-2020 BRE Group, Ltd. Licensed to SLR Intemational Corporation and Affiliates Page 43 of 101 Simulation Initiated on 11/18/2020 3:04:26 PM Regnier Farms 19H-8268_2 psig_SSOTEF_11.18.2020.pmx Page 3 of 8 Process Streams Report All Streams Tabulated; by Total Phase Client Name: ' Crestone Peak Resources Job: Site Specific Oil Tank Emissions Factor Estimate 2 psig Location: Reigner Farms 19H -B268 Flowsheet: Facility Operations Mass Flow Buffer Gas lb/h Buffer Gas Sample lb/h LP Gas to Buffer _ lb/h LP Oil Ib/h Oil tank flash gas Ib/h Carbon Dioxide 62.164 65.8119 * 62.2653 0.523806 0.159582 Nitrogen 2.41558 1.11157 * 2.41597 0.000175738 0.000538536 Methane 255.019 261.251 * 255.17 0.270913 0.236953 Ethane 1060.23 1093.59 * 1064.48 40.5419 5.48522 Propane 1856.21 2606.04 * 1883.58 646.552 21.2722 Isobutane 446.001 799.203 * 463.494 458.669 6.69605 n -Butane 1045.3 2182.06 * 1108.98 1733.36 17.1565 Isopentane 233.596 734.018 * 269.659 1178.06 4.43903 n -Pentane 231.712 832.58 * 280.132 1638.67 4.58705 Cyclopentane 12.49 42.4215 * 16.1553 124.651 0.268112 n -Hexane 34.3566 226.448 * 61.3939 1203.8 0.952767 Cyclohexane 10.5315 54.7104 * 20.5565 470.48 0.322781 Isohexane 77.6811 379.285 * 118.83 1655.75 1.90717 Heptane 11.5412 118.252 * 41.3876 2367.51 0.58644 Methylcyclohexane 5.03755 47.702 * 18.123 999.854 0.263102 • 2,2,4-Trimethylpentane 0.0361506 0.0902007 * 0.121285 6.63585 0.00175669 Benzene 4.17385 21.5267 * 7.03993 131.607 0.110724 Toluene 1.97801 18.5895 * 7.45649 465.588 0.107079 Ethylbenzene 0.0359879 0.649708 * 0.376902 70.1243 0.00488439 o-Xylene 0.218157 5.17671 * 2.88876 677.652 0.0368814 Octane 1.65069 42.4169 * 15.9093 2773.08' 0.203493 Nonane 0.116663 13.6724 * 3.91977 2107.43 0.0455743 Decane 0.0138517 20.7572 * 1.38085 2156.11 0.0144922 C11 0.000867948 0 * 0.306137 1450.63 0.0028831 C12 8.2746E-05 0 * 0.0888968 1187.85 0.000759168 C13 8.79093E-06 0 * 0.0309477 1200.09 0.000241532 C14 9.26793E-07 0 * 0.0100934 1094.45 7.20244E-05 C15 1.10031E-07 0 * 0.00332122 946.892 2.17915E-05 C16 7.48673E-09 0 * 0.000900494 779.573 5.42518E-06 C17 1.20799E-09 0 * 0.000340718 766.955 1.86041E-06 C18 1.08E-10 0 * 0.000120922 779.802 6.10528E-07 C19 3.72691E-12 0 * 2.85869E-05 663.962 1.29968E-07 C20 1.19334E-12 0 * 1.20772E-05 608.619 4.93657E-08 C21 9.83055E-14 0 * 3.44175E-06 478.351 1.31995E-08 C22 I 1.36946E-14 0 * 1.45701E-06 545.633 5.07353E-09 C23 1.15545E-15 0 * 4.02092E-07 434.072 1.28152E-09 C24 4.94003E-17 0 * 1.35558E-07 419.913 4.20367E-10 C25 2.30004E-17 0 * 6.13187E-08 402.366 1.70136E-10 C26 3.66114E-18 0 * 2.34402E-08 344.14 6.18347E-11 C27 3.3502E-19 0 * 7.71801E-09 346.702 1.86224E-11 C28 1.69087E-20 0 * 1.86314E-09 285.698 4.07975E-12 C29 2.11544E-21 0 * 6.3525E-10 259.621 1.20964E-12 C30 1.44158E-21 0 * 1.91879E-09 2856.58 3.19496E-12 Water 0 0* 0 0 0 C10+ 0 0* 0 0 0 Argon 0.418607 0.425857 * 0.418743 0.000116279 0.000194155 Stream Properties Property Units Buffer Gas Buffer Gas Sample LP Gas to Buffer LP Oil Oil tank flash gas Temperature °F 54.8951 68.7095 90 * 66 66 * Pressure psig 25 * 188 22 0 0 * Molecular Weight Ib/Ibmol 41.5823 48.4659 42.6634 122.135 50.9376 Mass Flow Ib/h 5352.92 9567.78 5706.57 36758.8 64.8625 Std Vapor Volumetric Flow MMSCFD 1.17243 1.79796 1.21822 2.74112 0.0115974 Std Liquid Volumetric Flow sgpm 22.2321 36.4778 23.3581 102.083 0.241749 Specific Gravity 1.43573 1.47306 0.723104 1.75874 Net Ideal Gas Heating Value Btu/ft^3 2160.6 2509.31 2214.57 6159.41 2644.31 * User Specified Values ? Extrapolated or Approximate Values ProMax 5.0.20034.0 Copyright© 2002-2020 BRE Group, Ltd. Licensed to SLR International Corporation and Affiliates Page 44 of 101 Simulation Initiated on 11/18/2020 3:04:26 PM Regnier Farms 19H -B268_2 psig_SSOTEF_11.18.2020.pmx Page 4 of 8 Process Streams Report All Streams Tabulated by Total Phase Client Name: Crestone Peak Resources Job: Site Specific Oil Tank Emissions Factor Estimate 2 psig Location: Reigner Farms 19H-8268 Flowsheet: Facility Operations Stream Properties Property Units Buffer Gas Buffer Gas Sample LP Gas to Buffer LP Oil Oil tank flash gas Net Liquid Heating Value Btu/lb 19567.9 19494.2 19548 18998.8 19541.8 Gross Ideal Gas Heating Value Btu/ft^3 2350.16 2723.71 2407.84 6630.05 2868.64 Gross Liquid Heating Value Btu/lb 21298.4 21173.3 21267.6 20461.1 21213.4 Remarks User Specified Values ? Extrapolated or Approximate Values Copyright © 2002-2020 BRE Group, Ltd. ProMax 5.0.20034.0 Licensed to SLR International Corporation and Affiliates Page 45 of 101 Simulation Initiated on 11/18/2020 3:04:26 PM Regnier Farms 19H -B268_2 psig_SSOTEF_11.18.2020.pmx Page 5 of 8 Process Streams Report All Streams Tabulated by Total Phase Client Name: Crestone Peak Resources Job: Site Specific Oil Tank Emissions Factor Estimate 2 psig Location: Reigner Farms 19H -B268 Flowsheet Facility Operations Connections Oil Tank Vapors Pressurized Liquid Sample ; Working & Breathing Gas 2 From Block MIX -101 -- MIX -102 XCHG-100 To Block -- SAT -1 MIX -101 Buffer House Stream Composition Mole Fraction Oil Tank Vapors % Pressurized Liquid Sample % Working & Breathing Gas % 2 % Hydrogen Sulfide 0 0 * 0 0 Sulfur 0 0 * 0 0 Helium 0 0 * 0 0 Hydrogen 0 0 * 0 0 Carbon Dioxide 0.270534 0.0126 * 0.239498 1.05774 Nitrogen 0.00106347 0.0177 * 9.00964E-05 0.0644772 Methane 0.898444 0.0428 * 0.328058 11.8915 Ethane 15.2662 1.9483 * 17.3173 26.4665 Propane 39.5727 4.0578 * 43.255 31.9351 Isobutane 8.69332 1.8687 * 7.92109 5.96187 n -Butane 22.1814 6.9087 * 20.0013 14.2647 Isopentane 4.55565 4.1665 * 3.95344 2.79426 n -Pentane 4.67763 6.0602 * 3.99002 2.90278 Cyclopentane 0.264824 0.5459 * 0.187617 0.172216 n -Hexane 0.804801 4.5098 * 0.666386 0.532626 Cyclohexane 0.259305 1.9351 * 0.167929 0.182611 Isohexane 1.60596 6.1147 * 1.31793 1.03092 Heptane 0.412993 8.4958 * 0.311302 0.308798 Methylcyclohexane 0.188088 3.6724 * 0.139342 0.137994 2,2,4-Trimethylpentane 0.00109516 0.0217 * 0.000849643 0.000793803 Benzene 0.0916388 0.5622 * 0.0487104 0.0673802 Toluene 0.0753065 1.8336 * 0.0404944 0.0605026 Ethylbenzene 0.00298689 0.2451 * 0.00162106 0.00265416 o-Xylene 0.022066 2.3708 * 0.0106892 0.0203428 Octane 0.121674 8.9556 * 0.0819171 0.104126 Nonane 0.0237067 6.102 * 0.014548 0.022849 Decane 0.00670324 5.6066 * 0.00387711 0.00725566 C11 0.00121317 3.4664 * 0.000699833 0.00146425 C12 0.000282721 2.6046 * 0.000135949 0.000390178 C13 8.0807E-05 2.4312 * 3.26503E-05 0.000125499 C14 2.33072E-05 2.0604 * 1.1957E-05 3.80367E-05 C15 6.52268E-06 1.6649 * 3.17697E-06 1.16894E-05 C16 1.50011E-06 1.2858 * 6.68211E-07 2.97307E-06 C17 4.76404E-07 1.1912 * 1.90299E-07 1.0593E-06 C18 1.39579E-07 1.1444 * 3.30951E-08 3.55227E-07 C19 3.16719E-08 0.9235 * 1.7846E-08 7.95919E-08 C20 1.03227E-08 0.8045 * 2.91078E-09 3.19562E-08 C21 8.71259E-09 0.6024 * 2.00931E-08 8.67614E-09 C22 9.65156E-10 0.6561 * 2.72335E-10 3.50705E-09 C23 2.27868E-10 0.4994 * 4.86803E-11 9.26022E-10 C24 7.32481E-11 0.4631 * 2.03914E-11 2.9926E-10 C25 2.8024E-11 0.4261 * 6.51597E-12 1.29985E-10 C26 9.75154E-12 0.3505 * 2.13769E-12 4.77885E-11 C27 2.82365E-12 0.3401 * 6.04252E-13 1.51553E-11 C28 5.70767E-13 0.2703 * 4.54373E-14 3.52853E-12 C29 1.6485E-13 0.2372 * - 1.75412E-14 1.16179E-12 C30 4.10473E-13 2.5233 * 1.14228E-14 3.39281E-12 Water 0 0 * 0 0 C10+ 0 0 * 0 0 Argon 0.000280632 0 * 6.02218E-05 0.0078367 * User Specified Values ? Extrapolated or Approximate Values ProMax 5.0.20034.0 Copyright* 2002-2020 BRE Group, Ltd. Licensed to SLR International Corporation and Affiliates Page 46 of 101 Simulation Initiated on 11/18/2020 3:04:26 PM Regnier Farms 19H -B268_2 psig_SSOTEF_11.18.2020.pmx Page 6 of 8 Process Streams Report All Streams Tabulated by Total Phase Client Name: Crestone Peak Resources Job: Site Specific Oil Tank Emissions Factor Estimate 2 psig Location: Reigner Farms 19H -B268 Flowsheet: Facility Operations Mass Fraction Oil Tank Vapors % Pressurized Liquid Sample % Working & Breathing Gas % 2 % Hydrogen Sulfide 0 0 * 0 0 Sulfur 0 0 * 0 0 Helium 0 0 * 0 0 Hydrogen 0 0 * 0 0 Carbon Dioxide 0.236509 0.00432115 * 0.214934 1.09112 Nitrogen 0.000591792 0.00386386 * 5.14671E-05 0.0423366 Methane 0.286313 0.00535053 * 0.107319 4.4715 Ethane 9.11862 0.456518 * 10.6184 18.6535 Propane 34.6633 1.39434 * 38.8945 33.0072 Isobutane 10.0371 0.846377 * 9.38822 8.12211 n -Butane 25.6101 3.12911 * 23.7059 19.4335 Isopentane 6.52918 2.34252 * 5.81648 4.72542 n -Pentane 6.704 3.4072 * 5.8703 4.90893 Cyclopentane 0.368942 0.298344 * 0.268318 0.2831 n -Hexane 1.37769 3.02846 * 1.17102 1.07584 Cyclohexane 0.433505 1.26908 * 0.288195 0.360225 Isohexane 2.74914 4.1062 * 2.31596 2.08234 Heptane 0.822049 6.6338 * 0.636085 0.725262 Methylcyclohexane 0.366851 2.80984 * 0.27899 0.317581 2,2,4-Trimethylpentane 0.00248502 0,019316 * 0.0019791 0.00212535 Benzene 0.142192 0.342208 * 0.077588 , 0.123365 Toluene 0.137833 1.31652 * 0.0760838 0.130665 Ethylbenzene - 0.00629911 0.202771 * 0.00350944 0.00660469 o-Xylene 0.0465354 1.96136 * 0.0231411 0.0506217 Octane 0.276091 7.97171 * 0.190812 D.278789 Nonane 0.0603983 6.09858 * 0.0380481 0.0686887 Decane 0.0189458 6.21628 * 0.011249 0.0241975 C11 0.00376689 4.22224 * 0.00223066 0.00536465 C12 0.000956623 3.45722 * 0.000472211 0.0015578 C13 0.000295936 3.49279 * 0.000122748 0.000542317 C14 9.18513E-05 3.18529 * 4.8372E-05 0.000176874 C15 2.75226E-05 2.75584 * 1.37611E-05 5.81999E-05 C16 6.74773E-06 2.26888 * 3.0855E-06 1.57799E-05 C17 2.27568E-06 2.23215 * 9.33144E-07 5.97062E-06 C18 7.05628E-07 2.26954 * 1.71751E-07 2.11899E-06 C19 1.68939E-07 1.9324 * 9.77184E-08 5.00946E-07 C20 5.79383E-08 1.77133 * 1.67709E-08 2.11636E-07 C21 5.13286E-08 1.3922 * 1.21517E-07 6.0312E-08 C22 5.95496E-09 1.58801 * 1.72489E-09 2.55322E-08 C23 1.46942E-09 1.26333 * 3.22251E-10 7.04613E-09 C24 4.92756E-10 1.22212 * 1.40818E-10 2.37547E-09 C25 [ 1.96332E-10 1.17105 * 4.68615E-11 1.07453E-09 C26 7.10348E-11 1.00159 * 1.59852E-11 4.10759E-10 C27 2.13556E-11 1.00904 * 4.69132E-12 1.35248E-10 C28 4.4758E-12 0.831498 * 3.65765E-13 3.26491E-11 C29 1.33864E-12 0.755603 " 1.46221E-13 1.11319E-11 C30 3.44756E-12 8.3138 * 9.84871E-14 3.36242E-11 Water 0 0 * 0 0 C10+ 0 0 * 0 0 Argon 0.000222695 0 * 4.90575E-05 0.00733791 Mass Flow Oil Tank Vapors Ib/h Pressurized Liquid Sample Iblh Working & Breathing Gas Ib/h 2 Ib/h Hydrogen Sulfide 0 0 * 0 0 Sulfur 0 0 * 0 0 Helium 0 0 * 0 0 Hydrogen 0 0 * 0 0 Carbon Dioxide 0.221114 1.48472 * 0.0615318 62.2653 * User Specified Values ? Extrapolated or Approximate Values ProMac< 5.0.20034.0 Copyright © 2002-2020 BRE Group, Ltd. Licensed to SLR International Corporation and Affiliates Page 47 of 101 Simulation Initiated on 11/18/2020 3:04:26 PM Regnier Farms 19H -B268_2 psig_SSOTEF_11.18.2020.pmx Page 7 of 8 Process Streams Report All Streams Tabulated by Total Phase Client Name. Crestone Peak Resources Job: Site Specific Oil Tank Emissions Factor Estimate 2,psig Location: Reigner Farms 19H -B268 Flowsheet: Facility Operations Mass Flow Oil Tank Vapors lb/h Pressurized Liquid Sample _ Ib/h Working & Breathing Gas lb/h 2 Ib/h Nitrogen 0.00055327 1.3276 * 1.47341E-05 2.41597 Methane 0.267676 1.83841 * 0.0307236 255.17 Ethane 8.52506 156.857 * 3.03984 1064.48 Propane 32.407 479.087 * 11.1348 1883.58 Isobutane 9.38373 290.81 * 2.68768 463.494 n -Butane 23.943 1075.14 * 6.78658 1108.98 Isopentane 6.10418 804.875 * 1.66515 269.659 n -Pentane 6.26761 1170.7 * 1.68056 280.132 Cyclopentane 0.344927 102.509 * 0.0768146 16.1553 n -Hexane 1.28801 1040.56 * 0.335243 61.3939 Cyclohexane 0.405286 436.048 * 0.082505 20.5565 Isohexane 2.57019 1410.87 * 0.663018 118.83 Heptane 0.76854 2279.34 * 0.1821 41.3876 Methylcyclohexane 0.342972 965.446 * 0.0798697 18.123 2,2,4-Trimethylpentane 0.00232327 6.63686 * 0.00056658 0.121285 Benzene 0.132936 117.581 * 0.0222121 7.03993 Toluene 0.128861 452.349 * 0.0217814 7.45649 Ethylbenzene 0.00588908 69.6711 * 0.00100469 0.376902 o-Xylene 0.0435062 673.914 * 0.00662489 2.88876 Octane 0.258119 2739.03 * 0.054626 15.9093 Nonane 0.0564668 2095.44 * 0.0108925 3.91977 Decane 0.0177126 2135.88 * 0.00322038 .1.38085 C11 0.00352169 1450.74 * 0.000638597 0.306137 C12 0.000894353 1187.88 * 0.000135186 0.0888968 C13 0.000276673 1200.1 * 3.51405E-05 0.0309477 C14 8.58724E-05 1094.45 * 1.3848E-05 0.0100934 C15 2.57311E-05 946.893 * 3.93956E-06 0.00332122 C16 6.3085E-06 779.573 * 8.83322E-07 0.000900494 C17 2.12755E-06 766.955 * 2.67142E-07 0.000340718 C18 6.59697E-07 779.802 * 4.91691E-08 0.000120922 C19 1.57943E-07 663.962 * 2.7975E-08 2.85869E-05 C20 5.41869E-08 608.619 * 4.80122E-09 1.20772E-05 C21 4.79875E-08 478.351 * 3.4788E-08 3.44175E-06 C22 5.56733E-09 545.633 * 4.93805E-10 1.45701E-06 C23 1.37377E-09 434.072 * 9.22547E-11 4.02092E-07 C24 4.60681E-10 419.913 * 4.03137E-11 1.35558E-07 C25 1.83552E-10 402.366 * 1.34156E-11 6.13187E-08 C26 6.64109E-11 344.14 * 4.57629E-12 2.34402E-08 C27 1.99655E-11 346.702 * 1.34304E-12 7.71801E-09 C28 4.18446E-12 285.698 * 1.04712E-13 1.86314E-09 C29 1.2515E-12 259.621 * 4.18606E-14 6.3525E-10 C30 3.22315E-12 2856.58 * 2.81951E-14 1.91879E-09 Water 0 0 * 0 0 C10+ 0 0 * 0 0 Argon 0.000208199 0 * 1.40443E-05 0.418743 Stream Properties Property Units Oil Tank Vapors Pressurized Liquid Sample Working & Breathing Gas 2 Temperature °F 64.4839 100 * 62.0329 52.33 * Pressure psig 0 188 * 4.53794 22 Molecular Weight Ib/Ibmol 50.3409 128.327 49.0392 42.6634 Mass Flow Ib/h 93.4907 34359.4 28.6282 5706.57 Std Vapor Volumetric Flow MMSCFD 0.0169142 2.43856 0.00531686 1.21822 Std Liquid Volumetric Flow sgpm 0.350958 94.5838 * 0.109209 23.3581 Specific Gravity 1.73814 0.715742 1.6932 Net Ideal Gas Heating Value Btu/ft^3 2615.43 6464.15 2552.44 2214.57 Net Liquid Heating Value Btu/lb 19557.4 18977.8 19592.9 19548 *User Specified Values ? Extrapolated or Approximate Values ProMax 5.0.20034.0 Copyright © 2002-2020 BRE Group, Ltd. Licensed to SLR International Corporation and Affiliates Page 48 of 101 Simulation Initiated on 11/18/2020 3:04:26 PM Regnier Farms 19H-8268_2 psig_SSOTEF_11.18.2020.pmx Page 8 of 8 Process Streams Report All Streams Tabulated by Total Phase Client Name: Crestone Peak Resources Job: Site Specific Oil Tank Emissions Factor Estimate 2 psig Location: Reigner Farms 19H-8268 Flowsheet: . Facility Operations Stream Properties Property Units Oil Tank Vapors Pressurized Liquid Sample Working & Breathing Gas 2 Gross Ideal Gas Heating Value Btu/ft"3 2837.76 6956.06 2770.41 2407.84 Gross Liquid Heating Value Btu/lb 21233.8 20432.5 21280 21267.6 Remarks . User Specified Values ? Extrapolated or Approximate Values _ Copyright© 2002-2020 BRE Group, Ltd. ProMax 5.0.20034.0 Licensed to SLR International Corporation and Affiliates Page 49 of 101 Simulation Initiated on 11/18/2020 3:04:26 PM Regnier Farms 19H -B268_2 psig_SSOTEF_11.18.2020.pmx Page 1 of 1 Environments Report Client Name: Crestone Peak Resources Job: Site Specific Oil Tank Emissions Factor " Estimate 2 psig Location: Reigner Farms 19H-8268 Project -Wide Constants Atmospheric Pressure 12.12 psia Ideal Gas Reference Pressure 14.6959 psia Ideal Gas Reference Temperature 60 °F Ideal Gas Reference Volume 379.484 ft"3/Ibmol Liquid Reference Temperature 60 °F Environment [Environment1] Environment Settings Number of Poynting Intervals 0 Phase Tolerance 1 % Gibbs Excess Model Evaluation Temperature 77 °F Emulsion Enabled False Freeze Out Temperature Threshold Difference 10 °F Components Component Name - Henry's Law Phase Component Initiator Component Name Henry's Law Phase Component :Initiator Hydrogen Sulfide False False Nonane False False Sulfur False False Decane False False Helium False False C11 False False Hydrogen False False C12 False False Carbon Dioxide False False C13 False False Nitrogen False False C14 False False Methane False False C15 False False Ethane False False C16 False False Propane False False C17 False False Isobutane False False C18 False False n -Butane False False C19 False False Isopentane False False C20 False False n -Pentane False False C21 False False Cyclopentane False False C22 False False n -Hexane False False C23 False False Cyclohexane False False C24 False False Isohexane False False C25 False False Heptane False False C26 False False Methylcyclohexane False False C27 False False 2,2,4-Trimethylpentane False False C28 False False Benzene False False C29 False False Toluene False False C30 False False Ethylbenzene False False Water False True o-Xylene False False C10+ False False Octane False False Argon False False Physical Property Method Sets Liquid Molar Volume COSTALD Overall Package Peng-Robinson Stability Calculation Peng-Robinson Vapor Package Peng-Robinson Light Liquid Package Peng-Robinson Heavy Liquid Package Peng-Robinson Remarks * User Specified Values ? Extrapolated or Approximate Values Copyright © 2002-2020 BRE Group, Ltd. ProMax 5.0.20034.0 Licensed to SLR International Corporation and Affiliates Page 50 of 101 Simulation Initiated on 11/18/2020 3:04:26 PM Regnier Farms 19H -B268 2 psig_SSOTEF_11.18.2020.pmx Page 1 of 1 Calculator Report Client Name: Crestone Peak Resources, " Job: Site Specific Oil Tank Emissions Factor Estimate_2 psig Location: Reigner Farms 19H -B268 Oil Throughput Source Code Residual Error (for CV1) = Oil_Prod/3500-1 Calculated Variable [CV1] Source Moniker ProMax:ProMax!Project!Flowsheets!Facility Operations!PStreams!Pressurized Liquid Sample!Phases!Total!Properties!Std Liquid Volumetric Flow Value 3242.87 Unit Measured Variable [Oil_Prod] Source Moniker ProMax:ProMax!Project!Flowsheets!Facility Operations!PStreams!LP Oil!Phases!Total!Properties!Std Liquid Volumetric Flow Value 3500 Unit Solver Properties Status: Solved Error 2.88658E-15 Weighting 1 Calculated Value 94.5838 sgpm Priority 0 Lower Bound sgpm Solver State Active Upper Bound sgpm Group Step Size sgpm Skip Dependency Check False Is Minimizer False Block Dependencies 6 Algorithm Default Recycle Dependencies 0 Iterations 2 Solver Dependencies 1 Max Iterations 20 Remarks Requested 3500 bbl/d User Specified Values ? Extrapolated or Approximate Values Copyright © 2002-2020 BRE Group, Ltd. ProMax 5.0.20034.0 Licensed to SLR International Corporation and Affiliates Page 51 of 101 Tank -1 ❑ X Working and Breathing Parameters 'Floating Roof Fttsva I Loading Loss Parameters I Results I Working and Breathing Report I Loadng Report Hash Re •0 operLY I Value Units ;l Process Stream Tank Geometry Shell Length SixA Diameter of Store lion Time Frame Report Component ......... .............. Bulk Temperature to Stream Temperature? Use AP42 Raoult's Vapor Pressure? Maximum Fraction FA of Tank Average Fraction FiA of T Fraction FA of Tank Matenal Category insulation Tank Color Paint Concftion eather Vent Pressure Breather Vacuum Pressure Type of Coned Roof Color Roof Pant Condition Flashing Temperature LP Gil Vernal Cylinder Average Average Bolted or Riveted Construction? (— KrtOxn Sum of increases in Liquid Level? - (" Balanced Tank? ste Loading Losses? th�tput Flashng Losses, Output Working/Breathing Losses? Edit Source ... 62.03 Page 52 of 101 A Tank -1 Working and Breathing Parame Property ❑ X Loading Loss Parameters Rking and Breathing Report Loading Report I Flash Re _. Value Atmospheric Pressure True Vapor Pressure at Average Temperature Average Liquid Surface Temperature { Maximum Liquid Surface Temperature Bulk Liquid Temperature Mnual Tank Turnover Rate Flashing Losses oading Losses 12.081, psia 11.41i psia 54.13 Maximum Hourly Loading Loss Total W/B Losses Working Losses per Tank Standing Losses per Tank Rim Seal Losses per Tank Withdra,al Loss per Tank Deck Fitting Losses per Tank Deck Seam Losses per Tank Edit Source ... 0, ton/yr 62.031 ?F 52.58 1 © ` tbihr 111.71 ton/yr 10.521. ton/yr 3.442; ton/yr 0 ton/yr 0: ton; yr 0 I ton/yr 01 ton//r Page 53 of 101 Tank -1 Plostfj Roof FittNtgs t Lass F a ProMax AP 42 Emissions Report Annual Emissions Vertical Cylinder astponent s ture Propane Tstbutane n -Butane Isapentane n -Pentane C•yclopentane n -Hexane Cyclahexane Is©hexane Heptane Methylcycichexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene o-Xylene Nonane C11 C12 C13 C14 C24 C25 C26 C27 O X Barring Losses (ton/yr) 64.14 36.74 e.eE9 22.4 5.495 5.5466 0.2535 1.106 0.2723 2.163 0.6009 0.2636 0.00187 0.0733 0.0718E 0.003315 0.02186 0.1803 0.03555 0.01063 0.002107 0.0004461 0.000116 4.570E-05 1.300E-05 2.515E-06 9.816E-07 1.623E-07 5.232E-06 1.se4E-oe 1.148E-07 1.630E-09 3.044E-10 1.330E-10 4.427E-11 1.510E-11 4.432E-12 3,455E-13 1.391E-13 5.304E-14 0 Breathing Lasses (ten/yr) Total Losses (tan/yr) 27.54 111.7 12.03 46.77 2.503 11.77 7.329 25.73 1.79e 7.253 1.e15 7.361 0.0°256 0.3364 0.3621 1.468 0.0$511 0.3614 0.7161 2.504 0.1967 0.7576 0.06626 0.3458 0.0006119 0.002462 0.02355 0.09725 0.02352 0.0954 0.001085 0.004401 0.007155 0.02902 0.055 0,2353 0.01176' 0.04771 0.003478 0.01411 0.0006357 0.002757 0.000146 0.0005921 3.755E-05 0.0001535 .1.496E-05 6.065E-05 4.255E-06 1.726E-05 5.540E-07 3.965E-06 2.955E-07 1.170E-06 5.310E -OS 2.154E-07 3.021E -0E 1.225E-07 5.1e5E-O5 2.103E-0° 3.757E-08 1.524E-07 5.333E-10 2.163E-09 5.563E-11 4.041E-10 4.354E-11 1.766E-10 1.449E-11 5.8?6E-11 4.542E-12 2.004E -I1 1.450E-12 5.883E-12 1.131E-13 4.5e6E-I3 4.521E-14 1.833E-13 3.045E-14 1.235E-13 0 0 Etfit Source Page 54 of 101 SOURCE T TiNG 5530 Marshall Street Arvada, Colorado 80002 Phone: 303-420-5949 Fax: 303-420-5920 EXTENDED NATURAL GAS LIQUID ANALYSIS SAMPLE DATA PROJECT NO OG-2020-0207 SAMPLE ID Pressurized Liquid COMPANY NAME Crestone Peak Resources ANALYSIS DATE 5/21/2020 SITE Regnier Farms 19H -B268 SAMPLE DATE 5/20/2020 UNIT ID Bulk Separator CYLINDER NO 39894 SAMPLED BY AJM LAB ANALYST CLB FIELD DATA SAMPLE PROBE PRESSURE (psig) 22.3 SAMPLE PROBE TEMP (°F) 131 UNIT GAUGE PRESSURE (psig) 21 UNIT GAUGE TEMP ( F) 144 AMBIENT PRESSURE (psi) 12.2 AMBIENT TEMP ( F) 82 COMMENTS: LABORATORY DATA COMPONENT MOLE % WT% LV% CARBON DIOXIDE 0.0126 0.0043 0.0040 NITROGEN (AIR) 0.0177 0.0040 0.0034 METHANE 0.0428 0.0053 0.0134 ETHANE 1.9483 0.4515 0.9611 PROPANE 4.0578 1.3791 2.0622 ISOBUTANE 1.8687 0.8372 1.1280 N -BUTANE 6.9087 3.0950 4.0178 ISOPENTANE 4.1665 2.3170 2.8108 N -PENTANE 6.0602 3.3701 4.0523 CYCLOPENTANE 0.5459 0.2951 0.2982 N -HEXANE 4.5098 2.9955 3.4210 CYCLOHEXANE 1.9351 1.2553 1.2142 OTHER HEXANES 6.1147 4.0313 4.4388 OTHER HEPTANES 8.4958 6.5305 7.0419 METHYLCYCLOHEXANE 3.6724 2.7792 2.7217 2,2,4 TRIMETHYLPENTANE 0.0217 0.0191 0.0201 BENZENE 0.5622 0.3385 0.2900 TOLUENE 1.8336 1.3022 1.1321 ETHYLBENZENE 0.2451 0.2006 0.1744 XYLENES 2.3708 1.9400 1.6870 OTHER OCTANES 8.9556 7.8267 8.0896 NONANES 6.1020 6.0277 6.2398 DECANES PLUS 29.5520 52.9952 48.1782 TOTAL 100.00000 100.00000 100.00000 SAMPLE FRACTIONS TOTAL C6+ C7+ C10+ SPG LIQUID 0.758 0.790 0.802 0.834 API GRAVITY 55.1 47.6 45.0 38.3 MOLECULAR WEIGHT 129.7 153.9 168.7 232.4 ABSOLUTE DENSITY (Ibs/gal) 6.3 6.6 6.7 7.0 HEATING VALUE LIQUID IDL GAS (GBTU/gal) 98449.9 126730.8 128128.0 130824.6 GBTU/GAL LIQUID 113839.2 126948.3 127924.5 129615.4 NBTU/GAL LIQUID 122147.7 126764.2 127264.8 132488.9 VAPOR/LIQUID (SCF/gal) 19.7 17.7 16.7 13.9 VAPOR PRESSURE (psia) 33.3 1.3 0.6 0.0 ANALYTICAL PROCEDURES TAKEN FROM GPA-2186, ASTM D6730-01(2011), ASTM D7169, GPA-2103M. Page 55 of 101 Page 1 of 6 11:10 AM, 5/27/2020 SOURCE TESTING 5530 Marshall Street Arvada, Colorado 80002 Phone: 303-420-5949 Fax: 303-420-5920 EXTENDED NATURAL GAS LIQUID ANALYSIS DHA COMPONENT ANALYSIS SAMPLE DATA PROJECT NO OG-2020-0207 SAMPLE ID Pressurized Liquid COMPANY NAME Crestone Peak Resources ANALYSIS DATE 5/21/2020 SITE Regnier Farms 19H -B268 SAMPLE DATE 5/20/2020 UNIT ID Bulk Separator CYLINDER NO 39894 SAMPLED BY AJM LAB ANALYST CLB FIELD DATA SAMPLE PROBE PRESSURE (psig) 22.3 SAMPLE PROBE TEMP (°F) 131 UNIT GAUGE PRESSURE (psig) 21 UNIT GAUGE TEMP ( F) 144 AMBIENT PRESSURE (psi) 12.2 AMBIENT TEMP ( F) 82 COMMENTS: LABORATORY DATA COMPONENT MOLE % INT% LV% Air 0.0177 0.0040 0.0034 Carbon Dioxide 0.0126 0.0043 0.0040 Methane 0.0428 0.0053 0.0134 Ethane 1.9483 0.4515 0.9611 Propane 4.0578 1.3791 2.0622 Isobutane 1.8687 0.8372 1.1280 n -Butane 6.9087 3.0950 4.0178 Cyclopentane 0.5459 0.2951 0.2982 Isopentane 4 1665 2.3170 2.8108 n -Pentane 6.0602 3.3701 4.0523 Unknown C5s 0.0000 0.0000 0.0000 Neopentane 0.0000 0.0000 0.0000 Benzene 0.5622 0.3385 0.2900 Methyicyclopentane 1.9408 1.2590 1.2662 Cyclohexane 1.9351 1.2553 1.2142 2,2-Dimethylbutane 0.0617 0.0410 0.0475 Neohexane 0.0000 0.0000 0.0000 2-Methylpentane 2.3661 1.5716 1.8101 2,3-Dimethylbutane 0.2704 0.1796 0.2044 3-Methylpentane 1.4209 0.9438 1.0691 Unknown C6s 0.0547 0.0363 0.0415 n -Hexane 4.5098 2.9955 3.4210 Toluene 1.8336 1.3022 1.1321 1,1-Dimethylcyclopentane 0.3173 0.2402 0.2399 1,t-3-Dimethylcyclopentane 0.3828 0.2897 0.2916 1,c-3-Dimethylcyclopentane 0.4281 0.3240 0.3273 1,t-2-Dimethylcyclopentane 0.6053 0.4581 0.4592 Methylcyclohexane 3.6724 2.7792 2.7217 1, c -2-D imethylcyclopentane 0.0589 0.0446 0.0435 Ethylcyclopentane 0.2011 0.1522 0.1496 Cycloheptane 0.0000 0.0000 0.0000 2,2-Dimethylpentane 0.0711 0.0549 0.0614 2,4-Dimethylpentane 0.2569 0.1984 0.2220 2,2,3-Trimethylbutane 0.0154 0.0119 0.0129 3,3-Dimethylpentane 0.0425 0.03218 0.0357 2-Methylhexane 1.0930 0.8441 0.9363 2,3-Dimethylpentane 0.3705 0.2862 0.3101 3-Methylhexane 1.1577 0.8941 0.9796 3-Ethylpentane 0.0985 0.0760 0.0820 n-Heptane 3.3131 2.5588 2.8197 Triptane 0.0000 0.0000 0.0000 Unknown C7s 0.0836 0.0646 0.0712 Page 56 of 101 Page 2 of 6 11:10 AM, 5/27/2020 Styrene 0.0000 0.0000 0.0000 Ethylbenzene 0.2451 0.2006 0.1744 o-Xylene 0.5430 0.4444 0.3808 m-Xylene 1.3150 1.0761 0.9388 p-Xylene 0.5127 0.4196 0.3674 1,1, 3-Tri methylcyclopentane 0.0000 0.0000 0.0000 1,t-2,c-4-Trimethylcyclopentane 0.2334 0.2019 0.2035 1,t-2,c-3-Trimethylcyclopentane 0.1905 0.1648 0.1647 1,c -3-D imethylcyclohexane 0.0344 0.0297 0.0293 1,t-4-Dimetylcyclohexane 0.4305 0.3724 0.3679 1,1-Dimethylcyclohexane 0.1558 0.1348 0.1301 1-Methyl-c-3-ethylcyclopentane 0.0366 0.0317 0.0309 1-Methyl-t-2-ethylcyclopentane 0.0582 0.0503 0.0493 1,1, 2-Tri methylcyclopentane 0.1125 0.0973 0.0949 1,c-2,t-4-Trimethylcyclopentane 0.0000 0.0000 0.0000 1,c-2,t-3-Trimethylcyclopentane 1.0304 0.8912 0.8718 1-Methyl-t-3-ethylcyclopentane 0.0320 0.0277 0.0274 1-Methyl-1-ethylcyclopentane 0.0000 0.0000 0.0000 1,t -3 -Di methylcyclohexane 0.4254 0.3679 0.3534 1,c-4-Dimethylcyclohexane 0.0000 0.0000 0.0000 1,c-2,c-3-Trimethylcyclopentane 0.0000 0.0000 0.0000 Isopropylcyclopentane 0.0375 0.0325 0.0315 1-Ethyl-c-2-methylcyclopentane 0.0000 0.0000 0.0000 1, c-2-Dimethylcyclohexane 0.0728 0.0630 0.0596 n-Propylcyclopentane 0.8301 0.7179 0.6971 Ethylcyclohexane 0.0635 0.0549 0.0525 Cyclooctane 0.0000 0.0000 0.0000 n -Octane 2.2535 1.9841 2.1296 Unknown C8s 0.1069 0.0941 0.1010 Dilsobutyl 0.0000 0.0000 0.0000 Isooctane 0.0000 0.0000 0.0000 2,2,4-Trimethylpentane 0.0217 0.0191 0.0201 2,2-Dimethylhexane 0.2915 0.2566 0.2780 2,4-Dimethylhexane 0.2086 0.1837 0.1975 2,5-Dimethylhexane 0.0424 0.0373 0.0405 2,2,3-Trimethylpentane 0.0000 0.0000 0.0000 3,3-Dimethylhexane 0.0488 0.0430 0.0456 2,3,4-Trimethylpentane 0.0273 0.0240 0.0252 2,3-Dimethylhexane 0.1261 0.1110 0.1175 2-Methylheptane 1.0698 0.9419 1.0165 4-Methylheptane 0.3197 0.2815 0.3009 3-Methylheptane 0.6665 0.5868 0.6264 3,4-Dimethylhexane 0.0509 0.0448 0.0469 3-Ethylhexane 0.0000 0.0000 0.0000 C9 6.1020 6.0277 6.2398 C10 5.6066 6.1484 6.3477 C11 3.4664 4.1763 4.2533 C12 2.6046 3.4195 3.4418 C13 2.4312 3.4547 3.1726 C14 2.0604 3.1506 2.8553 C15 1.6649 2.7258 2.4527 C16 1.2858 2.2442 2.0027 C17 1.1912 2.2078 1.9796 C18 1.1444 2.2448 2.0056 C19 0.9235 1.9114 1.6878 C20 0.8045 1.7519 1.5380 C21 0.6024 1.3771 1.2020 C22 0.6561 1.5706 1.3631 C23 0.4994 1.2495 1.0795 C24 0.4631 1.2088 1.0396 C25 0.4261 1.1582 0.9916 C,26 0.3505 0.9908 0.8444 C27 0.3401 0.9980 0.8467 C28 0.2703 0.8225 0.6947 C29 0.2372 0.7473 0.6291 C30 0.2449 0.7981 0.6696 C31 0.1750 0.5894 0.4923 C32 0.1813 0.6301 0.5246 C33 0.1383 0.4957 0.4113 C34 0.1476 0.5450 0.4508 C35 0.1313 0.4988 0.4112 C36+ 1.5048 5.8800 4.7903 TOTAL 100.0000 100.0000 100.0000 Page 57 of 101 Page 3 of 6 11:10 AM, 5/27/2020 SOURCE TESTING 5530 Marshall Street Arvada, Colorado 80002 Phone: 303-420-5949 Fax: 303-420-5920 EXTENDED NATURAL GAS LIQUIDS ANALYSIS BY CARBON NUMBER SAMPLE DATA PROJECT NO OG-2020-0207 SAMPLE ID Pressurized Liquid COMPANY NAME Crestone Peak Resources ANALYSIS DATE 5/21/2020 SITE Regnier Farms 19H -B268 SAMPLE DATE 5/20/2020 UNIT ID Bulk Separator CYLINDER NO 39894 SAMPLED BY AJM LAB ANALYST CLB FIELD DATA SAMPLE PROBE PRESSURE (psig) 22.3 SAMPLE PROBE TEMP (°F) 131 UNIT GAUGE PRESSURE (psig) 21 UNIT GAUGE TEMP ( F) 144 AMBIENT PRESSURE (psi) 12.2 AMBIENT TEMP ( F) 82 COMMENTS: LABORATORY DATA COMPONENT MOLE % WT% LV% Air 0.0177 0.0040 0.0034 Carbon Dioxide 0.0126 0.0043 0.0040 C1 0.0428 0.0053 0.0134 C2 1.9483 0.4515 0.9611 C3 4.0578 1.3791 2.0622 C4 8.7774 3.9322 5.1459 C5 10.7726 5.9821 7.1613 C6 13.1219 8.6205 9.3641 C7 14.0018 10.6119 10.8956 C8 11.5932 9.9863 9.9710 C9 6.1020 6.0277 6.2398 C10 5.6066 6.1484 6.3477 C11 3.4664 4.1763 4.2533 C12 2.6046 3.4195 3.4418 C13 2.4312 3.4547 3.1726 C14 2.0604 3.1506 2.8553 C15 1.6649 2.7258 2.4527 C16 1.2858 2.2442 2.0027 C17 1.1912 2.2078 1.9796 C18 1.1444 2.2448 2.0056 C19 0.9235 1.9114 1.6878 C20 0.8045 1.7519 1.5380 C21 0.6024 1.3771 1.2020 C22 0.6561 1.5706 1.3631 C23 0.4994 1.2495 1.0795 C24 0.4631 1.2088 1.0396 C25 0.4261 1.1582 0.9916 C26 0.3505 0.9908 0.8444 C27 0.3401 0.9980 0.8467 C28 0.2703 0.8225 0.6947 C29 0.2372 0.7473 0.6291 C30 0.2449 0.7981 0.6696 C31 0.1750 0.5894 0.4923 C32 0.1813 0.6301 0.5246 C33 0.1383 0.4957 0.4113 C34 0.1476 0.5450 0.4508 C35 0.1313 0.4988 0.4112 C36+ 1.5048 5.8800 4.7903 TOTAL 100.0000 100.0000 100.0000 Page 58 of 101 Page 4 of 6 11:10 AM, 5/27/2020 SOURCE TESTING 5530 Marshall Street Arvada, Colorado 80002 Phone: 303-420-5949 Fax: 303-420-5920 PHYSICAL PROPERTY TESTING SAMPLE DATA PROJECT NO OG-2020-0207 SAMPLE ID Sales Oil COMPANY NAME Crestone Peak Resources ANALYSIS DATE 5/21/2020 SITE Regnier Farms 19H -B268 SAMPLE DATE 5/20/2020 UNIT ID Storage Tank CYLINDER NO Jar SAMPLED BY Crestone Peak Resources LAB ANALYST CLB FIELD DATA SAMPLE PRESSURE (psig) NA SAMPLE TEMP (°F) 99 AMBIENT PRESSURE (psi) 12.2 AMBIENT TEMP ( F) 82 COMMENTS: LABORATORY DATA API GRAVITY ASTM D5002 RVP EQUIVALENT (psi) ASTM D6377* 48.2 7.8 NOTES: *RVPe = VPCR4(100°F) x A A = 0.915 for ambient samples or 0.834 for pressurized samples Page 59 of 101 Page 5 of 6 11:10 AM, 5/27/2020 Allis 5530 Marshall Street Arvada, Colorado 80002 Phone: 303-420-5949 Fax: 303-420-5920 SOURCE TESTING BUBBLE POINT QUALITY ASSURANCE SAMPLE DATA PROJECT NO OG-2020-0207 SAMPLE ID Pressurized Liquid COMPANY NAME Crestone Peak Resources ANALYSIS DATE 5/21/2020 SITE Regnier Farms 19H -B268 SAMPLE DATE 5/20/2020 UNIT ID Bulk Separator CYLINDER NO 39894 SAMPLED BY AJM LAB ANALYST CLB FIELD DATA SAMPLE PROBE PRESSURE (psig) 22.3 SAMPLE PROBE TEMP (°F) 131 UNIT GAUGE PRESSURE (psig) 21 UNIT GAUGE TEMP ( F) 144 AMBIENT PRESSURE (psi) 12.2 AMBIENT TEMP ( F) 82 COMMENTS: 700 600 500 400 300 200 100 0 100 200 300 400 500 600 700 800 0 RECORDED PRESSURE (psia) 34.5 VMG CALCULATED PRESSURE (psia) 42.3 DIFFERENCE 22.6% PHASE DIAGRAM T (Fj 900 Page 60 of 101 Page 6 of 6 11:10 AM, 5/27/2020 AIlia SOURCE TESTING SAMPLE DATA PROJECT NO OG-2020-0207 COMPANY NAME Crestone Peak SITE Regnier Farms UNIT ID Separator K SAMPLED BY AJM FIELD DATA SAMPLE PRESSURE 50 psig AMBIENT PRESSURE 12.2 psi COMMENTS: 5530 Marshall Street Arvada, Colorado 80002 Phone: 303-420-5949 Fax: 303-420-5920 FLASH LIBERATION ANALYSIS OF SEPARATOR WATER SAMPLE ID Pressurized Water Resources ANALYSIS DATE 5/22/2020 19H -B268 SAMPLE DATE 5/20/2020 CYLINDER NO 38528 . LAB ANALYST CLB SAMPLE TEMP 145 F AMBIENT TEMP 82 F Flash Liberation of Pressurized Water Pressure Temperature Separator Produced Water Stock Tank Base Conditions 50 psig 145 °F 12.2 psia 60 °F 14.65 psi 60 °F Flash Liberation Results Result Units Gas Water Ratio Gas Specific Gravity <0.5 SCF flashed gas/bbl stock tank liquid 1.1558 Air = 1.00 Quality Assurance Result Duplicate GWR RSD (20% max.) 0.00% Page 61 of 101 SOURCE TESTING SAMPLE DATA PROJECT NO COMPANY NAME SITE UNIT ID SAMPLED BY OG-2020-0207 Crestone Peak Resources Regnier Farms 19H -B268 Separator K AJM LAB CONDITIONS PRESSURE 12.2 psi COMMENTS: 5530 Marshall Street Arvada, Colorado 80002 Phone: 303-420-5949 Fax: 303-420-5920 Flashed Gas Extended Analysis SAMPLE ID Flashed Gas ANALYSIS DATE 5/22/2020 SAMPLE DATE 5/20/2020 CYLINDER NO 38528 LAB ANALYST CLB TEMPERATURE 72 F LABORATORY DATA COMPONENT MOLE% HYDROGEN SULFIDE CARBON DIOXIDE WT% GPM NITROGEN METHANE ETHANE PROPANE ISOBUTANE N -BUTANE ISOPENTANE N -PENTANE CYCLOPENTANE N -HEXANE CYCLOHEXANE OTHER HEXANES HEPTANES METHYLCYCLOHEXANE 2,2,4 TRIMETHYLPENTANE BENZENE TOLUENE ETHYLBENZENE XYLENES OCTANES NONANES DECANES PLUS SUBTOTAL 100.0000 OXYGEN/ARGON 0.0000 0.0000 14.4770 8.2086 32.2041 22.1388 12.1483 1.4973 4.0744 0.7636 0.9215 0.1467 0.6896 0.1710 1.2798 0.1734 0.1223 0.0000 0.3938 0.2726 0.0084 0.0591 0.1347 0.0242 0.0907 0.0000 19.0331 6.8695 15.4337 19.8865 16.0028 2.5997 7.0744 1.6459 1.9862 0.3074 1.7753 0.4300 3.2667 0.5173 0.3587 0.0000 0.9191 0.7505 0.0268 0.1874 0.4533 0.0911 0.3846 0.0000 2.4821 0.9073 5.4849 5.9482 3.3624 0.4922 1.2905 0.2806 0.3356 0.0437 0.2849 0.0584 0.5018 0.0790 0.0494 0.0000 0.1106 0.0917 0.0033 0.0230 0.0646 0.0128 0.0555 100.0000 21.9623 0.0000 0.0000 TOTAL 100 100 21.9623 BTU @ MOLECULAR WEIGHT 33.4745 NET DRY REAL 1320.3250 /scf RELATIVE DENSITY (AIR=1) 1.1558 COMPRESSIBILITY FACTOR 0.9928 GROSS DRY REAL 1450.7601 /scf GROSS WET REAL 1425.0966 /scf ANALYTICAL PROCEDURES TAKEN FROM GPA 2286-95 Page 62 of 101 Alliance SOURCE TESTING EXTENDED GAS ANALYSIS 5530 Marshall Street Arvada, Colorado 80002 Phone: 303-420-5949 Fax: 303-420-5920 SAMPLE DATA PROJECT NO OG-2020-0207 SAMPLE ID Sales Gas COMPANY NAME Crestone Peak Resources ANALYSIS DATE 5/21/2020 SITE Regnier Farms 19H-8268 SAMPLE DATE 5/20/2020 UNIT ID Regnier Farms 19H -B268 CYLINDER NO GV-115 SAMPLED BY AJM LAB ANALYST CLB FIELD DATA SAMPLE PRESSURE 188 psig SAMPLE TEMP 100 F AMBIENT PRESSURE 12.2 psi AMBIENT TEMP 82 F COMMENTS: LABORATORY DATA COMPONENT MOLE % HYDROGEN SULFIDE 0.0000 0.0000 0.0000 CARBON DIOXIDE 1.6914 3.1811 0.2892 NITROGEN 0.3086 0.3694 0.0340 METHANE... 70.5861 48.3913 11.9892 ETHANE 14.3392 18.4255 3.8421 PROPANE 7.4360 14.0122 2.0525 ISOBUTANE 1.1379 2.8262 0.3730 N -BUTANE 2.6529 6.5894 0.8380 ISOPENTANE.0.5754 1.7742 0.2108 N -PENTANE 0.6343 1.9558 0.2304 CYCLOPENTANE 0.0307 0.0921 0.0091 N -HEXANE 0.1352 0.4979 0.0557 CYCLOHEXANE 0.0343 0.1234 0.0117 OTHER HEXANES 0.2229 0.8167 0.0892 HEPTANES 0.0728 0.3108 0.0332 METHYLCYCLOHEXANE 0.0309 0.1298 0.0125 2,2,4 TRIMETHYLPENTANE 0.0001 0.0003 0.0000 BENZENE 0.0142 0.0473 0.0040 TOLUENE 0.0135 0.0531 0.0045 ETHYLBENZENE 0.0007 0.0033 0.0003 XYLENES 0.0062 0.0280 0.0024 OCTANES 0.0344 0.1667 0.0169 NONANES 0.0067 0.0360 0.0035 DECANES 0.0257 0.1560 0.0157 SUBTOTAL 99.9902 OXYGEN/ARGON 0.0098 WT% GPM 99.9866 20.1178 0.0134 0.0009 TOTAL 100.00 100.00 20.12 BTU @ MOLECULAR WEIGHT 23.4005 NET DRY REAL 1234.9057 /scf RELATIVE DENSITY (AIR=1) 0.8080 COMPRESSIBILITY FACTOR 0.9955 GROSS DRY REAL 1363.0294 /scf GROSS WET REAL 1339.0454 /scf ANALYTICAL PROCEDURES TAKEN FROM GPA 2286-95 Page 63 of 101 Apia SOURCE TESTING EXTENDED GAS ANALYSIS 5530 Marshall Street Arvada, Colorado 80002 Phone: 303-420-5949 Fax: 303-420-5920 SAMPLE DATA PROJECT NO OG-2020-0207 SAMPLE ID Gas COMPANY NAME Crestone Peak Resources ANALYSIS DATE 5/21/2020 SITE Regnier Farms 19H -B268 SAMPLE DATE 5/20/2020 UNIT ID Buffer House CYLINDER NO GV-31 SAMPLED BY AJM LAB ANALYST CLB FIELD DATA SAMPLE PRESSURE 32 psig SAMPLE TEMP 114 F AMBIENT PRESSURE 12.2 psi AMBIENT TEMP 82 F COMMENTS: LABORATORY DATA COMPONENT MOLE 'Yo WT% GPM HYDROGEN SULFIDE 0.0000 0.0000 0.0000 CARBON DIOXIDE 0.7575 0.6880 0.1317 NITROGEN 0.0201 0.0116 0.0023 METHANE... 8.2492 2.7313 1.4251 ETHANE 18.4229 11.4331 5.0208 PROPANE 29.9371 27.2452 8.4048 ISOBUTANE 6.9653 8.3554 2.3227 N -BUTANE 19.0173 22.8127 6.1097 ISOPENTANE 5.1535 7.6739 1.9206 N -PENTANE 5.8455 8.7043 2.1593 CYCLOPENTANE 0.3064 0.4435 0.0925 N -HEXANE 1.3311 2.3675 0.5578 CYCLOHEXANE 0.3293 0.5720 0.1141 OTHER HEXANES 2.2295 3.9448 0.9073 HEPTANES 0.5978 1.2331 0.2770 METHYLCYCLOHEXANE 0.2461 0.4988 0.1008 2,2,4 TRIMETHYLPENTANE 0.0004 0.0010 0.0002 BENZENE 0.1396 0.2251 0.0398 TOLUENE 0.1022 0.1944 0.0349 ETHYLBENZENE 0.0031 0.0068 0.0012 XYLENES 0.0247 0.0540 0.0097 OCTANES 0.1881 0.4404 0.0944 NONANES 0.0540 0.1426 0.0307 DECANES 0.0739 0.2168 0.0461 SUBTOTAL 99.9946 OXYGEN/ARGON 0.0054 99.9965 29.8035 0.0035 0.0005 TOTAL 100.00 100.00 29.80 BTU @ MOLECULAR WEIGHT 48.4522 NET DRY REAL 2510.4407 /scf RELATIVE DENSITY (AIR=1) 1.6729 COMPRESSIBILITY FACTOR 0.9788 GROSS DRY REAL 2781.0193 /SCf GROSS WET REAL 2730.4602 /SCf ANALYTICAL PROCEDURES TAKEN FROM GPA 2286-95 Page 64 of 101 TANKS 4.0 Report TANKS 4.0.9d Emissions Report - Detail Format Tank Indentification and Physical Characteristics Identification User Identification: City: State: Company: Type of Tank: Description: Tank Dimensions Shell Height (ft): Diameter (ft): Liquid Height (ft) : Avg. Liquid Height (ft): Volume (gallons): Tumovers: Net Throughput(gal/yr): Is Tank Heated (y/n): Paint Characteristics Shell Color/Shade: Shell Condition Roof Color/Shade: Roof Condition: Roof Characteristics Type: Height (ft) Slope (ftA (Cone Roof) Breather Vent Settings Vacuum Settings (psig): Pressure Settings (psig) 750 bbl PW Tank2 Colorado Crestone Vertical Fixed Roof Tank Regnier Farms 19H-8266 N Gray/Light Good Gray/Light Good Cone 24.00 15.60 22.03 12.00 31,500.00 486.67 15,330,000.00 0.00 0.06 -0.03 0.03 Meterological Data used in Emissions Calculations: Denver, Colorado (Avg Atmospheric Pressure = 12.12 psia) 750 bbl PW Tank2 - Vertical Fixed Roof Tank Mixture/Component Liquid Deily Liquid Surf. Bulk Vapor Liquid Vapor Temperature (deg F) Temp Vapor Pressure (psia) Mol. Mass Mass Mot Basis for Vapor Pressure Month Avg. Min. Max. (deg F) Avg. Mm. Max. Weight. Fract Fract. Weight Calculations Water Mixture Gasoline (RVP 13) Water All 58.16 4720 69.12 52.45 0.3079 0.2161 0.4341 277948 1877 6/115 5.4371 8.2126 62.0000 0.0500 0.4960 9210 0.2419 0.1623 0.3540 181153 0.9500 0.5040 18_02 Option 4: RVP=13, ASTM Slope=3 Option 1: VP50 = .17814 VP60 =.25633 Page 65 of 101 11/18/2020 TANKS 4.0 Report TANKS 4.0.9d Emissions Report - Detail Format Detail Calculations (AP -42) 750 bbl PW Tank2 - Vertical Fixed Roof Tank Annual Emission Cakaulabons Standing Losses (lb): Vapor Space Volume (cu ft): Vapor Dens/N(16/cu ft): Vapor Space Expansion Factor: Vented Vapor Saturation Factor'. Tank Vapor Space Volume: Vapor Space Volume (cu ft): Tank Diameter (ft)'. Vapor Space Outage (ft): Tank Shell Height (ft)'. Average Liquid Height (ft): Roof Outage (ft): Roof Outage (Cone Roof) Roof Outage (fly Roof Height (1t): Roof Slope (ftM): Shell Radius (R): Vapor Density Vapor Density (lb/cu ft): Vapor Molecular Weight (kb/lb-male): Vapor Pressure at Daily Average Liquid Surface Temperature (psis): Daily Avg. Liquid Surface Temp. (deg. R): Daily Average Ambient Temp. (deg. F): Ideal Gas Constant R (psia curt / (Ib-mol-deg R)): Liquid Bulk Temperature (deg. R): Tank Paint Solar Absorptance (Shell)'. Tank Paint Solar Absorptance (Root): Daily Total Solar Insulation Factor (Blu/sgft day): Vapor Space Expansion Factor Vapor Space Expansion Factor: Daily Vapor Temperature Range (deg. R): Daily Vapor Pressure Range (psia): Breather Vent Press. Setting Range(psia): Vapor Pressure at Daily Average Liquid Surface Temperature (psia): Vapor Pressure at Daily Minimum Liquid Surface Temperature (psia): Vapor Pressure at Daily Maximum Liquid Surface Temperature (psia): Daily Avg. Liquid Surface Temp. (deg R): Daily Min. Liquid Surface Temp. (deg R): Daily Max. Li Wid Surface Temp. (deg Rti Daily Ambient Temp. Range (deg. R): Vented Vapor Saturation Factor Vented Vapor Saturation Factor: Vapor Pressure at Daily Average Liquid: Surface Temperature (Psia)'. Vapor Space Outage (ft): Working Losses (lb): Vapor Molecular Weight (lb/lb-mole): Vapor Pressure at Daily Average Liquid Surface Temperature (psia): Annual Net Throughput (gal/yr.): Annual Turnovers: Tumover Factor: Maximum Liquid Volume (gap'. Maximum Liquid Height (ft): Tank Diameter (ft): Working Loss Product Factor'. Total Losses Ohl: 106.8898 2,324.6733 0.0015 0.0980 0.8344 2,324.6733 15.6000 12.1625 24,0000 12.0000 0.1625 0.1625 0.0000 0.0625 7.8000 0.0015 27.7948 0.3079 517.8285 50.2125 10.731 512.1225 0.5400 0.5400 1,588.5833 0.0980 43.8350 0.2180 0.0600 O 3079 0.2161 0.4341 517.8285 506.8697 528/872 27.9417 0.8344 0.3079 12.1625 713.2318 27.7948 0.3079 15,330,000.0000 486.6667 0.2283 31,500.0000 22.0312 15.6000 1.0000 Emissions Report for: Annual 820.1216 750 bbl PW Tank2 - Vertical Fixed Roof Tank Losses(Ibs) Components Working Loss' Breathing Loss Total Emissions Water 359.50 53.88 413.38 Gasolele (RVP 13) 353.73 53.01 406.74 Water Mixture 713.23 106.89 820.12 Page 66 of 101 11/18/2020 Attachment D Company Contact Information Form APCD-101 Page 67 of 101 Form APCD-101 COLORADO Department of Public Health & Environment Company Contact Information Form Ver. September 10, 2008 Company Name: Crestone Peak Resources Operating, LLC Source Name: Regnier Farms 19H -B268 Battery (123-A037) Permit t Contact : Sabrina Pryor Address: 10188 East I-25 Frontage Road Street Firestone CO 80504 City State Zip Phone Number: 303-774-3923 Fax Number: E-mail: sabrina.pryor@crestonepr.com Billing Contact: [Permit Fees Sabrina Pryor Address: See Permit Contact Street City State Zip Phone Number: Fax Number: E-mail: Check how would you like to receive your permit fee invoice? Compliance Contact2: Taryn Weiner Address: 10188 East I-25 Frontage Road Street Firestone CO 80504 City State Zip Phone Number: 303-774-3908 Fax Number: E-mail: taryn.weiner@crestonepr.com Billing Contact:{ [Annual FeesZ. Taryn Weiner Address: See Compliance Contact Street City State Zip Phone Number: Fax Number: E-mail: Mail: E-mail: Fax: ❑ Footnotes: I The permit contact should be the point of contact for technical information contained in the permit application. This may be a company representative or a consultant. 2 The compliance contact should be the point of contact for discussing inspection and compliance at the permitted facility. 3 The billing contact (Permit fees) should be the point of contact that should receive the invoice for fees associated with processing the permit application & issuing the permit. (Reg. 3, Part A, Section VI.B) 4 The billing contact (Annual fees) should be the point of contact that should receive the invoices issued on an annual basis for fees associated with actual emissions reported on APENs for the facility. (Reg. 3, Part A, Section VI.C) Page 68 of 101 Attachment E Ambient Air Impact Analysis Page 69 of 101 Ambient Air Impact Analysis The Colorado Department of Public Health and Environment Colorado Modeling Guideline for Air Quality Permits (Modeling Guideline), draft version dated May 2018, states that the preliminary air impact analysis for construction permit applications can be done using quantitative (modeling) or qualitative (non -modeling) methods. Table 1 of the Modeling Guideline provides modeling thresholds that indicate modeling is usually warranted for new sources with an emission rate greater the threshold. Table 1 below provides the modeling thresholds and a determination if modeling is required for this application. Table 1. Ambient Air Impact Determination Pollutant Modeling Threshold Modeling Required? Carbon Monoxide (CO) 23 pounds per hour No Nitrogen Oxides (NOx) 40 tons per year No Sulfur Dioxide (SO2) 40 tons per year No Particulate matter <10 µm (PMlo) 82 pounds per day No Particulate matter <2.5 µm (PM2.$) 5 tons per year No 11 pounds per day No Lead (Pb) 25 pounds per 3 -months No Based upon these criterions, Crestone has determined that no modeling analysis is required as a part of this application. Page 70 of 101 Attachment F Facility Emissions Inventory APCD Form 102 Page 71 of 101 Form APCD-102 Company Name: Creston Peak Resources Operating, LLC Source Name: Regnier Emus 19H -B268 Soon AIRS ID: 123-A037 Colorado Department of Public Health and Environment Air Pollution Control Division Facility Wide Emissions Inventory Form Ver. April, 2015 Uncontrolled Potential to Emil (PIE) controlled Potential to Emit (MI Criteria (fF`l')• • ' HAYs IIbJyrl Cr Uric DTP ) 1I3APs(Ibs/yr) AIRS ID Equipment Description DP PA1111 PM112.5 SO2 NOx VOC CO I HMO Acetal Acro dL Tol Ea Xyl n -Hex Meth 223-T'MP TSP YM1110 YA12.5 SO2 NOx VOC CO I FICHO Acetal Acro WA Tot EH Xyl n-Hcx Meth 221-73AP 010 TANKS _ _ -_ _ _ 370.0 _ I _ _ _ 1165 1129_ 381 11,284 _ _ _ _ .. _ I -- _ - 58 56 2, 19 564-- I u 002 IM' - I _ -- _315 257 64 609- - - - - 1.2E-02 -021 -- _ _LI 0 1-- 003 LOAD -1 77.0 I — — — 235 — — — — — III 3v 6 1 -- — — 12 12 -- 0�2 IMO dollar 342X — I -- -- -- IZX13 1,566 Si 435 IY316X — x — — — -- 06 I).l 2] I -- — — JI )tl 1 -- 953 — U I Permitted Sources Subtotal= ADEN Only -Permit Exempt Sources 0.0 0.0 0.0 0.11 0.0 796.6 0.0 I U 0 0 3,535 3,1117 126 9611 33,310 U 33 0.0 0.0 0.0 0.0 1.4 39.8 6.4 I 0 0 0 161 146 6 4,5 1,63- II 2 006 L'ompmssco 01230 i2E-02 4.2E-02 4.2E-02 13,03 )3 n4 8.3 I 89 12 II ) 2 I.IE,-01 1 - 13 -- 4.2E-02 42E-02 4.2E-112 13E -a3 OA I.8 1 12 11 2 1.1E-nl 1 -- 13 �- 00> Compruseco4.2Eir 4.2E-02 4.2E-112 13E-03 8.3 I 89 12 11) 2 1.1E-111 1 - 13 - 7.2E-02 3.2E-112 13E-03 0.9 OA 1.8 1 89 12 11 7 2 1.1E-111 I It -- UX umpmeacoO1230 4.2E-02 4.2E-112 4.2E-02 1.3E-03 J3 0.1 1 ) 1.1E-01 I - 13 - 3.2E-02 4.2E-02 13E -m I 12 11 1.1,01 — — 009 sxc. G1230 E-02 12E-02 1.3E-03 II.3 I 89 12 11 J 1.1E-11 1I 4.2E02 4.2E-02 7,2E -1H 1 X I 89 L2 II) _ 1.1E1.1E,01— 13 — 1110 Compressor 01230 2£-02 4.2E-02 4,2E-02 13Ei13 11.1 tl0Y _3 I X 12 I I 1.1E-111 I - 13 -- 4.2E-02 4.2E-02 4.2E-02 1.3E-03 1.x I X 12 11 ) 1.1.1 - 13 - 1111 Compressu.G1230 4.2E-02 4.2E-02 32E-02 13E-113 ],] of X tl9 I 12 11 J 2 I.IE-01 1 - 13 -- _ 4.+E-112 6.2E-112 4.2E-112 1.3E-03 O.Y 11. 4 IN tl'J 1 12 11 ] + _ I.IE-111 I — 13 -- 012 cnG1230 32,112 4.2E-02 4.2,02 13E -0i ]3 X X 12 11 I.IE-01 1 - 13 - _E-02 4.2E-112 4.2E-112 13E.-03 0.4 IX x 12 ] 2 1.1E-111 — 13 — 013 Compress,. G1230 4.2E-02 3.2E-02 3.2E-112 1..3E-03 73 nA X3 ; 69 12 II J - I.IE-01 1 -- 13 — 12,02 12E-02 J2E-112 1.3E-03 0.9 0.4 1.8 . tl9 12 11 > 2 EIE-111 1 — 13 — APEN Only Muml= APEN Exempt/ Insignimmnl sour es OJ OJ UJ O.0 56.5 36 66.2 1 713 9] YI 55 I9 t 7 U 106 n O.J 0.3 0.3 0.0 ).1 ].6 13.E 1 )IJ Y) 91 .5< IY I J U 106 U Exempl IIi Low Suparumro(10 112 112 112 1,E-112 23 I 1.1 a.0 r _ J -- — I0E-01 I.fi,01 — — x] — — 11. 2 U. 2 11. 2 1.4E-02 3.3 01 2.0 J -- - 1. uEAI 1.6E-111 -- — 87 -- — Exempt dull Healer Thaler 0.1 0.1 0.1 J6E-n3 UX 4.2E -n2 n6 I 1 — — 3.2F.-112 5.2[-112 — — 2X — -- 11.1 U.1 n.l 4.6E413 O.X E- 4.2' U2 1. 16 1 -- — 3.2E-0+ 5.2E -U2 - - - — 0U5 NG - - - - - U.J -- I -- -- -- 3 111 1 13 31 - II - -- - - - n] - I _ _ _ 3 10 1 13 31 -- U 1 1 Insignificant Subtotal= Total, All Sources= 0.2 0.2 0.2 0.0 3.2 0.9 2.7 I 5 U 0 l IU 1 Il IM u 0 0.2 0.2 0.2 0.0 3.2 0.9 2.7 1 5 0 U 3 10 1 13 146 II o 0.6 0.6 0.6 11.0 61.) 801.0 68.8 I 71] 9) YI 3,594 3,216 129 WM 33,456 106 33 0.6 0.6 11.6 0.11 11.) 44.2 233 I 71) 9) 91 219 176 8 65 1,781 106 2 Uncontrolled HAN Summary(TPV11 Uncontrolled TARI,M, HAPS(Tell i Controlled HAP. Summary Cnnrnnm Tnal, All HAPs(TP1')4 0.36 II 0.048 10.0461 EXo I 1.61 I 006 I 0.49 I 16.) I nits I 0016 CM') all J6 176 I 0.05 1 0.051 1.11 I 0.09 10.00101 0.03 I 0.89 I 005 I 0.0009 4=I I r.a 1 Footnotes: 1. This form should be completed to include both existing sources mid all proposed new or modifications to existing emissions sources 2. lithe emissions source is new then enter "proposed" under the Pemlit No. and AIRS Ill data columns 3. HAP abbreviations include: BZ =Benzene Tn1= Toluene EB = Ethylbenzene Xyl = Xylene HCHO = Formaldehyde 4. APEN Exempt/Insignificant Sources should be included when warranted. Crestone Peak Resources Operating, LLC 224-TMP = 2,2,4-Trimethylpentane Acetal = Acetaldehyde Acro = Acmlein n -Hex = n -Hex Meth = Methanol Page 72 of 101 12/3/2020 Attachment G Process Description and Flow Diagram Page 73 of 101 Process Description The Regnier Farms 19H -B268 Battery is an oil and gas production facility located in Weld County, Colorado. The eleven (11) wells on site each produce through high/low pressure separators. • Hydrocarbon liquids from the low-pressure side of separators are routed to a common bulk heater treater for further gas, oil and water separation. The oil from the heater treater is routed through a vapor recovery tower (VRT) before being sent to the condensate storage tanks. Produced water from the low-pressure side of the separators as well as the heater treater is routed directly to water storage tanks. Condensate and produced water storage tank emissions are routed to enclosed combustors for control. Condensate is transferred out of the facility either by pipeline or truck. Produced water is transported from the facility by trucks. The storage tank battery consists of eight (8) 750 -barrel condensate storage tanks and two (2) 750 -barrel water storage tanks. • Gas from the low-pressure side of the separators are routed to the buffer house where liquid is knocked out. The low-pressure gas is then routed to the sales line via vapor recovery units (VRU). In the event the VRUs are offline, gas is sent to enclosed combustors for control. • Gas from the high-pressure side of the separators is directed to the sales line via VRU. In the event the sales line is unavailable or VRUs are offline the site is shut in. The Regnier Farms 19H -B268 Facility consists of a bank of eight (8) enclosed combustors for control of the condensate storage tanks, produced water storage tanks, hydrocarbon liquid loadout to trucks and the low- pressure separator venting. Page 74 of 101 Figure 1. Process Flow Diagram CWellheads /Water Loadout Produced o Truck;/ Gas to ECD Produced Water Tanks PW Low Pressure Gas to PCP Low Pressure Gas 10 VBU High Pressure Gas to Sales Separators Produced Water Gas to ECD 1 / Condensate Loadout to Trucks LOAD -1/ Gas to ECD Condensate Storage Tanks \ TANKS Gas from VRT Condensate Vapor Recovery Tower Condensate Page 75 of 101 Attachment H Operating and Maintenance (0&M) Plan: Form APCD-304 — O&M Plan for Condensate Storage Tanks - AIRS 123-A037-001 Form APCD-307 — 0&M Plan for Produced Water Storage Tanks - AIRS 123-A037-002 Form APCD-312 —0&M Plan for Hydrocarbon Liquid Loadout—AIRS 123-A037-003 Form APCD-309 — O&M Plan for Separators Form -309 — Buffer — AIRS 123-A037-004 Page 76 of 101 CDPHE COLORADO Air Pollution Control Division Department of Public Health b Envtronment Form APCD-304 APCD Internal Use, Only Received Date Approved? ❑ 'Approval Date Operating and Maintenance Plan Template for Condensate Storage Tanks Ver. January 27, 2020 The Air Pollution Control Division developed this Operating and Maintenance Plan (O&M Plan) for condensate storage tanks that use emissions controls, permitted at synthetic minor and major oil and gas facilities in the State of Colorado. One OEtM Plan may be used for multiple tanks at one facility if each are controlled and monitored in the same manner. An OEtM Plan shall be submitted with the permit application when required. The facility operator must comply with the requirements of the oam Plan upon commencement of operation. An existing approved OEtM Plan may be modified without a permit modification or permit reissuance, but the operator must adhere to the requirements of the existing approved O8th Plan until an approval letter is issued for the new OEtM Plan. The operator is required to use the division -developed O8th Plan template forms in order to meet minimum expectations within a standard, organized format. Do not modify the structure and/or content of this template. If the facility or emissions unit is subject to other state or federal regulations with duplicative requirements, the operator must follow the most stringent regulatory requirement. Please note that O8th requirements are different for facilities in the Denver Metro and North Front Range 8 -hour ozone nonattainment area. For sources that are subject to the Title V Operating Permits program: In accordance with Colorado Regulation No. 3, Part C, Section V.C.5., some or all of the monitoring specified in this OEtM plan will be incorporated as specific conditions in the source's Title V Operating Permit (if applicable). Additional monitoring not listed in this O8th Plan may be included in the source's Operating Permit in order to satisfy the periodic monitoring requirements of Regulation No. 3, Part C, Section V.C.5.b. Submittal Date: December 3, 2020 Section 1 - Source Identification For new permits, some of this information (i.e., Facility AIRS ID, Permit Number, and AIRS Point ID) may not be known at the time of application. Please only fill in the fields that are known and leave the others blank. Company Name: Crestone Peak Resources Facility Operating, LLC Location: SWSE Sec 18 T2N R68W NWNE Sec 19 T2N R68W Facility Name: Regnier Farms 19H -B268 Facility AIRS ID (for existing facilities) 123 - A037 Battery Is this facility located in the Denver Metro and North Front Range 8 -hour ozone nonattainment area? ® Yes ❑ No Emission Units Covered by this OaM form Facility Equipment ID Permit Number TANKS 19WE0334 AIRS Point ID 001 Page 1 of 4 Page 77 of 101 CDPHE COLORADO Air Pollution Control Division Department of Public Health 8 Environment Section 2 - Maintenance Schedules Check one of the following: Facility shall follow manufacturer recommendations for the operation and maintenance of the emissions unit and control devices. These schedules and practices, as well as all maintenance records showing compliance with these recommendations, shall be made available to the division upon request. Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of emissions unit and control devices. These schedules and practices, as well as all maintenance records showing adherence to these practices, shall be made available to the division upon request and shall be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard (NSPS) general conditions. Section 3 - Recordkeeping Requirements The following box must be checked for the 0&M Plan to be considered complete: Synthetic minor and major sources are required to maintain maintenance and monitoring records for the requirements of this OEtM Plan for a period of five (5) years. If applicable state requirements or any Federal NSPS, NESHAP, or MACT require a longer record retention period, the operator must comply with the longest record retention requirement. Section 4 - Monitoring Requirements Check one of the following two boxes: Check this box to confirm that the storage tank(s) are subject to the requirements of Regulation No. 7, Sections XVII.C.2. and C.3 (Storage Tank Emission Management System "STEM"). By checking this box, the operator confirms adherence to the operating, maintenance, and recordkeeping requirements of STEM as developed and implemented by the operator, as required by Regulation No. 7, Sections XVII.C.2. and C.3. @ Check this box if the storage tank(s) are not subject to the requirements of Regulation No. 7, Sections XVII.C.2. and C.3. ("STEM"). Leakage to the atmosphere shall be minimized as follows: • Thief hatch seals shall be inspected monthly for integrity and replaced as necessary; • Thief hatch covers shall be properly weighted and seated to ensure flashing, working, and breathing losses (as applicable) are routed to the control device under normal operating conditions; • Pressure relief valves (PRV) shall be inspected monthly for proper operation and repaired or replaced as necessary; • PRVs shall be set to release at a pressure that will ensure flashing, working, and breathing losses (as applicable) are routed to the control device under normal operating conditions; and • Inspections shall be documented with an indication of status, a description of any problems found, and their resolution (e.g., adjustments made to thief hatch weight cover weight or PRV setpoint, including the modified settings). Page 2 of 4 Page 78 of 101 COLORADO Air Pollution Control Division Department of Publtc Health b Environment Table 1 below details the monitoring parameters and frequency for control equipment depending on the type of control equipment and the requested permitted emissions at the facility. Indicate the storage tank emissions control by checking the appropriate boxes. In addition, check the appropriate box for "Monitoring Frequency" based on the facility attainment area status and facility -wide permitted VOC emissions. Table 1 Emissions Control or Recycling Method Parameter Monitoring Frequency Ozone Nonattainment Area Ozone Attainment Areas ❑ Permitted Facility Emissions z 40 tpy VOC ❑ Permitted Facility Emissions z 80 tpy VOC ❑ Permitted Facility Emissions < 80 tpy VOC O Permitted Facility Emissions < 40 tpy VOC Enclosed Flare or Elevated Open Flare a Pilot Light / Auto - igniter Monitoring and Visible Emissions Observation Daily b' c Weekly b' c Daily b' c Weekly b' c ►� Vapor Recovery Unit (VRU) or Recycled or Closed Loop System d ❑ Monitorin requirementsincludin g q g parameters and frequency, to be determined by the operator and listed below in footnote d. Other ❑ Monitoring requirements, including specific parameters and frequency, to be described in Section 5 below, and approved by the division. a Elevated Open Flare If the storage tank is subject to Regulation No. 7, Section XII or Section XVII, the use of an open flare must be approved by the division as an alternate emission control device prior to operation in accordance with Regulation No. 7 Section XVI1.B.2.e.; see PS Memo 15-03. Open flares permitted prior to May 1, 2014 are approved for operation. All new open flares permitted on or after May 1, 2014 are required to obtain division approval prior to operation. b Pilot Light Monitoring Options If the tanks are controlled by combustion device, then the operator must indicate in Table 2 the primary method by which the presence of a pilot light will be monitored. One primary method for Pilot Light Monitoring must be checked and, optionally, secondary methods may be checked. Table 2: Pilot Light Monitoring Primary Secondary Monitoring Method /1 ❑ Visual Inspection ❑ ❑ Optical Sensor ❑ L Auto -Igniter Signal ❑ ❑ Thermocouple Page 3 of 4 Page 79 of 101 COLORADO Air Pollution Control Division Department of Public Health b Environment Visible Emissions Observation and Method 22 Options At the frequency specified in Table 1, the operator is required to conduct an inspection of the subject combustion device for the presence or absence of smoke (e.g., visible emissions). If smoke is observed during the visible emissions inspection, the operator has the option to either (1) immediately shut-in the emissions unit to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (2) conduct a formal Method 22 observation to determine whether visible emissions (as defined per Regulation No. 7, Section XVII.A.17.) are present. If a Method 22 is conducted, the record of the observations shall be maintained as required in Section 3 of this Ol*M Plan (Reference: Regulation No. 7, Section XVII.C.3.d). If visible emissions are observed by Method 22, the operator shall immediately conduct any necessary repairs and maintain records of the specific repairs completed; if repair cannot be immediately completed, the operator shall shut-in the emissions unit, conduct any necessary repairs, and maintain records of the specific repairs completed. If the emissions unit is subject to Regulation No. 7, Section XII.E, operators must document the required inspections for the presence or absence of smoke. The division has historically approved a "check box" to satisfy the documentation procedures referenced in Section XII. The division will continue to accept the "check box" recordkeeping format in instances where no visible emissions are observed in order to demonstrate compliance with Regulation No. 7 Section XII.E.4.a. d Vapor Recovery Unit (VRU) or Recycled or Closed Loop System In the space provided below, please provide a description of the emission control or recycling system, including an explanation of parameters monitored, monitoring frequency, and how the system design ensures that emissions are being routed to the appropriate system at all times, or during all permitted runtime. Also, provide a description of how downtime is tracked and recorded. Section 5 - Additional Notes and OaM Activities Please use this section to describe any additional notes or operation and maintenance activities, or if additional space is needed from a previous section. Attach additional pages if necessary. Page 4 of 4 Page 80 of 101 CDPHE COLORADO Air Pollution Control Division Department of Public Health £r Environment Form APCD-307 APCD Internal Use Only Received Date Approved? ❑ Approval Date Operating and Maintenance Plan Template for Produced Water Storage Tanks Ver. January 27, 2020 The Air Pollution Control Division developed this Operating and Maintenance Plan (atM Plan) for produced water storage tanks that use emissions controls, permitted at synthetic minor and major oil and gas facilities in the State of Colorado. One O&M Plan may be used for multiple produced water storage tanks at one facility if each are controlled and monitored in the same manner. An atM Plan shall be submitted with the permit application when required. The facility operator must comply with the requirements of the Oath Plan upon commencement of operation. An existing approved O&M Plan may be modified without a permit modification or permit reissuance, but the operator must adhere to the requirements of the existing approved atM Plan until an approval letter is issued for the new O&M Plan. The operator is required to use the division -developed atM Plan template forms in order to meet minimum expectations within a standard, organized format. Do not modify the structure and/or content of this template. If the facility or emissions unit is subject to other state or federal regulations with duplicative requirements, the operator must follow the most stringent regulatory requirement. Please note that O£tM requirements are different for facilities in the Denver Metro and North Front Range 8 -hour ozone nonattainment area. For sources that are subject to the Title V Operating Permits program: In accordance with Colorado Regulation No. 3, Part C, Section V.C.5., some or all of the monitoring specified in this OItM plan will be incorporated as specific conditions in the source's Title V Operating Permit (if applicable). Additional monitoring not listed in this atM Plan may be included in the source's Operating Permit in order to satisfy the periodic monitoring requirements of Regulation No. 3, Part C, Section V.C.5.b. Submittal Date: December 3, 2020 Section 1 - Source Identification For new permits, some of this information (i.e., Facility AIRS ID, Permit Number, and AIRS Point ID) may not be known at the time of application. Please only fill in the fields that are known and leave the others blank. Company Name: Crestone Peak Resources Facility Operating, LLC Location: Facility Name: Regnier Farms 19H -B268 Battery Is this facility located in the Denver Metro and North Front Range 8 -hour ozone nonattainment area? ® Yes ❑ No SWSE Sec 18 T2N R68W NWNE Sec 19 T2N R68W Facility AIRS ID (for existing facilities) 123 - A037 Emission Units Covered by this OEM form PW Facility Equipment ID Permit Number 19WE0334 AIRS Point ID 002 Page 1 of 4 Page 81 of 101 CDPHE COLORADO Air Pollution Control Division Department of Public Health & Environment Section 2 - Maintenance Schedules Check one of the following: 11 Facility shall follow manufacturer recommendations for the operation and maintenance of the emissions unit and control devices. These schedules and practices, as well as all maintenance records showing compliance with these recommendations, shall be made available to the division upon request. Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of the emissions unit and control devices. These schedules and practices, as well as all maintenance records showing adherence to these practices, shall be made available to the division upon request and shall be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard (NSPS) general conditions. Section 3 - Recordkeeping Requirements The following box must be checked for the O&M Plan to be considered complete: Synthetic minor and major sources are required to maintain maintenance and monitoring records for the requirements of this OEtM Plan for a period of five (5) years. If applicable state requirements or any Federal NSPS, NESHAP, or MACT require a longer record retention period, the operator must comply with the longest record retention requirement. Section 4 - Monitoring Requirements Check one of the following two boxes: Check this box to confirm that the storage tank(s) are subject to the requirements of Regulation No. 7, Sections XVII.C.2. and C.3 (Storage Tank Emission Management System "STEM"). By checking this box, the operator confirms adherence to the operating, maintenance, and recordkeeping requirements of STEM as developed and implemented by the operator, as required by Regulation No. 7, Sections XVII.C.2. and C.3. 1 ❑ Check this box if the storage tank(s) are not subject to the requirements of Regulation No. 7, Sections XVII.C.2. and C.3. ("STEM"). Leakage to the atmosphere shall be minimized as follows: • Thief hatch seals shall be inspected monthly for integrity and replaced as necessary; • Thief hatch covers shall be properly weighted and seated to ensure flashing, working, and breathing losses (as applicable) are routed to the control device under normal operating conditions; • Pressure relief valves (PRV) shall be inspected monthly for proper operation and repaired or replaced as necessary; • PRVs shall be set to release at a pressure that will ensure flashing, working, and breathing losses (as applicable) are routed to the control device under normal operating conditions; and • Inspections shall be documented with an indication of status, a description of any problems found, and their resolution (e.g., adjustments made to thief hatch weight cover weight or PRV setpoint, including the modified settings). Page 2 of 4 Page 82 of 101 CDPHE COLORADO Air Pollution Control Division Department of Public Health 8 Environment Table 1 below details the monitoring parameters and frequency for control equipment depending on the type of control equipment and the requested permitted emissions at the facility. Indicate the storage tank emissions control by checking the appropriate boxes. In addition, check the appropriate box for "Monitoring Frequency" based on the facility attainment area status and facility -wide permitted VOC emissions. Table 1 Emissions Control or Recycling Method Parameter Monitoring Frequency Ozone Nonattainment Area Ozone Attainment Areas ❑ Permitted Facility Emissions ≥ 40 tpy VOC ❑ Permitted Facility Emissions ≥ 80 tpy VOC ❑ Permitted Facility Emissions < 80 tpy VOC /1 Permitted Facility Emissions < 40 tpy VOC Enclosed Flare or Elevated Open Flare a Pilot Light / Auto - igniter Monitoring and Visible Emissions Observation Daily b, c Weekly b' ` Daily b' c Weekly I), ►1 Vapor Recovery Unit (VRU) or Recycled or Closed Loop System d ❑ Monitoring requirements, including parameters and frequency, to be determined by the operator and listed below in footnote d. Other ❑ Monitoring requirements, including specific parameters and frequency, to be described in Section 5 below, and approved by the division. a Elevated Open Flare If the storage tank is subject to Regulation No. 7, Section XII or Section XVII, the use of an open flare must be approved by the division as an alternate emission control device prior to operation in accordance with Regulation No. 7 Section XVI1.B.2.e.; see PS Memo 15-03. Open flares permitted prior to May 1, 2014 are approved for operation. All new open flares permitted on or after May 1, 2014 are required to obtain division approval prior to operation. b Pilot Light Monitoring Options If the tanks are controlled by combustion device, then the operator must indicate in Table 2 the method by which the presence of a pilot light will be monitored. One primary method for Pilot Light Monitoring must be checked and, optionally, secondary methods may be checked. Table 2: Pilot Light Monitoring Primary Secondary Monitoring Method r ❑ Visual Inspection ❑ ❑ Optical Sensor ❑ /1 Auto -Igniter Signal ❑ ❑ Thermocouple Page 3 of 4 Page 83 of 101 CDPHE COLORADO Air Pollution Control Division Department of Public Health 8 Environment Visible Emissions Observation and Method 22 Options At the frequency specified in Table 1, the operator is required to conduct an inspection of the subject combustion device for the presence or absence of smoke (e.g., visible emissions). If smoke is observed during the visible emissions inspection, the operator has the option to either (1) immediately shut-in the emissions unit to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (2) conduct a formal Method 22 observation to determine whether visible emissions (as defined per Regulation No. 7, Section XVII.A.17.) are present. If a Method 22 is conducted, the record of the observations shall be maintained as required in Section 3 of this OM Plan (Reference: Regulation No. 7, Section XVII.C.3.d). If visible emissions are observed by Method 22, the operator shall immediately conduct any necessary repairs and maintain records of the specific repairs completed; if repair cannot be immediately completed, the operator shall shut-in the emissions unit, conduct any necessary repairs, and maintain records of the specific repairs completed. d Vapor Recovery Unit (VRU) or Recycled or Closed Loop System In the space provided below, please provide a description of the emission control or recycling system, including an explanation of parameters monitored, monitoring frequency, and how the system design ensures that emissions are being routed to the appropriate system at all times, or during all permitted runtime. Also, provide a description of how downtime is tracked and recorded. Section 5 - Additional Notes and O&M Activities Please use this section to describe any additional notes or operation and maintenance activities, or if additional space was required for a previous section. Attach additional pages if necessary. Page 4 of 4 Page 84 of 101 CDPHE COLORADO Air Pollution Control Division Department of Public Health & Environment Form APCD-312 APCt) internal Use Onty , Received Date Approved? ❑ Approval Date Operating and Maintenance Plan Template for Hydrocarbon Liquid Loadout Ver. January 27, 2020 The Air Pollution Control Division developed this Operating and Maintenance Plan (OEtM Plan) for hydrocarbon liquid loadout activities that use emissions controls, permitted at synthetic minor and major oil and gas facilities in the State of Colorado. One OEtM Plan may be used for multiple loadouts at one facility if each are controlled and monitored in the same manner. An O&M Plan shall be submitted with the permit application when required. The facility operator must comply with the requirements of the oam Plan upon commencement of operation. An existing approved OEtM Plan may be modified without a permit modification or permit reissuance, but the operator must adhere to the requirements of the existing approved O&M Plan until an approval letter is issued for the new OEtM Plan. The operator is required to use the division -developed OEtM Plan template forms in order to meet minimum expectations within a standard, organized format. Do not modify the structure and/or content of this template. If the facility or emissions unit is subject to other state or federal regulations with duplicative requirements, the operator must follow the most stringent regulatory requirement. Please note that OEtM requirements are different for facilities in the Denver Metro and North Front Range 8 -hour ozone nonattainment area. For sources that are subject to the Title V Operating Permits program: In accordance with Colorado Regulation No. 3, Part C, Section V.C.5., some or all of the monitoring specified in this oam plan will be incorporated as specific conditions in the source's Title V Operating Permit (if applicable). Additional monitoring not listed in this OEtM Plan may be included in the source's Operating Permit in order to satisfy the periodic monitoring requirements of Regulation No. 3, Part C, Section V.C.5.b. Submittal Date: December 3, 2020 Section 1 - Source Identification For new permits, some of this information (i.e., Facility AIRS ID, Permit Number, and AIRS Point ID) may not be known at the time of application. Please only fill in the fields that are known and leave the others blank. Company Name: Crestone Peak Resources Facility Location: SWSE Sec 18 T2N R68W Facility Name: Operating, LLC NWNE Sec 19 T2N R68W Regnier Farms 19H -B268 Facility AIRS ID (for existing facilities) 123 - A037 Battery Is this facility located in the Denver Metro and North Front Range 8 -hour ozone nonattainment area? ® Yes ❑ No Loadout Sources Covered by this 0&M form Facility Equipment ID LOAD -1 Permit Number 19WE0334 AIRS Point ID 003 Page 1 of 4 Page 85 of 101 COLORADO Air Pollution Control Division Department of Public Health & Environment Section 2 - Maintenance Schedules Check one of the following: Facility shall follow manufacturer recommendations for the operation and maintenance of the emissions unit and control devices. These schedules and practices, as well as all maintenance records showing compliance with these recommendations, shall be made available to the division upon request. Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of the emissions unit and control devices. These schedules and practices, as well as all maintenance records showing adherence to these practices, shall be made available to the division upon request and shall be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard (NSPS) general conditions. Section 3 - Recordkeeping Requirements The following box must be checked for the O&M Plan to be considered complete: Synthetic minor and major sources are required to maintain maintenance and monitoring records for the requirements of this OltM Plan for a period of five (5) years. If applicable state requirements or any Federal NSPS, NESHAP, or MACT require a longer record retention period, the operator must comply with the longest record retention requirement. Section 4 -Monitoring Requirements Control Equipment Information Check the appropriate box below that describes the technique used to collect truck loadout vapors. Vapor balance connects the truck vapor headspace to the storage tanks, and the displaced vapors are controlled along with storage tank vapors. Direct connection to combustion device, not via storage tanks. Other (describe in Section 5). Page 2 of 4 Page 86 of 101 CDPHE COLORADO Air Pollution Control Division Department of Public Health Er Environment Table 1 below details the monitoring parameters and frequency for control equipment depending on the type of control equipment and the requested permitted emissions at the facility. Indicate the emissions control by checking the appropriate boxes. In addition, check the appropriate box for "Monitoring Frequency" based on the facility attainment area status and facility -wide permitted VOC emissions. Table 1 Emissions Control or Recycling Method Parameter Monitoring Frequency Ozone Nonattainment Area Ozone Attainment Areas ❑ Permitted Facility Emissions ≥ 40 tpy VOC ❑ Facility Emissions ≥ 80 tpy VOC ❑ Permitted Facility Emissions < 80 tpy VOC aPermitted Permitted Facility Emissions < 40 tpy VOC Enclosed Flare or Elevated Open Flare a Pilot Light / Auto - igniter Monitoring and Visible Emissions Observation Daily b' c Weekly b' c Daily b' ` Weekly b' c ►L Vapor Recovery Unit (VRU) or Recycled or Closed Loop System d ❑ Monitoring requirements, including parameters and frequency, to be determined by the operator and listed below in footnote d. Other ❑ Monitoring requirements, including specific parameters and frequency, to be described in Section 5 below, and approved by the division. a Elevated Open Flare An open flare permitted after May 1, 2014 and used to comply with Regulation No. 7 Section XVII must be approved by the division as an alternate emission control device prior to operation, in accordance with Regulation No. 7 Section XVI1.B.2.e.; see PS Memo 15-03. b Pilot Light Monitoring Options If emissions are controlled by combustion device, then the operator must indicate in Table 2 the method by which the presence of a pilot light will be monitored. One primary method for Pilot Light Monitoring must be checked and, optionally, secondary methods may be checked. Table 2: Pilot Light Monitoring Primary Secondary Monitoring Method // ❑ Visual inspection ❑ ❑ Optical Sensor ❑ // Auto -Igniter Signal ❑ ❑ Thermocouple Page 3 of 4 Page 87 of 101 CDPHE COLORADO Air Pollution Control Division . Department of Public Health b Environment Visible Emissions Observation and Method 22 Options At the frequency specified in Table 1, the operator is required to conduct an inspection of the subject combustion device for the presence or absence of smoke (e.g., visible emissions). If smoke is observed during the visible emissions inspection the operator has the option to either (1) immediately shut-in the emissions unit to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (2) conduct a formal Method 22 observation to determine whether visible emissions (as defined per Regulation No. 7, Section XVII.A.17.) are present. If a Method 22 is conducted, the record of the observations shall be maintained as required in Section 3 of this O&M Plan (Reference: Regulation No. 7, Section XVII.C.3.d). If visible emissions are observed by Method 22, the operator shall immediately conduct any necessary repairs and maintain records of the specific repairs completed; if repair cannot be immediately completed, the operator shall shut-in the emissions unit, conduct any necessary repairs, and maintain records of the specific repairs completed. If the emissions unit is subject to Regulation No. 7, Section XII.E, operators must document the required inspections for the presence or absence of smoke. The division has historically approved a "check box" to satisfy the documentation procedures referenced in Section XII. The division will continue to accept the "check box" recordkeeping format in instances where no visible emissions are observed in order to demonstrate compliance with Regulation No. 7 Section XII.E.4.a. If a flare is not subject to Regulation No. 7 requirements (as described in the permit), a similar approach may be employed where the operator may conduct an inspection for presence or absence of smoke, and if smoke is observed the operator has the option to (1) immediately conduct repairs and maintain records of the specific repairs completed; (2) shut-in the emissions unit to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (3) conduct a formal Method 9 observation to determine the opacity of the visible emissions, and conduct repairs if necessary.. d Vapor Recovery Unit (VRU) or Recycled or Closed Loop System In the space provided below, please provide a description of the emission control or recycling system, including an explanation of parameters monitored, monitoring frequency, and how the system design ensures that emissions are being routed to the appropriate system at all times, or during all permitted runtime. Also, provide a description of how downtime is tracked and recorded. Section 5 - Additional Notes and O£tM Activities Please use this section to describe any additional notes or operation and maintenance activities, or if additional space is needed from a previous section. Attach additional pages if necessary. Page 4 of 4 Page 88 of 101 Form APCD-309 CDPHE COLORADO Air Pollution Control Division Department of Public Health Er Environment APCD Internal Use Only Received Date Approved? ❑ Approval Date Operating and Maintenance Plan Template for Separators' Ver. January 27, 2020 This term "separators" is intended throughout to include two-phase separators, three-phase separators, high/low pressure separators, heater -treaters, vapor recovery towers, etc., and the associated air pollution control equipment. The Air Pollution Control Division developed this Operating and Maintenance Plan (oam Plan) for separators that use emissions controls, permitted at synthetic minor and major oil and gas facilities in the State of Colorado. One OEtM Plan may be used for multiple separators at one facility if each are controlled and monitored in the same manner. An oam Plan shall be submitted with the permit application when required. The facility operator must comply with the requirements of the O&M Plan upon commencement of operation. An existing approved O&M Plan may be modified without a permit modification or permit reissuance, but the operator must adhere to the requirements of the existing approved OEtM Plan until an approval letter is issued for the new OEtM Plan. The operator is required to use the division -developed OEtM Plan template forms in order to meet minimum expectations within a standard, organized format. Do not modify the structure and/or content of this template. If the facility or emissions unit is subject to other state or federal regulations with duplicative requirements, the operator must follow the most stringent regulatory requirement. Please note that atM requirements are different for facilities in the Denver Metro and North Front Range 8 -hour ozone nonattainment area. For sources that are subject to the Title V Operating Permits program: In accordance with Colorado Regulation No. 3, Part C, Section V.C.5., some or all of the monitoring specified in this OEtM plan will be incorporated as specific conditions in the source's Title V Operating Permit (if applicable). Additional monitoring not listed in this oam Plan may be included in the source's Operating Permit in order to satisfy the periodic monitoring requirements of Regulation No. 3, Part C, Section V.C.5.b. Submittal Date: December 3, 2020 Section 1 - Source Identification For new permits, some of this information (i.e., Facility AIRS ID, Permit Number, and AIRS Point ID) may not be known at the time of application. Please only fill in the fields that are known and leave the others blank. Company Name: Crestone Peak Resources Operating, LLC Facility Location: SWSE Sec 18 T2N R68W NWNE Sec 19 T2N R68W Facility Name: Regnier Farms 19H -B268 Facility AIRS ID (for existing facilities) 123 - A037 Battery Is this facility located in the Denver Metro and North Front Range 8 -hour ozone nonattainment area? Facility Equipment ID Permit Number ® Yes ❑ No Emission Units Covered by this O&M form Buffer 19WE0334 Page 1 of 5 Page 89 of 101 CDPHE I AIRS Point ID COLORADO Air Pollution Control Division Department of Public Health & Environment 004 Section 2 - Maintenance Schedules Check one of the following: El o i Facility shall follow manufacturer recommendations for the operation and maintenance of the emissions unit and control devices. These schedules and practices, as well as all maintenance records showing compliance with these recommendations, shall be made available to the division upon request. Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of the emissions unit and control devices. These schedules and practices, as well as all maintenance records showing adherence to these practices, shall be made available to the division upon request and shall be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard (NSPS) general conditions. Confirm the following requirement, if the separator has a pressure relief valve (PRV): The operator shall inspect the separator pressure relief valve (PRV) at a minimum once every calendar year. The inspection shall include a check that the PRV set point is adequate to ensure that emissions are routed to the emissions control device during normal operation. Records of these inspections, and any repairs, shall be made available to the division upon request. Section 3 - Recordkeeping Requirements The following box must be checked for the O&M Plan to be considered complete: Synthetic minor and major sources are required to maintain maintenance and monitoring records for the requirements of this O&M Plan for a period of five (5) years. If applicable state requirements or any Federal NSPS, NESHAP, or MACT require a longer record retention period, the operator must comply with the longest record retention requirement. Page 2 of 5 Page 90 of 101 CDPHE COLORADO Air Pollution Control Division Department of Public Health £r Environment Section 4 - Monitoring Requirements Emission Unit Information The following boxes must be checked for the 0&M Plan to be considered complete: Attach a diagram or plot plan of the configuration of the separator(s), control device(s), and vapor recovery unit(s), as well as the location(s) of flow meters. This diagram is required in addition to the facility -wide diagram required for new permit applications. This diagram shall be retained with the oftM Plan for reference by the operator and division inspector. The permit requires calculation and recordkeeping of actual emissions from this source, but the calculation methods are not incorporated into the permit. In the space below, describe the formulas used to calculate the volume of gas vented from the separator and sent to the control device, using data from the meter if required. If using a vapor recovery tower (VRT), describe the method used to calculate the volume of gas vented from the VRT. If the permit throughput limit is in terms of hydrocarbon liquid, then in the space below describe how the liquid throughput shall be tracked. Examples: Flow meter at enclosed flare directly measures the volume of gas sent to flare from a single separator. OR Volume from low pressure separator sent to control device = (Metered volume through high pressure separator) - (Metered volume through low pressure separator) OR Volume vented from VRT = (Total gas volume metered at flare) - (Metered volume to flare from low pressure separator) - (Volume to flare from tanks) OR Permit throughput limit is based on hydrocarbon liquid, which is tracked by tank inlet meter, with backup of sales/haul tickets. OR etc. Please be clear and specific about the sources of input data, and describe how the input data is collected and recorded. Attach additional pages if needed. A flow meter is installed prior to the enclosed combustor device (ECD) to directly measure the total volume of gas sent to the ECD from the low pressure side of all separators and routed through the buffer house. Page 3 of 5 Page 91 of 101 CDPHE COLORADO Air Pollution Control Division Department of Public Health b Environment Control Equipment Information Table 1 below details the monitoring parameters and frequency for control equipment depending on the type of control equipment and the requested permitted emissions at the facility. Indicate the separator emissions control by checking the appropriate boxes. In addition, check the appropriate box for "Monitoring Frequency" based on the facility attainment area status and facility -wide permitted VOC emissions. Table 1 Emissions Control or Recycling Method Parameter Monitoring Frequency Ozone Nonattainment Area Ozone Attainment Areas ❑ Permitted Facility Emissions a 40 tpy VOC ❑ Permitted Facility Emissions a 80 tpy VOC ❑ Permitted Facility Emissions < 80 tpy VOC /1 Permitted Facility Emissions < 40 tpy VOC Enclosed Flare or Elevated Open Flare a Pilot Light / Auto - igniter Monitoring and Visible Emissions Observation Daily b' ` Weekly b' c Daily b' ` Weekly b' c ..- Vapor Recovery Unit (VRU) or Recycled or Closed Loop System d ❑ Monitoring requirements, including parameters and frequency, to be determined by the operator and listed below in footnote d. Other ❑ Monitoring requirements, including specific parameters and frequency, to be described in Section 5 below, and approved by the division. a Elevated Open Flare An open flare permitted after May 1, 2014 and used to comply with Regulation No. 7 Section XVII must be approved by the division as an alternate emission control device prior to operation, in accordance with Regulation No. 7 Section XVII.B.2.e.; see PS Memo 15-03. b Pilot Light Monitoring Options If emissions are controlled by combustion device, then the operator must indicate in Table 2 the method by which the presence of a pilot light will be monitored. One primary method for Pilot Light Monitoring must be checked and, optionally, secondary methods may be checked. Table 2: Pilot Light Monitoring Primary Secondary Monitoring Method /1 ❑ Visual Inspection ❑ ❑ Optical Sensor ❑ r Auto -Igniter Signal ❑ ❑ Thermocouple Page 4 of 5 Page 92 of 101 CDPHE COLORADO Air Pollution Control Division Department of Public Health b Environment Visible Emissions Observation and Method 22 Options At the frequency specified in Table 1, the operator is required to conduct an inspection of the subject combustion device for the presence or absence of smoke (e.g., visible emissions). If smoke is observed during the visible emissions inspection, the operator has the option to either (1) immediately shut-in the emissions unit to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (2) conduct a formal Method 22 observation to determine whether visible emissions (as defined per Regulation No. 7, Section XVII.A.16.) are present. If a Method 22 is conducted, the record of the observations shall be maintained as required in Section 3 of this atM Plan (Reference: Regulation No. 7, Section XVII.C.3.d). If visible emissions are observed by Method 22, the operator shall immediately conduct any necessary repairs and maintain records of the specific repairs completed; if repair cannot be immediately completed, the operator shall shut-in the emissions unit, conduct any necessary repairs, and maintain records of the specific repairs completed. If the emissions unit is subject to Regulation No. 7, Section XII.E, operators must document the required inspections for the presence or absence of smoke. The division has historically approved a "check box" to satisfy the documentation procedures referenced in Section XII. The division will continue to accept the "check box" recordkeeping format in instances where no visible emissions are observed in order to demonstrate compliance with Regulation No. 7 Section XII.E.4.a. If a flare is not subject to Regulation No. 7 requirements (as described in the permit), a similar approach may be employed where the operator may conduct an inspection for presence or absence of smoke, and, if smoke is observed, the operator has the option to (1) immediately conduct repairs and maintain records of the specific repairs completed; (2) shut-in the emissions unit to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (3) conduct a formal Method 9 observation to determine the opacity of the visible emissions, and conduct repairs if necessary. d Vapor Recovery Unit (VRU) or Recycled or Closed Loop System In the space provided below, please provide a description of the emission control or recycling system, including an explanation of parameters monitored, monitoring frequency, and how the system design ensures that emissions are being routed to the appropriate system at all times, or during all permitted runtime. Also, provide a description of how downtime is tracked and recorded. Attach additional pages if necessary. Section 5 - Additional Notes and O&M Activities Please use this section to describe any additional notes or operation and maintenance activities, or if additional space is needed from a previous section. Attach additional pages if necessary. Page 5 of 5 Page 93 of 101 CWellheads Produced Water Loadout to Truck Low Pressure Gas to Sales--- --------High Pressure Gas to Sales Low Pressure Gas to ECD Low Pressure Gas to VRU High Pressure Gas to Sales Gas to ECD Produced Water Tanks PW Separators Produced Water Gas to ECD Condensate Loadoutto _ Trucks LOAD -1 Gas from VRT ^---Condensate Gas to ECD Condensate' Storage Tanks TANKS N _ Vapor Recovery Tower Condensate Pipeline Page 94 of 101 Attachment I Regulatory Analysis Page 95 of 101 Regulatory Analysis The Regnier Farms 19H-8268 Battery facility began production on February 23, 2020. When necessary, the regulatory analysis below uses this date for applicability. The regulatory analysis provided here is for the condensate tanks, produced water tanks, truck loadout, and the enclosed process flare and the facility -wide determinations associated with this permit application. 1.0 Federal New Source Review Non -attainment New Source Review Weld County was re -designated as serious non -attainment for ozone on January 27, 2020. Upon facility startup, the Regnier Farms 19H -B268 Battery became a major source in an ozone non -attainment area with potential facility -wide emissions of ozone precursors, Nitrogen Oxides (NOx) and Volatile Organic Compounds (VOC). With this modification request the Regnier Farms 19H -B268 Battery facility will become an existing synthetic minor source for VOC emissions, however it will remain an existing major source of NOx emissions only. New Source Review (NSR) applies to new or modified sources with emissions or net emission increases in excess of specified thresholds. Existing minor sources are subject to Non -Attainment New Source Review (NANSR) only if proposed increases in NOx or VOC emissions constitute a major stationary source in and of themselves (Colorado Regulation 3, Part D, Section II.A.25.c.). Under serious non -attainment, the major stationary source threshold is 50 tpy of either NOx or VOC. NANSR is triggered by any modification to an existing major source that increases potential emission of NOx or VOC by 25 tpy or more. The projected change in emissions associated with this permit application indicates an increase of less than 25 tpy of both NOx and VOC, therefore this modification to the Regnier Farms 19H -B268 facility is not subject to additional NANSR review under the NSR thresholds. Potential for Significant Deterioration Specific source types are subject to Prevention of Significant Deterioration (PSD) review if their potential to emit (PTE) exceeds 100 tpy of any regulated NSR pollutant. All other source types are subject to PSD review if their PTE exceeds 250 tpy. This facility is not one of the listed source types and does not exceed a PTE of 250 tpy of any regulated NSR pollutant; therefore, this facility is not subject to PSD review. 2.0 Federal Operating Permits Sources are required to obtain a Part 70 Title V Operating Permit if they are a major source of emissions. A major source is defined as a stationary source that emits or has the potential to emit 10 tpy of any single hazardous air pollutant (HAP), 25 tpy of total HAPs, or 100 tpy of any regulated air pollutant. However, the thresholds for NOx and VOC are 50 tpy in a serious non -attainment area. An Exploration & Production well facility is not a listed source type, therefore fugitive emissions are not included in determining major source status. This facility has the PTE NOx emissions above the specified serious non -attainment area threshold and is therefore required to obtain a Title V operating permit within 12 months of becoming designated as a major source. Should the PTE NOx emission remain above the specified threshold Title V operating permit application will be submitted within the required timeframe. Page 96 of 101 3.0 State Regulations Regulation 1, Section II.A.1. Except as provided in paragraphs 2 through 6 of Regulation 1, Section II.A, stationary sources are limited to emissions with a maximum opacity of 20% except during periods of startup and shutdown. Regulation 2, Odor Emission All sources are subject to the general odor emission provisions detailed in Colorado Regulation 2. Regulation 3, Part A, Section II. Regulation 3, Part A, Section II describes when an APEN must be submitted for new, modified, and existing sources. This application proposes to modify four existing stationary emission sources, with estimated uncontrolled criteria pollutant emissions greater than one ton per year in a non -attainment area. Therefore, it is subject to the provisions of Regulation 3, Part A. Regulation 3, Part B Regulation 3, Part B describes the requirements for Construction Permits. This application requests a new construction permit be issued. Therefore, it is subject to the provisions of Regulation 3, Part B. Regulation 3, Part C Regulation 3, Part C describes the requirements for Operating Permits. As described above, the facility became an existing major source, upon start-up and therefore will be subject to the provisions of Regulation 3, Part C. Regulation 3, Part D Regulation 3, Part D describes the requirements for new or existing major stationary source New Source Review and Prevention of Significant Deterioration. As described above, the facility is not subject to NSR or PSD review at this time. Regulation 7, Part D, Section I. Regulation 7, Part D, Section I describes requirements for VOC emissions from oil and gas operations located in the ozone non -attainment area. ■ The control equipment (enclosed combustors) used to demonstrate compliance with the requirements under this section must comply with all general requirements under Section I.C. The condensate storage tanks at this facility are subject to the emission control requirements under Section I.D. ■ The condensate storage tanks at this facility are subject to the monitoring requirements under Section I.E. ■ The condensate storage tanks at this facility are subject to the recordkeeping and reporting requirements under Section I.F. Regulation 7, Part D, Section II. Regulation 7, Part D, Section II. describes statewide requirements for control of emissions from oil and gas operations. The following requirements apply under this Section: Page 97 of 101 ■ The control equipment used to demonstrate compliance with the requirements under this section (enclosed combustors) must comply with all general requirements under Section II.B. ■ The condensate storage tanks at this facility are subject to the emission control requirements under Section II.C, including Storage Tank Emission Management System (STEM) plan requirements. ■ The separator venting emissions at this facility will be subject to the emission control requirements of Regulation No. 7, Part D, Section II.F because the gas coming off a separator comes from a well that was newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014. Emissions from this source are controlled via enclosed combustor. There are no further requirements under this section applicable to this source. 4.0 New Source Performance Standards Regulation 6, Part A (40 CFR Part 60), Subpart A - General Provisions New Source Performance Standards (NSPS) Subpart A, General Provisions, applies to any stationary source that contains an affected facility to which an NSPS applies. This facility has sources subject to NSPS OOOOa; therefore, the requirements of Subpart A apply to this source. Regulation 6, Part A (40 CFR Part 60), Subpart Kb — Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification Commenced After July 23, 1984 NSPS Subpart Kb applies to storage vessels with a capacity greater than or equal to 75 cubic meters that is used to store volatile organic liquids (VOL) and that was constructed, reconstructed, or modified after July 23, 1984. ■ Condensate Storage Tanks All condensate storage tanks at this facility have maximum volumes of 750 bbl (approximately 119 cubic meters) but are used to store condensate prior to custody transfer. Therefore, these tanks are exempt from Subpart Kb requirements per §60.110b(d)(4). ■ Produced Water Storage Tanks All produced water storage tanks at this facility have maximum volumes of 750 bbl (approximately 119 cubic meters), but the produced water stored has a maximum true vapor pressure less than 15 kPa. Therefore, these tanks are exempt from Subpart Kb requirements per §60.110b(b). 40 CFR Part 60 Subpart 0000a - Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 NSPS 0000a applies to each affected facility for which construction, modification, or reconstruction commenced after September 18, 2015. This wellsite facility commenced construction after this date, and the following affected facilities at this location are subject to requirements under this Subpart: • All 11 well affected facilities • The collections of fugitive emissions components at a well site The eight condensate storage tanks and two produced water storage tanks have actual controlled emissions less than 6 tpy per tank and are therefore not affected facilities under this Subpart. Page 98 of 101 Attachment J COGCC 805 Series Rule Requirements Form APCD-105 — Condensate Tanks — AIRS 123-A037-001 Form APCD-105 — Produced Water — AIRS 123-A037-002 Page 99 of 101 Form APCD-105 Colorado Department of Public Health and Environment Air Pollution Control Division Colorado Oil & Gas Conservation Commission (COGCC) 805 Series Requirements Ver. March 30, 2015 Company Name: Crestone Peak Resources Operating, LLC Source Name(s): Regnier Farms 19H -B268 Battery (123 -A037) -Condensate Tank Source AIRS ID(s)1: 123-A037-001 PART A —COGCC Applicability to Tanks (Condensate, Crude ail; and Produced Water)` Yes No 1. Are uncontrolled actual emissions of volatile organic compounds (VOCs) 5 tons per year or greater? (Note that for the purposes of Rule 805 "uncontrolled actual emissions" are as defined in Colorado Regulation 3, Part A, Section I.B.46. For new sources, annual projected uncontrolled actual emissions shall be used.) ✓ ❑ 2. Is the tank located within 1/4 mile of a Building Unit4 or Designated Outside Activity Area"? ✓ ❑ If answers to both questions are "yes", COGCC Section 805.b.(2).A is applicable to this source. PART B,-COGCC App IIca tiility.to Glycol Dehydrators` Yes No 1. Are uncontrolled actual emissions of volatile organic compounds (VOCs) 5 tons per year or greater? (Note that for the purposes of Rule 805 "uncontrolled actual emissions" are as defined in Colorado Regulation 3, Part A, Section I.B.46. For new sources, annual projected uncontrolled actual emissions shall be used.) ❑ ❑ 2. Is the glycol dehydrator located within 1/4 mile of a building unit, educational facility, assembly building, hospital, nursing home, board and care facility, jail, or designated outside activity area? If answers to both questions are "yes", COGCC Section 805.b.(2).B is applicable to this source. PART C COGCCSection 805 Series' Crude Oil, Condensate, and Produced Water Tanks - COGCC Section 805.b.(2)A: "Crude Oil, Condensate, and Produced Water Tanks. All crude oil, condensate, and produced water tanks with uncontrolled actual emissions of volatile organic compounds (VOC) of five (5) tons per year (tpy) or greater, located within 1,320 feet of a Building Unit, or a Designated Outside Activity Area shall use an emission control device capable of achieving 95% control efficiency of VOC and shall obtain a permit as required by Colorado Department of Public Health and Environment, Air Pollution Control Commission Regulation as set forth in 805. b. (1)." Glycol Dehydrators - COGCC Section 805.b.(2).B: "All glycol dehydrators with uncontrolled actual emissions of VOC of five (5) tpy or greater, located within 1,320 feet of a Building Unit , or a Page 100 of 1 armAPCD-105-COGCC805SeriesRules-Ver.3-30-2015-Branded.doc Form APCD-105 Colorado Department of Public Health and Environment Air Pollution Control Division Colorado Oil & Gas Conservation Commission (COGCC) 805 Series Requirements Company Name: Source Name(s): Source AIRS ID(s)': Ver. March 30, 2015 Crestone Peak Resources Operating, LLC Regnier Farms 19H -B268 Battery (123 -A037) -Produced Water Tank 123-A037-002 PART A COGCC Applicability to Tanks (Condensate, Crude Oil, and Produced Water)2 Yes No 1. Are uncontrolled actual emissions of volatile organic compounds (VOCs) 5 tons per year or greater? (Note that for the purposes of Rule 805 "uncontrolled actual emissions" are as defined in Colorado Regulation 3, Part A, Section I.B.46. For new sources, annual projected uncontrolled actual emissions shall be used.) ✓ ❑ 2. Is the tank located within 1/4 mile of a Building Unit4 or Designated Outside Activity Area4? ✓ ❑ If answers to both questions are "yes", COGCC Section 805.b.(2).A is applicable to this source. PART -B -COGCC Applicability to Glycol Dehydrators2 Yes No 1. Are uncontrolled actual emissions of volatile organic compounds (VOCs) 5 tons per year or greater? (Note that for the purposes of Rule 805 "uncontrolled actual emissions" are as defined in Colorado Regulation 3, Part A, Section I.B.46. For new sources, annual projected uncontrolled actual emissions shall be used.) ❑ ❑ 2. Is the glycol dehydrator located within 1/4 mile of a building unit, educational facility, assembly building, hospital, nursing home, board and care facility, jail, or designated outside activity area? If answers to both questions are "yes", COGCC Section 805.b.(2).B is applicable to this source. PART C — COGCC Section 805 Series3 Crude Oil, Condensate, and Produced Water Tanks - COGCC Section 805.6.(2)A: "Crude Oil, Condensate, and Produced Water Tanks. All crude oil, condensate, and produced water tanks with uncontrolled actual emissions of volatile organic compounds (VOC) of five (5) tons per year (tpy) or greater, located within 1,320 feet of a Building Unit, or a Designated Outside Activity Area shall use an emission control device capable of achieving 95% control efficiency of VOC and shall obtain a permit as required by Colorado Department of Public Health and Environment, Air Pollution Control Commission Regulation as set forth in 805. b. (1)." Glycol Dehydrators - COGCC Section 805.b.(2).B: "All glycol dehydrators with uncontrolled actual emissions of VOC of five (5) tpy or greater, located within 1,320 feet of a Building Unit , or a 105-COGCC805SeriesRules-Ver.3-30-2015-Branded.doc Page 101 of 1RrmAPCD- Hello