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Home My WebLink About20203878.tiff,. COLORADO Department of Public Health b Environment Weld County - Clerk to the Board 1150 O St PO Box 758 Greeley, CO 80632 December 16, 2020 Dear Sir or Madam: RECEIVED DEC 21 2020 WELD COUNTY COMMISSIONERS On December 17, 2020, the Air Pollution Control Division will begin a 30 -day public notice period for Crestone Peak Resources Operating, LLC - Bighorn 17H -P267. 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 &t Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Public Notice Coordinator 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe Jared Potis, Governor I Jilt Hunsaker Ryan, MPH, Executive Director Pol, I G Rev-, eGJ OI/ll/2l C C . PLOP) H L(OSInq Pt„)OKIERI CH ICK1 OG(3M) 01/04 /2.I �o2o-357g CDPHE Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Crestone Peak Resources Operating, LLC - Bighorn 17H -P267 - Weld County Notice Period Begins: December 17, 2020 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: Bighorn 17H -P267 exploration and production SESE, Section 17, T2N, R67W Weld County The proposed project or activity is as follows: modify emission factors and emissions The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 19WE0360 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: Kirk Bear Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 (COLORADO Department of Public Health 6 Environment COLORADO Air Pollution Control Division Department of Public Health b Environment CONSTRUCTION PERMIT Permit number: 19WE0360 Date issued: Issuance: 2 Issued to: Crestone Peak Resources Operating, LLC Facility Name: Bighorn 17H -P267 Plant AIRS ID: 123 A036 Physical Location: SESE, Section 17, T2N, R67W County: Weld County Description: Well Production Facility Equipment or activity subject to this permit: AIRS Point Equipment Description Emissions Control Description 001 Eight 500 barrel condensate storage tanks Enclosed combustor 002 Two 500 barrel produced water storage tanks Enclosed combustor 003 Liquid loadout by submerged fill Enclosed combustor 005 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. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. This construction permit represents final permit approval and authority to operate this emissions source. Therefore, it is not necessary to self -certify. (Regulation Number 3, Part B, Section III.G.5.) EMISSION LIMITATIONS AND RECORDS 2. Emissions of air pollutants must not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Page 1 of 12 r'M,Mr COLORADO Air Pollution Control Division Department of Public Health b Environment Annual Limits: AIRS Point Tons per Year Emission Type PM2.5 N0,t V0C CO 001 0.0 1.0 32.8 4.6 Point 002 0.0 0.1 0.8 0.2 Point 003 0.0 0.1 0.3 0.1 Point 005 0.0 0.4 8.0 1.5 Point Note: See "Notes to Permit Holder" for more information on emission factors. Facility -wide emissions of each individual hazardous air pollutant must not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants must not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants must apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, must be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder must calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 3. 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. 4. The owner or operator must track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility emission limitations as indicated below. An inventory of each insignificant activity and associated emission calculations must be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities are defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. (Regulation 3, Part C. II.E.) Total potential emissions from the facility, including all permitted emissions and potential to emit from all insignificant activities, must be less than: • 50 tons per year of V0C • 53 tons per year of N0x 5. The emission points in the table below must be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Page 2 of 12 COLORADO Air Pollution Control Division Department of Public Health b Environment AIRS Point Control Device Pollutants Controlled 001 Enclosed combustor VOC and HAP 002 Enclosed combustor VOC and HAP 003 Enclosed combustor VOC and HAP 005 Enclosed combustor VOC and HAP PROCESS LIMITATIONS AND RECORDS 6. This source must be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates must be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits AIRS Point Process Parameter Annual Limit 001 Condensate 803,000 barrels 002 Produced water 803,000 barrels 003 Condensate 73,000 barrels 005 Low-pressure separator gas 3.80 MM scf Compliance with the annual throughput limits must be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder must calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 7. Point 005: The owner or operator must continuously monitor and record the volumetric flow rate of natural gas vented from the separator(s) using the flow meter. The flow meter must be calibrated and maintained per the manufacturer's specifications and schedule. The owner or operator must 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 8. Point 001, 002, 003, 005: The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) must be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) Page 3 of 12 teNt, f ��M COLORADO Air Pollution Control Division Department of PubIto Health 6 Environment 9. Point 001, 002, 003, 005: No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Regulation Number 1, Section II.A.5.) 10. Point 001, 002, 003, 005: This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 11. Point 001, 002: 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) 12. 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. 13. Point 003: Storage tanks must operate without venting at all times during loadout. (Regulation Number 7, Part D, Section II.C.5.a.(ii)) 14. Point 003: The owner or operator must, as applicable (Regulation Number 7, Part D, Section II.C.5.a.(iii)). Compliance must be achieved in accordance with the schedule in Section II.C.5.a.: 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. Page 4 of 12 COLORADO Air Pollution Control Division Department of Publtc Health Fr Environment 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 vapor loss during loadout. These inspections must occur at least monthly, unless loadout occurs less frequently, then as often as loadout is occurring. 15. Point 003: The owner or operator must perform the following observations and training (Regulation Number 7, Part D, Section II.C.5.a.(iv)). Compliance must be achieved in accordance with the schedule in Section II.C.5.a.: 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. 16. 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. Compliance must be achieved in accordance with the schedule in Section II.C.5.a. 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. 17. 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 hydrocarbon control efficiency of 95%. (Regulation Number 7, Part D, Section II.C.5.a.(vi)) 18. Point 001, 002, 005: 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 Page 5 of 12 'MN COLORADO Air Pollution Control Division Department of Publtc Health b Enwronment 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. 19. Point 001, 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. 20. Point 001, 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. 21. Point 005: 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 a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. 22. Point 001, 002, 003, 005: 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 £t MAINTENANCE REQUIREMENTS 23. Point 001, 002, 003, 005: Upon startup of these points, the owner or operator must follow the most recent operating and maintenance (0&tM) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the 0£tM 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 Page 6 of 12 COLORADO Air Pollution Control Division Department of Public Health b Environment 24. Point 001, 002, 003, 005: This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements 25. Point 001, 002, 003: This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. 26. Point 005: On an annual basis, the owner/operator must complete a site specific extended gas analysis ("Analysis") of the natural gas vented from this emissions unit in order to verify the VOC content (weight fraction) of this emission stream. Results of the Analysis must be used to calculate site -specific emission factors for the pollutants referenced in this permit (in units of lb/MMSCF gas vented) using Division approved methods. Results of the Analysis must be used to demonstrate that the emissions factor established through the Analysis is less than or equal to, the emission factor submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this Analysis is greater than the emissions factor submitted with the permit application and established in the "Notes to Permit Holder" the operator must submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). ADDITIONAL REQUIREMENTS 27. A revised Air Pollutant Emission Notice (APEN) must 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 (NO,t) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or Page 7 of 12 COLORADO Air Pollution Control Division Department of Public Health b Environment • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 28. This source is subject to the provisions of Regulation Number 3, Part C, Operating Permits (Title V of the 1990 Federal Clean Air Act Amendments). The application for the Operating Permit is due within one year of the earliest commencement of operation of any piece of equipment covered by this permit. 29. Federal regulatory program requirements (i.e. PSD, NANSR) must apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source must not exceed the Federal program threshold until a permit is granted. (Regulation Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS 30. 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. 31. 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. 32. 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. 33. 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. 34. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof must constitute a rejection of the entire permit and upon such occurrence, this permit must be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed Page 8 of 12 COLORADO Air Pollution Control Division Department of Public Health & Environment upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 35. 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. 36. 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: Kirk Bear OG Permits The Division Permit History Issuance Date Description Issuance 1 9 September 2019 Issued to Crestone Peak Resources Operating, LLC Issuance 2 This Issuance Modification to emissions factors and emissions. Remove Point 004. Page 9 of 12 , COLORADO Air Pollution Control Division Department of Public Health E, Environment Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder must pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator must notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-reps 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 001 Benzene 71432 5577 279 Toluene 108883 5590 279 Ethylbenzene 100414 298 15 Xylenes 1330207 1906 95 n -Hexane 110543 42,053 2103 224 TMP 540841 118 6 002 Benzene 71432 758 38 n -Hexane 110543 529 26 005 Benzene 71432 1406 71 Toluene 108883 1884 95 Ethylbenzene 100414 95 5 Xylenes 1330207 572 29 n -Hexane 110543 12,307 615 224 TMP 540841 10 1 Page 10 of 12 a„, COLORADO Air Pollution Control Division Department of Public Health b Environment Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: AIRS Point CAS # Pollutant Uncontrolled Emission Factors Source 001 N0x 0.068 lb/MM Btu AP -42 CO 0.310 lb/MM Btu AP -42 V0C 1.6321b/bbl Promax 71432 Benzene 0.006941b/bbl Promax 108883 Toluene 0.006961b/bbl Promax 100414 Ethylbenzene 0.000371b/bbl Promax 1330207 Xylene 0.002371b/bbl Promax 110543 n -Hexane 0.052401b/bbl Promax 540841 224 TMP 0.00014 lb/bbl Promax 002 N0x 0.068 lb/MM Btu AP -42 CO 0.310 lb/MM Btu AP -42 V0C 0.0401b/bbl Promax 71432 Benzene 0.0009441b/bbl Promax 110543 n -Hexane 0.0006581b/bbl Promax 003 N0x 0.068 lb/MM Btu AP -42 CO 0.310 lb/MM Btu AP -42 V0C 0.1311b/bbl AP -42 005 N0x 0.068 lb/MM Btu AP -42 CO 0.310 lb/MM Btu AP -42 V0C 83478 lb/MM scf Gas analysis 71432 Benzene 370 lb/MM scf Gas analysis 108883 Toluene 496 lb/MM scf Gas analysis 100414 Ethylbenzene 24.89 lb/MM scf Gas analysis 1330207 Xylene 150 lb/MM scf Gas analysis 110543 n -Hexane 3239 lb/MM scf Gas analysis 540841 224 TMP 2.50 lb/MM scf Gas analysis Note: The controlled emissions factors for these points 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 Page 11 of 12 awr-t- COLORADO Air Pollution Control Division Department of Public Health 8 Environment revised APEN must be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic -minor source of: VOC, CO, Total HAP Major source of NOx NANSR Synthetic -minor source of: VOC Major source of NOx 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart UUUU NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart X O0O0( Page 12 of 12 Colorado Air Permitting (Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Package #: Received Date: Review Start Date: for Division Use Only Kirk Bear 427163 7/16/2020 11/10/2020 Section 01 - Facility Information Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Location: County: Type of Facility: Exploration & Production Well Pad What industry segment? Oil& Natural Gas Production & Processing Is this facility located in a NAAQS non -attainment area? If yes, for what pollutant? Crestone Peak Resources Operating, LLC 123 A038 .Bighorn 17H -P267 SESE quadrant of Section 17, Township 2N, Range 67W Weld County Section 02 - Emissions Units In Permit Application Leave Blank - For Division Use Only 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 # Self Cert Required? Action Engineering Remarks 001 Storage Tank Yes 19WE0360 2 Yes Permit Modification 002 Storage Tank Yes 19WE0360 2 Yes Permit ' Modification 003 Liquid Loading Yes 19WE0360 2 Yes Permit Modification 005 Separator Venting Yes 19WE0360 2 Yes Permit Modification j Yes Ozone (NOx &. VOC) Quadrant Section Township Range SESE 17 2N 67 Section 03 - Description of Project modification to permit through -puts and emissions. remove point 004. L Sections 04, 05 & 06 - For Division Use Only Section 04 - Public Comment Requirements Is Public Comment Required? Yes If yes, why? Greater than 25 tons. per year in Non -Attainment Area Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? No If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? No Is this stationary source a synthetic minor? Yes If yes, indicate programs and which pollutants: SO2 NOx CO Prevention of Significant Deterioration (PSD) CIOCID Title V Operating Permits (OP) ❑ d ❑ Non -Attainment New Source Review (NANSR) 0 Is this stationary source a major source? Yes VOC 0 0 PM2.5 PM10 TSP ❑ ❑ ❑ ❑ ❑ HAPs ❑ Colorado Air Permitting Project If yes, indicate programs and which pollutants: SO2 NOx CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration (PSD) DODD ❑ ❑ Title V Operating Permits (OP) ❑ M ❑ ❑ ❑ ❑ ❑ ❑ Non -Attainment New Source Review (NANSR) • El ❑ Emissions Invent y Section 01- Administrative Information 'Facility AIRS ID: 123 County A033 Plant 001 Point 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 Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions -Storage Tank(s) Actual Throughput= P11,7571724WA1141W-§.-.WiT,' enclosed combustor Potential to Emit (PTE) Condensate Throughput = 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 = 5. Barrels (bbl) per year Barrels (661) per year Barrels (bbl) per year u/scf Potential to Emit (PTE) heat content of waste gas routed t0 combustion device = Control Device f/bbl 29,147.0 MMBTU per year 29,147.0 MMBTU per year 29,147.0 MMBTII per year Section 04 -Emissions Factors & Methodologies Will this storage tank emit flash emissions? Pollutant Pollutant Pollutant Condensate Tank Uncontrolled Controlled (lb/bbl) (lb/bbl) (Condensate Throughput) 0.0001 (Condensate Throughput) 0.0816 0.0003 0.0003 0.0000 0.0001 0.0026 0.0000 Control Device Uncontrolled (Ib/MMBtu) (waste heat combusted) Uncontrolled (Ib/bb0 (Condensate Throughput) 0.0000 0.0000 0.0000 0.0025 Pilot Light Emissions Uncontrolled (Ib/MMBtu) Uncontrolled (Ib/MMscf) (Pilot Gas Throughput) (Pilot Gas Heat Combusted) Section 05 - Emissions Inventory 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 Emission Factor Source Emission Factor Source Emission Factor Source Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 50x NOx voc co :31: ::!nli=1:=EKENII '®' M X :I '®' :1!: °®' '®' =1=11.3= r II:MillillIMIZIMIN® �� :1!:CIE2131..OF 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 ® ®IEMIIII !IZIEMSE=II 523IIIII® ,. 3 of 19 K:\PA\2019\19 W E0360.CP2.xlsm Storage Tar -114s) Er.issicns InventOry Xylene n -Hexane 224 TMP 19®3 42077 1903 42077 95 �19G 2104 118 118 4af19 KAPA\2019\19 W E0360.CP2.xlsm Storage Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Part D,Section LC, 0, E, F Storage tank is subject to Regulation 7, Part D, Section I.C-F Regulation 7, Part D,Section I.G, C Storage Tank is not subject to Regulation 7, section I.G Regulation 7, Part D,Section II.B, C.1, C.3 Storage tank is subject to Regulation 7, Part D, Section II, B, C.1 & [.3 Regulation 7, Part D,Section II.C.2 Storage tank is subject to Regulation 7, Part D, Section II.C.2 Regulation 7, Part D,Section ll.C.4.a.(I) Storage Tank is not subject to Regulation 7, Part D, Section ll.C.4.a(i) Regulation 7, Part D,Section ll.C.4.a.(ii) Storage Tank is not subject to Regulation 7, Part D, Section ll.C.4.a(ii), b - f Regulation 6, Part A, NSPS Subpart Kb Storage Tank is not subject to NSPS Kb Regulation 6, Part A, NSPS Subpart 0000 Storage tank is not subject to NSPS O0OO. NSPS Subpart 0000a Storage Tank is not subject to NSPS 0000a Regulation B, Part E, MACT Subpart HH Storage Tank is not subject to MALT NH. (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements For condensate or crude oil tanks, does the company use the state default emissions factors to y estimate emissions?"v- _L dyes, 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? Ifyes, 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 estimateemissions? dyes 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. !Eno, 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 O8 -Technical Analysis Notes Section 09 -SCC Coding and Emissions Factors (For Inventory Use Only) AIRS Point it on Process ti SCC Code 01 .e.._. Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons Condensate throughput PM2.5 0.00 0 lb/1,000 gallons Condensate throughput 50x #REFI 0 lb/1,000 gallons Condensate throughput NOx 0.06 0 lb/1,000 gallons Condensate throughput VOC -38.86 95 lb/1,000 gallons Condensate throughput CO 0.27 0 lb/1,000 gallons Condensate throughput Benzene 0.17 95 16/1,000 gallons Condensate throughput Toluene 0.17 95 lb/1,000 gallons Condensate throughput Ethylbenzene 0.01 95 lb/1,000 gallons Condensate throughput Xylene 0.06 95 lb/1,000 gallons Condensate throughput n -Hexane 1.25 95 lb/1,000 gallons Condensate throughput 224 TMP 0.00 95 lb/1,000 gallons Condensate throughput 5,0119 KAPA\2019\39W E0360.CP2.xism Storage Tank Regulatory Analysis Worksheet The regulatory requirements below are determined based on requested emissions. Colora_ _do Regulation 3 Parts A and B- APEN and Permit Requirements ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutantsfrom this individual source greaterthan 2 TPY (Regulation 3, Part A, Section ll.D.l.a)7 ® Source Requires an APEN. Go to 2. Isthe construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions112 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total fadlity uncontrolledVOC emissions greater than 5 TPY, NOx greater than to TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section ll.D.31? have h.hcnte!-.. _— ci el. Nor,Atta Ime tAura NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1TPY(Regulation 3, Part A, Section ll.D.l.a)? 2. Is the construction date (service date) priorto 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-010efinitians 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 2TPy, NOx greaterthan STPY or CO emissions greater than 10 TPY(Regukation 3, Part%Section ll.D.2)? _^�arce rcgnlresa permit Colorado Regulation 7, Part D. Section I.C-F N G 1. Is this storage tank located In the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area (Regulation '7, Part D, Section I.A.1)? 2. Is this storage tank located at oil and gas operations that collect, store, or handle hydrocarbon liquids or produced water AND that are located m or upstream of a natural gas processing plant (Regulation 7, Part D, Section IA.1)? 3. Is this storage tank located at a natural gas processing plant (Regulation 7, Part D, Section I.G)? 4. Doesthls storage tank contain condensate? 5. Doesthb storage tank exhibit "Flash" (e.g.storing non -stabilized liquids) emissions(Regulation7, part 0, Section l.G.2)? 6. Are uncontrolled actual embsionsof this storage tank equal to orgremerthan 2tons per year VOC (Regulation 7, Part D, Section l.D.3.a(ii))? tis 'Scum.iansublect to Rya,:: '.::=a,t D. Sector l.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 D, Section I.0 -Emissions Control Requirements Part D, Section I.E-Monitoring Part 0, Section I.F-Recordkeeping and Reporting I ssoruto Tank is n .sect nn i.G Part D, Section I.G.2 - Emissions Control Requirements Part 0, Section I.C.l.a and b -General Requirements for Air Pollution Control Equipment -Prevention of leakage Colorado Regulation 7. Part D. Section II 1. Isthb storage tank located at a transmission/storage facility? 2. Is this rtoragetanks located at an oil and gas exploration and production operation , well produrtion faciltya, natural gas mmpressorstationa or natural gas processiag plant (Regulation 7, Part D, Section ILC)7 3. Does this storage tank have a fixed roof(Regulation 7, Part D, Section 11.0.20)7 4. Are uncontrolled actual emissions of this storage tank equal toor greater than 2 tons per year VOC (Regulation 7, Part D, Section ll.Cl.c)? ,.ction II, is. 0.14, 0,3 Part D, Section II.B - General Provisions for Air Pollution Control Equipment and Prevention of Em Part D, Section II.C.1- Emissions Control and Monitoring Provblons Part D, Section II.C.3 - Recardkeeping Requirements 5. Does the storage tank contain only stabilized"liquids (Regulation 7, Part 0, Section il.C.21)7 on Yes Yas Ga to next question Source Requires a permit Source Requires an APEN. Go to Go to next question Source Requires a permit Continue - You have indicated th Continue You have indicated th Stange 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, j.joysyassisources subject to all provislem Part D, Section II.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment Is the controlled storage tank located at a well production facility, natural gas wmpressorrtation,car natural gas processing plant carntrurted on or after May 1, 2020 or lasted at a facility th. was modified on or after May 1, 2020, such 6. that an additional controlled storage vessel h constructed to receive an anticipated increase in throughput of hydrocarbon liquids or produced water (Regulation 7, Part D, Section ll.C.4.a.(R7 IStorage Tank Is not subject to Re Is the controlled storage tank located at a well production facility, natural gas compressor rtation, or natural gas processing plant constructed an or after January 1, 2021 or located at a facility -M. was mad'died on or after January 1, 7. 2021, such that an additional controlled storage vessel is constructed to receive an anticipated increase In throughput of hydrocarbon liquids or produced water (Regulaion 7, Part D, Section II.C4.a.(ii)? 40 CFR. Part 60. Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1 Is theindividual storage vessel capacity greaterthan or equal to 75 cubic meters (m) [-472 BBLs] (40 CFR 60.110b(a))? 2. Does the storage vessel meet the following exemption In 60.1116(d)(4)7 a. Does the vessel has a design capacity less than or equal to 1,589.874 ma[ -10,000 BBL] used for petroleum' or 13 condensate stored, or treated prior. custody transfer' as defined in 60.1b? as 3. Wthis storage vessel constructed,reconstructed, or ',tacitness (see definitions 40 CFR, 60.2) after July 23,1984(40 CFR 60.1106(a))? 4. Ooest. tank meet the definition of "storage vessel"' in 60.11.7 S. Doesthe storage vessel store a"volatile arganic liquid(VOL)"'as defined in 60.111b? 6. Does the storage vessel meet any one of the following additional exemptions: a. Is the storage vessel a pressure vessel designed to operate in excess of 204.9 kPa 1-29.7 psi] and without emissionstothe atmosphere (60.110b(d)(2))7; or b. The design capacity is greaterthan or equalta 151m' (`950 BBL] and stores a liquid with a maximum true vapor pressure less than 3.5 kPa (60.1106(6))?; or c. The design capacity is greaterthan or equal to 75 Ma [-472 BBL] but less than 151 ma x-950 BBL] and stores a liquid with a maximum true vapor pressure` less than 15.0 kPa(60.13Im(b))7 7. Does the storage tank meet either one of the following exemptions from control requirements: a. The design capacity b greater than or equal to 151 ms 1-950 BBL] and stores a liquid with a maximum true vapor pressure greater than or equal to 3.5 kPa but less than 5.2 kPa?; o b. The design capacity is greater than or equal to 75 he( -472 BBL) but less than 151 mz[`950 BBL] and stores a liquid with a maximum true vapor pressuregreaterthan or equal to 15,0 kPa but less than 27.6 kPa? IStaraee Tank is nns NSPS .2 90 CFR, Part 60. Subpart 0000/0000a.Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Isthis storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this 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,reconstructed, or modified (see definitions 40 CFR, 60.2) after September 18, 2015? 4. Are potential VOCemissions' from the Individual storage vessel greater than or equal to 6 tom per year? 5. Does this storage vessel meet the definition of"storage vessel"' per 60.5430/605430a? 6. Is the storage vessel subject to and controlled in accordance with requlrementsforstorage vessels in 40 CFR Part 60 Subpart Kb .40 CFR Part 63 Subpart NH? Y 4 Go to the next question ,rifle Storage Tanks not subject NSPS tes T,& u''t+t_., [Note: If a storage vessel Is previously determined to be subjectto NSPS 0000/0000e due b emissions above 6 tons per year VOC on the applicability determinatan date, it should remain subject to NSPS 0000/0000a per 60.5365(e)(2)/60.5365a(e)(2) even if potential VOC emissions drop below 6 tans per year] 40 CFR, Part 63, Subpart MAR NH, 011 and Gas Product,. Facilities 1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. Afacility thatprocesses, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR b. A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end user'(63.760(a)(3))? 2. Is the tank located at a facility that b major' for HAPs7 3. Does the tank meet the definition of"storage vessel"a In 63.7617 4. Does the tank meet the definition of "storage vessel with the potential for 'Ras h emissions'' per 63.761? 5. Is the tank subject to control re ulrements under 40 CFR Part 60, Subpart Kb or Sub art 0000? Subpart A, General provisions per 463.764 (a) Table 2 463.766- Emissions Control Standards §63.773 -Monitoring §63.774-Recordkeeping §63.T75 -Reporting RACT Review RACT review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets bath criteria, then review RAC' requirements. Disclaimer Continue -You have indicated th Storage Tank is not subject NSPS Go to the next question Storage Tank b not subject NSPS Continue - You have Indicated th Storage Tank is not subject MAC This document exists 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 particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, r any other legally binding requirement and is not legally enforceable. In the event ofany conflict between the language of this document and the language of the dieen 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 Yeconmend,""prey,"should,"and -can,"is intended to describe APCQ interpretations and recommendations. Mandatory terminology such as "must" and 'required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. Storage Tani( Ertsslons Inventory Section 01 -Administrative Information 'Facility Allis ID: 123 A036 County Plant 002 Point 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 µ Section 03- Processing Rate Information for Emissions Estimates Primary Emissions -Storage Tank's) Actual Throughput= 'Requested Permit Limit Throughput= 95.0 .803,000 Barrels (bbl) per -Near 803,000 Barrels (bbl) per year Potential to Emit (PTE) Condensate Throughput = 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 = 803,000. Barrels (bbl) per year 3184.0 Btu/scf 0.9 scf/bbl Potential to Emit (PTE) heat content of waste gas routed to combustion device = Control Devke 2,301.1 MMBTU per year 2,301.1 MMBTU per year 2,301.1 MMBTU per year Pilot Fuel Use Rate: Pilot Fuel Gas Heating Value: 25 scfh 1000 Btu/scf 0.2 MMscf/yr 219.0 MMBTU/yr Section 04 - Emissions Factors & Methodologies Will this storage tank emit flash emissions? Emission Factors Produced Water Tank Emission Factor Source Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) (Produced Water Throughput) (Produced Water Throughput) VOC 0.0400 0.0020 Site Specific E. F. (includes flash} "}`- v- Site Specific E.F. (includes flash$ Site Specific E.F..(includes flash) '- v$m b Benzene 0.0009 0.0000 Toluene .0.0007 0.0000 Ethylbenzene 0.0000 Xylene 0.0000_° n -Hexane 0.0000 224 TMP 0.0000 Pollutant Control Device Emission Factor Source Uncontrolled Uncontrolled (Ib/MMBtu) (Ib/bbp (waste heat combusted) (Produced Water Throughput) PM102. 0.0000PSOx AP -42 Chapter 13.5 lddu' AP -42 Chapter 13.5 Indu y" 0.0000 OR 0.0000 N NOx 0.0680 0.0002 CO ' 0:3100 0.0009 Pollutant Pilot Light Emissions Emission Factor Source Uncontrolled Uncontrolled (Ib/MMBtu) (Ib/MMscf) (Pilot Gas Heat Combusted) (Pilot Gas Throughput) PM10 0.0000 PSOx 0.0000 Ox 0.0000 NOx 0.0000 VOC 0.0000 co 0.000D Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 SOx NOx VOC CO Hazardous Air Pollutants 0.0 0.0 0.0 0.1 16.1 0.4 0.0 0.0 0.0 0.1 16.1 0.4 0,0 0.0 0.0 0.1. 0.8 0,4 0.0 0.0 0.0 O 16.11 0.4 0 4' 0.0 0.0 0.0 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 758 528 758 528 38 26 758 528 0 S of 19 KAPA\2019\39 W E0360.CP2a Ism Xylene n-Homne 224 TMP 9 of 19 KAPA\2019\19 W E0360.CP2.xlsm Storage Tank(s) Emissions Inventory Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, 8 Source requires a permit Regulation 7, Part D,Section I.C, D, E, F Storage tank is subject to Regulation 7, Part 0, Section I.C-F Regulation 7, Part D,Section I.G, C Storage Tank is not subject to Regulation 7, Section I.G Regulation 7, Part D,Section II.B, C.1, C.3 Storage tank is subject to Regulation 7, Part D, Section II, B, C.1 & C.3 Regulation 7, Part D,Section II.C2 Storage tank is subject to Regulation 7, Part D, Section II.C.2 Regulation 7, Part O,Section II.C.4.a.(i) Storage Tank is not subject to Regulation 7, Part D, Section II.C4.a(ij Regulation 7, Part D,Section II.C.4.a.(ii) Storage Tank is not subject to Regulation 7, Part D, Section II.C4.alii), b -f Regulation 6, Part A,. NSPS Subpart Kb Storage Tank is not subject to NSPS Kb Regulation 6, Part A, NSPS Subpart 0000 Storage tank is not subject to NSPS 0000. NSPS Subpart 0000a Storage Tank is not subject to NSPS 000Oa Regulation 8, Part E, MACE Subpart HH Produced Water Storage tank is not subject to MACT HH (See regulatory applicability worksheet far detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements r-� 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 PS Memo 14-03. Does the company request acontrol 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 # 002 Section 09 - SCC Coding and Emissions Factors (For Inventory Use Only) Process SCC Code 01 Uncontrolled Emissions Pollutant Factor Control% Units PM10 coo 0 lb/1,000 gallons Produced Waterthroughput PM2.5 cum 0 lb/1,000 gallons Produced Water throughput SOx #REF! 0 lb/1,000 gallons Produced Water throughput NOx 0.00 0 lb/1,000 gallons Produced Water throughput VOC 0.95 95 lb/1,000 gallons Produced Water throughput CO 0.02 0 16/1,000 gallons Produced Water throughput Benzene 0.02 95 16/1,000 gallons Produced Water throughput Toluene 0.02 95 lb/1,000 gallons Produced Water throughput Ethylbennene 0.00 95 lb/1,000 gallons. Produced Water throughput Xylene 0.00 95 16/1,000 gallons Produced Water throughput n -Hexane 0.00 95 lb/1,000. gallons Produced Water throughput 224 TMP 0.00 95 lb/1,000 gallons Produced Water throughput 10 of 19 KAPA\2019\19 W E0360.CP2.xlsm Storage Tank Regulatory Analysis Worksheet The regulatory requirements below ore determined based on requested emissions. Colorado Regulation 3 Parts A and B-APEN and Permit Reauirements ATTAINMENT 1 Are uncontrolled actual f y ( p Ilut t from this individual source greater than 2TPY(Regulation 3, Part A, Section ll.Dla)7 5 R q son APEN. Gam 2. Produced W.er Tani. hgrandfatheringp v Go to nextquestion 3. Are total facility uncontrolledVOL emissions greater than 5TPY, NOx greater than SOTPY or CO emissions greater than 10 TPY(Regulaton 3, Part&Section 11.0.3)? Source Requires a permit NON -ATTAINMENT 1. Are unconrolled emissions from any criteria pollutants from this individual source greater than 1TPY(Regulation 3, Part A,Section ll.D.1.a)? 2. Produced WaterTanks have no grandfathering provisions 3. Are totalfacility uncontrolled VOC emissions greater than 2TPY, NOx greater than 5 TPY ar CO emissions greater than 10 TPY(Regulation 3, Part B, Section 11.0.2)? Colorado Regulation 7, Part 0. Section I.C-F & G 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area (Regulation 7, Part D, Section I.A.1)? 2. Is this storage tank located at ail 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.A.11? 3. Is this storage tank located at a natural gas processing plant (Regulation ], Part 0, Section 1.07 4. Does this storage tank contain condensate? 5. Does this storage tank exhibit"Flash"(e.g. staring non -stabilized liquids) embsians(Regulation 7, part 0, Section 1.6.2)7 6. Are uncontrolled actual emissions of this storage tank equal to or greater than 'tans per year VOC (Regulation 7, Part 0, Section 1.0.3..0? Ic. Part D, Section l.C.1—General Requirements for Air Pollution Control Equipment —Prevention of Leakage Part D, Section I.C.2—Emission Estimation Procedures Part D, Section l.D —Emi ns Control Requirements Part D, Section 1.6 —Monitoring Part D, Section I.F —Recordkeeping and Reporting Part D, Section I.G.2- Emissions Control Requirements Part D, Section I.C.l.a and h —General Requirements for Air Pollution Control Equipment— Prevention of Leakage Colorado Regulation 7, Part D, Section,' 1. Is this storagetank located at a transmission/storagefacility? 2. Is this sorage tank' located at an oil and gas exploration and production operation, well production facility, natural gas compressor stations or natural gas processing plans°(Regulation], Part 0, Section ILL)? 3. Doesthis storage tank have afixed roof (Regulation 7, Part D,Section ll.A.20)? 4. Are uncontrolled actual emissions of this storagetank equal to or greater than 2 tons per year VOC (Regulation], Part 0, Section ll.Glc)? Smiacc Mr& is catigrtil m Racttiatizu 7. P&L_Suzhou S. 0_1 & if.3 Part 0, Section 11.0 —General Provisions for Air Pollution Control Equipment and Prevention of Emissions Part 0, Section II.C.1- Emissions Control and Monitoring Provisions Part O, Section II.C.3 - Recordkeeping Requirements 5. Does the storage k contain only "stabilized" liquid (Regulation 7, Part 0, Section 11.C.2.6)? I5+.. L _ . Part 0, Section II.C.2- Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment Is the controlled storage tank located at a well productionfacility, natural gas compressor station,or natural gas processing plant constructed on or after May 1, 2020 or located at a facilirythat was modified on or after May 1, 2020, such & that an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of hydrocarbon liquids or produced water (Regulation 7, Part D, Section Is the controlled storage tank located at a well production facility, natural gas compressor or natural gas processing plant co cted on or after January 1, 2021 or located at a facility that was modified on or after January 1, ]. 2021, such that an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of hydrocarbon)quids or produced wrier(Regulation 7, Part D,Section ll.C.4.aliil? 90 CFR, Part 60, Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the individual storage vessel capacity greaterthan or equal to 75 cubic meters (m3) I-4]2 18Ls] (40 CFR 60.110b(a))? 2. Does thestorage vessel meet the following exemption in 60.1116(d)(4)? a. Does the vessel has a design capacity less than or equalto 1,589.679 in3 `10,000 BBL]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 defnitions 40 CFR, 60.2) after July 23,1984 (40 CFR 60.1106(a))? 4. Doesthe tank meet the definition of"storage vessel"' In 60.111b? 5. Does thestorage vessel store a"volatile organic liquid(VOL)"Sas defined in 60.111b? 6. Does thestorage vessel meet any one of the following additional exemptions: a. Is the storage v sel a pressure vessel designed to operate In excess of 204.9 kPa[-29.7 psi]and without emissions to the atmosphere (60.110h(d)(2))?; or b. The design capacity is greater than or equal to 151 m3 (`950 BBL] and stores a liquid with a maximum true vapor pressures less than 3.5 kna (60.110b(b))?For c. The design capacity is greater than or equalto 75 M' (`472 BBL] but less than 151 mI`950 BBL] and stores a liquid with a maximum true vapor pressure` less than 15.0 kPa(60.1106(b))? 7. Does the storage tank meet either one of the following exemptlonsfrom control requirements: a. The design capacity ¢ greater than or equal to 151 m3 [`950 BBL] and stores a liquid with a maximum true vapor pressure greater than or equal to 3.5 kPa 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 ms (-950 BBL] and stares a liquid with a maximum true vapor pressure greater than or equal to 15.0 kPa bin less than 2].6 kPa? Continue - You have indicated th Continue - You have indicated th Storage Tank is not subjectto Rs Continue -You have indicated th Go to the next question -You ha Go to the next question Source is subject to parts of Reg, I'Source is subject to all provision, Go to the next question Storage Tank is not subject NSPS 40 CFR, Part 60, Subpart 0000/0000a. Standards of Performancefor Crude Oil and Natural Gas Production, Transmission and Distribution 1. Isthh storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and starage 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. Wasthis storage vessel constructed,reconstructed, or modified (see definitions 40 CFR, 602) after September 18, 2015? 4. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6tons per year? 5. Does this storage vessel meet the definition of"storage vessel"' per 60.5430/60.5430a? 6. Is the storage vessel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 635ubpart NH? [Note: If a storage vessel is previously determined to be subjectta NSPS 0000/0000a due to emissions above 6 tons per year VOC an the applicability determination date, it should remain subjeRta NSPS 0000/0000a per 6a.5365(e](2f/60.5365aM1(2) even if potential VOC emissions drop below 6 tons per year] 40 CFR, Part 63, Subpart MALT NH, Oil and Gas Production Facilities 1. Is the storage tank located at an oil and natural gas production facility that meets either of the fallowing criteria; a. Afacility that processes,Upgrades or stores hydrocarbon liquids' (63.760(a)121), OR b. Afacility 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)(31)? 2. Is the tank located at a fadlity that is majors for HAPs? 3. Does thetank met the definition of "storage vessel"' in 63.761? 4. Does the tank me. the definition of ''storage vessel with the potential forflash emissions' per 63.]61? 5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or subpart 0000? ?znd d or qt.nl,. , Subpart A, General provisions per 463.]64 (a) Table 2 363.166 - Emissions Control Standards 463.7]3 -Monitoring 363.7]4- Recordkeeping 463.]75 -Reporting RACE Review RACT review is required if Regulation 7 does not apply AND If theMnk is in the non -attainment area. If the mnk meets both criteria, then review RACT requirements. Disclaimer Continue - You have Indicated th Storage Tank 5 not subject NSPS Ga to the next question Storage Tank is not subject NSPS 'Mc )Continue- You have Indicated th torage Tank is not subject MAC 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 toa 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 d non -mandatory language such as "recommend,""may,""should,"and "can," is intended to describe APCO interpretations and recommendations. Mandatory terminology such as "muse' and "required" are intended to describe controlling requirements under the terns of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. i`ydrocdrbun nventory Section 01 -Administrative Information - Facility AIRS ID: 1036 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 far Emissions Estimates Primary Emissions- Hydrocarbon Loadout Actual Volume Loaded = Requested Permit Limit Throughput= Potential to Emit (PTE) Volume Loaded = ?,. :2j3;Odp; Barrels (bbl) per year Barrels (hbl) per year Requested Monthly Throughput= 6200 Barrels (bbl) per month Secondary Emissions -Combustion Device(s) Heat content of waste gas= Actual Volume of waste gas emittedper 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 device = BTS4. Btu/scf 66833 scf/year 66833 scf/year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 213 MMBTU per year 213 MMBTU per year 213 MMBTU per year Control Device Pilot Fuel Use Rate: Pilot Fuel Gas Heating Value: scfh Btu/scf 0.2 MMscf/yr 219.0 MMBTU/yr Section 04 -Emissions Factors & Methodologies Does the company use the state default emissions factors to estimate emissions? Are the emissions factors based on a stabilized hydrocarbon liquid sample drawn atthe facility being permitted? Loading Loss Equation L =12.46"S•P*M/T 4.77 The stabilized hydrocarbon liquid sample is valid for developing site specific emissions factors. Factor Meaning Value Units Source S Saturation Factor 0.6 hilikONAMEAP-02 fkapter6.2 Table 5.2-1 Submerged Loading:Ddicated Normal Service(S=SF:.: P True Vapor Pressure 4 psis previous permit notes M Molecular Weight of Vapors 54.1 Ib/Ib-mol previous permit notes T Liquid Temperature x:520 :: Rankine " previous permit notes L Loading Losses 3.1116/1000 gallons 0.13 lb/bbl Component Mass Fraction Emission Factor Units Source Benzene _: .",,. ` .. 0 lb/bbl r Toluene O lb/bbl Ethylbenzene 0 lb/bbl Xylene ,� .,„�, ,.,ass, �..,, , ar 0 lb/bbl n -Hexane 0 lb/bbl 224 TMP 0 lb/bbl Pollutant Pollutant Pollutant Uncontrolled Controlled (Ib/bbl) (lb/bbl) (Volume Loaded) 0.0000 0,0000 0.0000 o.0000 11 0.0000 0.0000 (Volume Loaded) 0,0065 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 Control Device Uncontrolled (Ib/MMBtu) Uncontrolled (Ib/bbp (waste heat combusted) (Volume Loaded) 0.0000 0.0000 0.0000 0.0002 0.0009 Pilot Light Emissions Uncontrolled (Ib/MMBtu) Uncontrolled (Ib/MMscf) (Pilot Gas Throughput) (Waste Heat Combusted) 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 Emission Factor Source Emission Factor Source Emission Factor Source 13 of 19 K:\PA\2019\19 W E0360.CP2.xlsm Section 05 - Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (Ibs/month) PM10 0.00 0.00 .0.00 0.00 0.00 0 PM2.5 0.00 0.00 0.00 0.00 0.00 0 sox 0.00 0.00 0.00 0.00 0.00 0 NOx _ 0.01 0.01 0.01 0.01 0.01 1 VOC 4.77 4.77 0.24 4.77 0.24 41 CO 0.03 0.03 0.03 0.03 0.03 6 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ibs/year) (Ibs/Year) (Ibs/Year) (Ibs/year) Ilbs/year) Benzene 0 0 0 0 0 Toluene 0 0 0 0 0 Ethylbenzene 0 0 0 0 - 0 Xylene 0 0 0 0 0 n -Hexane 0 0 0 0 0 224 TMP 0 0 0 0 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, 8 Source requires a permit Regulation 7 Part D Section II.C.S. (See regulatory applicability worksheet for detailed analysis) The hydrocarbon liquids loadout source is subject to Regulation 7 Part D Section II.C.5. 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 AIRS Point 11 003 Section 09 -SCC Coding and Emissions Factors (For Inventory Use Only) Process it SCC Code 01 4-06-001-32 Crude Oil: Submerged Loading Normal Service (S=0.6) Uncontrolled Emissions Pollutant Factor Control% Units PM10 0.00 0 lb/1,000 gallons transferred PM2.5 0.00 - 0 16/1,000 gallons transferred SOx 0.00 0 lb/1,000 gallons transferred NOx 0.00 0 Ib/1,000-gallons transferred VOC 3.1 95 lb/1,000 gallons transferred ' CO 0.02 0 1b/1,000 gallons transferred Benzene 0.00 95 lb/1,000 gallons transferred Toluene 0.00 95 lb/1,000 gallons transferred Ethylbenzene 0.00 95 lb/1,000 gallons transferred Xylene 0.00 95 lb/1,000 gallons transferred n-liexane 0.00 95 lb/1,000 gallons transferred 224 TMP 0.00 95 16/1,000 gallons transferred 14 of 19 K:\PA\2019\19 W E0360.CP2.xlsnr Hydrocarbon Loadaut Regulatory Analysis Worksheet The regulatory requirements below are determined based on requested emissions and throughput. Colorado Regulation 3 Parts A and B-APEN and Permit Requirements Iao or in No titiNtiumirevre red ATTAINMENT 1. a, uncontra.... emissions, criteria pollutants from this individual scums greater than 2TPy (Regulation 3, FNMA, section 11.0.1.a), load..t bated at....0. nomanaproaucuon5ite leg., wow) (Regulation an lLD.i.il? 8. Is the laadout operation loading less than 10.005 gallons 1230 6eei ofc'rude oil perday on an annual average bash? a. IS the ....per. on loading less than 6,]50 tails per year of condensate via splash fill? 5. Is the loadoutoperation loading less Nan., . hhls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled VOC emissions greater than 5TPY, NOx greater than TOTPT or CO emissions greater than lO TPV(Regulation 3, Part B, Section 11.0.3)? NON -ATTAINMENT �s�� 1. Are uncontrolled em criteria pollubts from this individual so ter than 1TPY(Reg Part A, Section ll.D.1a1? ^₹^�Gol next qua 2. IS Me...c.oc production slte(e.g well padl(Regula0 3, Part on II.D.1.1)cn3 `.r. `e g"Go to Men on 3. Is Me loadout operation loading lessMan10,660.gallons(23a eaL5l of crude all per day on an annual average basis? �Go ertlonn 4. Is the loadu ,. on loadingless than 6,150 Isiah per yearPear,condense splash fill? Go to next question 6. Is the load°. operation loading less than 16.360 bids. per year of condensate via submerged fill procedure? .INMS Go to next question 6. Are total facility uncontrolled Vocemissions from the greaNrMan 2TPY, NOx greaOr than 5 TPY or CO emissions greater than 10 TM'(Regulaton 3, �rbonll.o.z) kor.44M The loadout requires a permit Ish Calomda Regulation ] Part 0 section lics. scondensate storage tank hydrocarbon liquids loadeutlocated at a well production facility, natural gas compressor -Motion or natural gas prmesdng plant? 2. Does the fadlity haves throughput, Hydrocarbon liquids loadaut to transport vehicles greater Nan or equal to 5,000 barrels? Section CS.a(I)FComplance Schedule e section II.CS.a.(li)-Operation vnthout Venting section II.e5.a.liiil-Inadut Equipment Operaton and Maintenance Section II.c5.adivl- Lcadout observations and Operator Training Section II.CS.a.NI -Retards Section II.E.5.a.lvil-Requirements for Air Pollution Control Equipment Disclaimer This daunt., assts.. operators with determining appf ability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Cont. Commission regulations. This document u not a rule or regulation, ad the analysis it contains may rrf. apply to a particular situation based upon the in drvidual facts and circumstances. This document does not charge or substitute for any law, regulation, or any other legally bidng requirement and. not-lege., enforceable. In the evert of any conlFct between the language of this document and the language cf the Clean Air Act„ ifs implementing regulations, and Air Quality Control Commission regulations, the language of Mesta.. or regulation will control. The use of non -mandatory language such a s"recwnmend,nay,""stwuM,"ant"can,"is intended fo describe APCO interpretetians and recommendations. Mandatory...elegy such as "musf"and "required' are intended ...film contru'Fng requirements under.he.erms of the Clean Air Actand Air Quafdy Conevl commission regulations, but this document does not establish legally bindng requirements in ado.... SorextquctM estion. ?a urcels zubjeRegulaton]Part OSecdcn ll.C5. Separator Venting Emissions inventory Section 01- Administrative Information Fa cility Al Rs ID: 123 County A036 Plant 005 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Low pressure _separator emissions during VRU downtime. This point does not include emissions from the downstream Vapor Recoveryi Emission Control Device Description: enclosed combustor Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter Gas meter Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Separator Actual Throughput = IRequested Permit Limit Throughput= "3:80 MMscf per year 3.80 MMscf per year 95 Potential to Emit (PTE) Throughput = 3.80 MMscf per year Secondary Emissions- Combustion Device(s) for Air Pollution Control Separator Gas Heating Value: Volume of waste gas emitted per BBL o liquids throughput: scf/bbl Control Device Pilot Fuel Use Rate: Pilot Fuel Gas Heating Value: 25 scfh 1000 Btu/scf 0.2 MMscf/yr �1ANN' Section 04 - Emissions Factors & Methodologies Description MW Low pressureseparator emissions during VRU downtime. This point does not include emissions from the downstream Vapor Recovery Tower. 42.3 Weight Helium 20.0000 CO2 .x'1.4567 N2 -"0.0414 methane ` 8.7374 ethane 14:8757 propane '7 25.5804 isobutane 5.8927 n -butane :16.1872 isopentane ,5.3803 n -pentane ':6.8355 cyclopentane :0:4309 n -Hexane +*2.9049 cyclohexane O8310 Other hexanes ::.4.4179 heptanes -.2.3820 methylcyclohexane "`L0427 224-TMP ' 0.0022 Benzene -.. 0.3320 Toluene ".'.0.4447 Ethylbenzene i.:0.0223 Xylenes ..0.1350 C8+ Heavies :.2.0568 Total VOC Wt 99.9897 74.8785 b/Ib-mol Displacement Equation Ex=Q`MW*Xx/C 16 of 19 K:\PA\2019\19W E0360.CP2.xlsm Separator Venting Emissions inventory Pollutant Separator Venting Uncontrolled (Ib/MMscf) Controlled (Ib/MMscf) M EIMM MMM 150.49 M=M OMEK Emission Factor Source Pollutant Pilot Light Emissions Pollutant Primary Control Device Uncontrolled (Ib/MMBtu) (Waste Heat Combusted) Uncontrolled Ib/MMscf (Gas Throughput) Uncontrolled (Ib/MMBtu) (Waste Heat Combusted) Uncontrolled Ib/MMscf Section 05 - Emissions Inventory (Pilot Gas Throughput) 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 Emission Factor Source Emission Factor Source Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 SOx NOx VOC CO =IMEE=:E= =M3:=1==3:= �1.111=1=XMIll '®' 111.1. •=3 3ill:IMIIMIETZENEEMFITM MESEIWIMESEMNIV- 21:1 iiii0ii -.4%4 ' 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 TM 1406 0 00417 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Part D, Section II.B, F Regulation 7, Part D, Section II.B.2.e (See regulatory applicability worksheet for detailed analysis) Source requires a permit Source is subject to Regulation 7, Part D, Section 11.B.2, F The control device for this separator is not subject to Regulation 7, Part D, Section 11.B.2.e 17 of 19 K:\PA\2019\ 19WE0360.CP2.xlsm Separator Venting 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 AIRS 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 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. -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? Yes 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 You have indicated above that the monitored process parameter is natural gas vented. The following questions do not require an answer. Section 08 -Technical Analysis Notes AIRS Paint # 005 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 0.0 0 Ib/MMSCF PM2.5 0.0 0 Ib/MMSCF 5Ox 0.0 0 Ib/MMSCF NOx 163.8 0 Ib/MMSCF VOC 83472.7 95 Ib/MMSCF CO 746.8 0 Ib/MMSCF Benzene 370.1 95 Ib/MMSCF Toluene 495.7 95 Ib/MMSCF Ethylbenzene 24.9 95 Ib/MMSCF Xylene 150.5 95 Ib/MMSCF n -Hexane 3238.3 95 Ib/MMSCF 224 TMP 2.5 95 Ib/MMSCF 18 of 19 K:\PA\2019\19WE0360.CP2.xlsm Separator Venting Regulatory Analysis Worksheet The regulatory requirements below are determined based on requested emissions. Colorado Regulation 3 Parts A and B -APEN and Permit Requirements �Sour_e :s Ir. s.^.a t1an.AHa'nerren? Aria ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section ll.O.S.a)? 2. Are total facility uncontrolled VOC emissions greater than 5TPY, NOx greater than 10 TPY or CO emissions greater than SO TPY (Regulation 3, Part B,Section 11.0.3)7 scurcn is in .. a,.._. tainnnan.. a_g NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than )TPY(Regulation 3, PartA, Section 11.0.1.a)? 2. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY arCO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.2)? Colorado Regulation ], Part 0, Section II 1. Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1,2014? 'Source AnnInct Regniation] Pan D. F Section 11.8.2 -General Provisions for Air Pollution Control Equipment Used to Comply with Section II Section II.F - Control of emissions from well production facilities Alternative Emisions Control (Optional Section). a. Is this Separator controlled by a back-up It at combustion d (i.e., notthe primary control device) that is not enclosed? IThe for thin .1-nnoPatpn innot sobin, CR=„l,E.,; 0=1 Pa. 0SPC'c elE2, 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 Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," may,""should,"and "can,"is intended to describe APCD interpretations and recommendations. Mandatoryterminology 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. _ Source Re Source Re Source is: The contra 4[ I VE Hydrocarbon Liquid Loading APEN J(la Form APCD-208 ' MO 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-2OO) 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: 19WE0360 AIRS ID Number: 123 / A038 /003 ID! Section 1 - Administrative Information Company Name': Crestone Peak Resources Operating, LLC Site Name: gighom 17H -P267 Site Location: SESE Section 17 T2N R67W 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 ' 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. 1I �COLORADO fRath:� Page 19 of 96 Permit Number: 19WE0360 Section 2 - Requested Action AIRS ID Number: 123 /A03B/003 ❑ 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 5353.13 must be submitted along with the APEN filing fee. -OR- El MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 0 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 Ft Notes: Requesting a reduced throughput. 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 Ioadout of condensate from tanks Company equipment Identification No. (optional): LOAD -1 For existing sources, operation began on: 11/19/2019 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? Yes No GI ■ Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Yes ❑ No ■ 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 GI If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Yes No O ■ Does this source splash fill less than 6,750 bbl of condensate per year? Yes No SI ■ Does this source submerge fill less than 16,308 bbl of condensate per year? Yes No IN © t oaci 1 07,.2(220 se COLORADO 2 I a....—. at c.boe X.YN b Cmavrawet Page 20 of 96 Permit Number: 19WE0360 AIRS ID Number: 123 /A03B/003 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: 73,000 bbl/year Actual Volume Loaded: This product is loaded from tanks at this faci ity 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: 0.6� Average temperature of bulk liquid loading: 60 ° F True Vapor Pressure: 4.0 Psia ® 60 °F Molecular weight of displaced vapors: 54. lb/lb-mol If this APEN is being filed for vapors displaced from pressurized loading tines, 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 11TM) 40.133683 / -104.90784 Q 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 (AGFM) Velocity (/t/sec) Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Downward ❑ Horizontal ❑ 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): or CD -208 �� _. , L v_ti, „ L., .(.1 , G% 2 2O COLORADO 3 I�°elmemmevatPubtk �:, Page 21 of 96 Permit Number: 19WE0360 AIRS ID Number: 123 / A03B / 003 Pu . _s r)sslci,neo . t - 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: 3,i84 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? Q 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 SO, 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? — 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 SO, NO, 0.068 lo/MMstu AP -42 - - - 0.02 CO 0.31 b/MMBtu AP -42 - - - 0.08 VOC 0.131 lb/bbl Site Specific — -- - 4.77 024 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 APC D 0 - . :', IPEN o C7:2020 se COLORADO 4 I Depots*of ,Public, Page 22 of 96 Permit Number: 19WE0360 AIRS ID Number: 123 /A03B/003 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? ❑ Yes El 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 (lbs/year) Controlled Emissionsb (lbs/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 2,2,4-Trimethylpentane 540841 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 will be operated in full compliance with each condition of General Permit GP07. 07/15/2020 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: E✓ Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $216.00 and the General Permit registration fee of $353.13, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 OR (303) 692-3148 APCD Main Phone Number (303) 692-3150 1 07/2020 .ArIcaskicotoptApt) 5 I ; ao.ni..wet wrk Noe. i4tnwt...t Page 23 of 96 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: 1 9WE0360 AIRS ID Number: 123 / A03B /001 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Crestone Peak Resources Operating, LLC Bighorn 17H -P267 Site Location: SESE Section 17 T2N R67W 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: Sabrina Pryor Phone Number: (303) 774-3923 E -Mail Addressz: sabrina.pryor@crestonepr.com ' Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-205 - Condensate Storage Tankis) APEN - Revision 07/2020 iCOLORADO 1 tm� Heal. environment Permit Number: 19WE0360 AIRS ID Number: 123 / A03B / 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 El 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 £t Notes: Requesting a reduced throughput and providing 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: Condensate storage tanks TANKS 11/19/2019 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Storage tank(s) located at: 0 Exploration Et Production (EftP) site ❑ Midstream or Downstream (non E£tP) site Will this equipment be operated in any NAAQS nonattainment area? Yes No • ■ Are Flash Emissions anticipated from these storage tanks? Yes No p ■ Is the actual annual average hydrocarbon liquid throughput a 500 bbl/day? Yes No p ■ If "yes", identify the stock tank gas -to -oil ratio: 3,58 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 D ■ 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 00 2I COLORADO HMaPalath 6 Environment Permit Number: 19WE0360 AIRS ID Number: 123 / A03B / 001 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bb!/year) Condensate Throughput; Requested Annual Permit Lirrtits (bbllyear) 803,000 From what year is the actual annual amount? Average API gravity of sales oil: 47.8 degrees Tank design: ❑✓ Fixed roof ❑ Internal floating roof RVP of sales oil: 8.3 ❑ External floating roof Storage '', Tank ID # of�Llquid Manifold Storage ` Yes'sels .in $forage dank Total Volume of Storage Tank (bbi) ; Installation Date of Most Recent Storage Vessel in , Storage Tank (month/year) Date of First Pr4du�foh (montblyeat) TANKS 8 4000 11/2019 11/2019 API Number' Welts Serviced by this Storage Tank or ;Tank Battery6 (E&P Sites Only) Name of We[1 Newly Reported Well 05 - 123 - 41200 Bighorn 4A -17H -P267 05 - 123 - 41197 Bighorn 4B -17H -P267 05 - 123 - 41187 Bighorn 4C -17H -P267 05 - 123 - 41293 Bighorn 4D -17H -P267 05 - 123 - 41186 Bighorn 4E -17H -P267 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 EftP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Geographical/Stack Information Geographical coordinates {LatFxudelLorrgitude or urm 40.133683 / -104.90784 ❑✓ 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. Uperator Stack ID No. Discharge Height Above Ground Level(Feet)('F)` Temp. .Flow Rate (A FM) Velocity (fftlsec) 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-205 Condensate Storage Tank(s) APEN - Revision 07/2020 coLo RA DO 3 f .�t�;c i ricaiirtb Envttu�ment Permit Number: 19WE0360 AIRS ID Number: 123 /A036/OO1 [Leave blank unless APCD has already assigned a permit 4 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 Type: Enclosed Combustor MMBtu /hr 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: 3,184 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&P 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 separators, bulk gas from separators to sales, bulk condensate from separators to vapor recovery tower (VRT) and then to tanks, bulk water to storage tanks, and low-pressure gas to enclosed combustor. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2020 4 'COLORADO OcTattrnent !. Health 6 Environment Permit Number: 1 QVVE0360 AIRS ID Number: 123 / A03B / 001 [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? ID 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) V0C Enclosed Combustor (ECD) 95% NOx CO HAPs Enclosed Combustor (ECD) 95 Other: From what year is the following reported actual annual emissions data? —' Use the following table to report the criteria pollutant emissions from source: Pollutant Emission Factor? Actual Annual Emissions Requested Annual Permit Emission Limits) 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 1.632 lb/bbl Site Specific -- — 655 32.76 NO, 0.068 Ib/MMBtu AP -42 — -- — 1.00 CO 0.31 Ib/MMBtu AP -42 -- -- -- 4.55 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? ❑✓ Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Emission Factory ' Actual Annual Emissions Abstract Source Uncontrolled Controlled Chemical Name Service (CAS) ` Number Uncontrolled Basis Units (AP -42, Mfg., etc.) Emissions Os/year) Emissions$ - (lbs/year) Benzene 71432 6.94E-03 lb/bbl Site Specific 5577 279 Toluene 108883 6.96E-03 lb/bbl Site Specific 5590 279 Ethylbenzene 100414 3.71E-04 lb/bbl Site Specific 298 15 Xylene 1330207 2.37E-03 lb/bbl Site Spec 1906 95 n -Hexane 110543 5.24E-02 lb/bbl Site Specific 42053 2103 2,2,4-Trimethylpentane 540841 1.47E-04 lb/bbl Site Specific 118 6 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 a!COLORADO 5 EN Permit Number: 19WE0360 AIRS ID Number: 123 / A03B i 001 [Leave blank unless APCD has already assigned a permit r 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. ( , 1 12/08/2020 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-205 - Condensate Storage Tank(s) APEN - Revision 07/2020 6 lee(COLORADO I Department a wwk Health Environment E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Formt Company Name: Crestone Peak Resources Operating, LLC Source Name: Bighorn 17H -P267 (TANKS) Emissions Source AIRS ID2: 123 / A03B / 001 Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 — 41192 Bighorn 4F -17H -P267 ❑ 05 - 123 - 41189 Bighorn 4G -17H -P267 ❑ 05 - 123 - 41195 Bighorn 4H -17H -P267 ❑ 05 - 123 - 41291 Bighorn 4I -17H -P267 ❑ 05 - 123 - 41292 Bighorn 4J -17H -P267 ❑ 05 - 123 - 41196 Bighorn 4K -17H -P267 ❑ 05 - 123 - 41198 Bighorn 4L -17H -P267 ❑ 05 - 123 - 48762 Bighorn 4M -17H -P267 ❑ 05 - 123 - 48758 Bighorn 4N -17H -P267 ❑ 05 - 123 - 48763 Bighorn 4O -17H -P267 ❑ 05 - 123 - 48761 Bighorn 4P -17H -P267 ❑ 05 - 123 - 48760 Bighorn 4Q -17H -P267 ❑ 05 - 123 - 48759 Bighorn 4R -17H -P267 ❑ 05 - 123 - 48764 Bighorn 4S -17H -P267 ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ 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 B1b-CT-APEN Wellsite Addendum-Bighoml9H CDPHE 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: 19WE0360 AIRS ID Number: 123 / A03B / 002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Site Name: Crestone Peak Resources Operating, LLC Bighorn 17H -P267 Site Location: SESE Section 17 T2N R67W 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: Sabrina Pryor Phone Number: (303) 774-3923 E -Mail Address2: 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 Health& Etwirtnung. Permit Number: 19WE0360 AIRS ID Number: 123 / A03B / 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 Ft Notes: Requesting a reduced throughput and providing 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 11/19/2019 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 Storage tank(s)located at: hours/day 7 days/week 52 weeks/year ❑✓ Exploration Et Production (E&P) site ❑ Midstream or Downstream (non EEtP) site Will this equipment be operated in any NAAQS nonattainment area? Yes No SI ■ Are Flash Emissions anticipated from these storage tanks? Yes No SI ■ 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 ■ O 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-207 - Produced Water Storage Tank(s) APEN - Revision 07/2020 ;COLORADO 2 I PER neaoh agadrm Heattl� b En�lronmm� Permit Number: 19WE0360 AIRS ID Number: 123 /A036/002 ❑ Upward ❑ Horizontal [Leave blank unless APCD has already assigned a permit h and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/year) I Produced Water Throughput: Requested Annual Permit Limits (bbUyear) 803,000 From what year is the actual annual amount? Tank design: ❑✓ Fixed roof ❑ 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 1000 11/2019 11/2019 Wells Serviced by this Storage Tank or Tank Battery(' (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 41200 Bighorn 4A -17H -P267 ■ 05 - 123 - 41197 Bighorn 4B -17H -P267 ■ 05 - 123 - 41187 Bighorn 4C -17H -P267 ■ 05 - 123 - 41293 Bighorn 4D -17H -P267 ■ 05 - 123 - 41186 Bighorn 4E -17H -P267 ■ 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 EEtP 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) 40.133683 / -104.90784 ❑✓ 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 ' (D No. Discharge Height Above Ground Level (Feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-207 Produced Water Storage Tank(s) APEN - Revision 07/2020 coLoRADO 3 I � Department al Public 1 Health& Envitonment Permit Number: 19WE0360 AIRS ID Number: 123 / A03B / 002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: ❑ Combustion Device: Pollutants Controlled: 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: 3,184 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 (MP 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 separators, bulk gas from separators to sales, bulk condensate from separators to vapor recovery tower (VRT) and then to tanks, bulk water to storage tanks, and low-pressure gas to enclosed combustor. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2020 4 COLORADO Wealth `mbr welic an Wealth ntolnnbOM Permit Number: 19WE0360 AIRS ID Number: 123 /A036/002 [Leave blank unless APCD has already assigned a permit . and AIRS !Dl 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): 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? -- Use the following table to report the criteria pollutant emissions from source: Pollutant Emission Factor7 Actual Annual Emissions Requested Annual Permit s Emission Limit(s) 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 0.0397 lb/bbl Site Specific — 15.92 0.80 NO), 0.068 Ib/MMBtu AP -42 -- — 0.04 CO 0.31 Ib/MMBtu AP -42 -- -- — 0.17 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? ❑r 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 Os/year) Controlled Emissions$ Os/year) Benzene 71432 9.44E-04 lb/bbl Site Specific 758 38 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 6.58E-04 lb/bbl Site Specific 529 26 2,2,4-Trimethylpentane 540841 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) APEN - Revision 07/2020 !COLORADO 5! xw�nse+,w�nmmi Permit Number: 19WE0360 AIRS ID Number: 123 / A03B / 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 and willbe operated in full compliance with each condition of the applicable General Permit. c7 / � \ // / 1 �� ('�'�- �- ��-(1 2 17 l , / r �, 12/08/2020 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-207 Produced Water Storage Tank(s) APEN - Revision 07/2020 COLORADO 6 d x.mnuen.i.onm.m E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Forml Company Name: Crestone Peak Resources Operating, LLC Source Name: Bighorn 17H -P267 (PW) Emissions Source AIRS ID2: 123 / A03B / 002 Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 — 41192 Bighorn 4F -17H -P267 ❑ 05 - 123 - 41189 Bighorn 4G -17H -P267 ❑ 05 - 123 - 41195 Bighorn 4H -17H -P267 ❑ 05 - 123 - 41291 Bighorn 4I -17H -P267 ❑ 05 - 123 - 41292 Bighorn 4J -17H -P267 ❑ 05 - 123 - 41196 Bighorn 4K -17H -P267 ❑ 05 - 123 - 41198 Bighorn 4L -17H -P267 ❑ 05 - 123 - 48762 Bighorn 4M -17H -P267 ❑ 05 - 123 - 48758 Bighorn 4N -17H -P267 ❑ 05 - 123 - 48763 Bighorn 4O -17H -P267 ❑ 05 - 123 - 48761 Bighorn 4P -17H -P267 ❑ 05 - 123 - 48760 Bighorn 4Q -17H -P267 ❑ 05 - 123 - 48759 Bighorn 4R -17H -P267 ❑ 05 - 123 - 48764 Bighorn 4S -17H -P267 ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ 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 B16-CT-APEN Wellsite Addendum-Bighornl9H 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 lacks 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: 19WE0360 AIRS ID Number: 123 / Ao36 /005 [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: Bighorn 17H -P267 Site Location: SESE Section 17 T2N R67W 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 Address2: 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 12/2019 ,COLORADO Haslt�BLnWronment Permit Number: 19WE0360 AIRS ID Number: 123 / A03B / 005 [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 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 - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info It Notes: Requesting a reduced throughput. 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. This point does not include emissions from the downstream Vapor Recovery Tower. Controlled by enclosed combustor. Company equipment Identification No. (optional): Buffer For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: 11/19/2019 O 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 12/.2019 days/week weeks/year O Yes ❑ Yes ❑ Yes ❑ No O No O No COLORADO 2 IOOP W ra. EtItwwx Naiifh 6 in�4onment Permit Number: 19WE0360 AIRS ID Number: 123 / A03B / 005 [Leave blank unless APCD has already assigned a permit # and AIRS ID Section 4 - Process Equipment Information ❑r 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/pint 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 Parameters5: Vented Gas Properties: ❑r No Vent Gas Heating Value: 2 409 BTU/SCF Requested: 3.80 MMSCF/year Actual: __ MMSCF/year -OR- Requested: bbl/year Actual: bbl/year Molecular Weight: 42.2528 VOC (Weight %) 74.8783 Benzene (Weight %) 0.3320 Toluene (Weight %) 0.4447 Ethylbenzene (Weight %) 0.0223 Xylene (Weight %) 0.1350 n -Hexane (Weight %) 2,9049 2,2,4-Trimethylpentane (Weight %) 0.0022 Additional Required Documentation: ❑✓ Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et 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 12/2019 3 I a COLORADO new.terlene of wmm Health f. Environment Permit Number: 1 9WE0360 AIRS ID Number: 123 / A036 / 005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.133683 / -104.90784 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. ©peratQr Stac K lD pia` atsrharge Height �rouhd Le�rar Temp FAQ #aie � atity 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: NA MMBtu/hr Type: Enclosed Combustor Make/Model: N/A Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: NA 95 95 % Waste Gas Heat Content: Constant Pilot Light: 0 Yes ❑ No Pilot burner Rating: 2,409 0.025 Btu / scf MMBtu / hr Other: Pollutants Controlled: Description: Requested Control Efficiency: % Form APCD-211 - Gas Venting APEN - Revision 12/2019 cOLORADO 4 I d Public xn`etl.6 Environment Permit Number: 1 9WE0360 AIRS ID Number: 123 / A03B / 0055 [Leave blank unless APCD has already assigned a permit r 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? ❑r Yes ❑ No If yes, describe the control equipment AND state the collection and control efficiencies (report the overall, or combined, values if multiple emission control methods were identified in Section 6): Pollutant Control Equipment Description Collection Efficiency (% of total emissions captured by control` equipment) Control Efficiency (% reduction of captured emissions) PM SO. NO. CO VOC Enclosed Combustor 100% 95% HAPs Enclosed Combustor 100% 95% Other: From what year is the following reported actual annual emissions data? 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 Emissionsb (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) PM SO. NO. 0.068 Ib/MMBtu AP -42 -- — -- 0.32 CO 0.31 Ib/MMBtu AP -42 — — — 1.45 VOC 83,478 lb/MMscf Site specific -- — 159 7.93 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 Uncontmited Basis Units Source , (AP-42' Mfg., etc.) Uncontrolled Emissions abs/year) Sontrplled Emissions' abs/year) Benzene 71432 370 lb/MMscf Site specific 1,406 70.32 Toluene 108883 496 lb/MMscf Site specific 1,884 94.20 Ethylbenzene 100414 24.89 lb/MMscf Site specific 94.57 4.73 Xylene 1330207 150 lb/MMscf Site specific 572 28.59 n -Hexane 110543 3,239 lb/MMscf Site specific 12,307 615 2,2,4-Trimethylpentane 540841 2.50 lb/MMscf Site specific 9.51 0.48 Other: ❑r 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 12/2019 as COLORADO 5 IHEnvironment Permit Number: 19WE0360 AIRS ID Number: 123 / A03B / 005 [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. -, 1 ,ie., 12/08/2020 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 $191.13 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 12/2019 �!a. COLORADO 6 I it..IN > b E mlronment Hello