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Home My WebLink About20200624.tiffCOLORADO Department of Public Health & Environment Weld County - Clerk to the Board 11500 St PO Box 758 Greeley, CO 80632 September 30, 2020 Dear Sir or Madam: RECEIVED OCT 0 2 2020 WELD COUNTY COMMISSIONERS On October 1, 2020, the Air Pollution Control Division will begin a 30 -day public notice period for PDC Energy, Inc. - Lincoln State 3-18 Pad. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Public Notice Coordinator 4300 Cherry Creek Drive S., Denver, Co 80246-1530 P 303-692-2000 www.colorado.govfcdphe Jared Polls, Governor I Jill Hunsaker Ryan, MPH, Executive Director 17061;c P. e're'..) to/l'}/2.o cc : PL(Tp) tr(L(,os) Pc.J(TM/ER/CH/Cx) lofo f2o 2©20-0624 TPA Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: PDC Energy, Inc. - Lincoln State 3-18 Pad - Weld County Notice Period Begins: October 1, 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: PDC Energy, Inc. Facility: Lincoln State 3-18 Pad Exploration Et Production Well Pad NENW SEC 18 T6N R66W Weld County The proposed project or activity is as follows: Applicant proposes the construction of one condensate tank battery (covered by permit 19WE0724), one condensate loadout point (covered by permit 19WE0725), one produced water tank battery (covered by GP08), and three engines (covered by GP02) at a new EELP facility. 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 19WE0724 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: Ben Fischbach Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 COLORADO Department of Public Health @ Environment COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado CONSTRUCTION PERMIT Permit number: 19WE0724 Issuance: 1 Date issued: Issued to: PDC Energy, Inc. Facility Name: Plant AIRS ID: Physical Location: County: Description: Lincoln State 3-18 Pad 123/A069 NENW SEC 18 T6N R66W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description TNK 1 6 001 Six (6) 400 barrel fixed roof storage vessels used to store condensate Enclosed Flare This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit must be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self - certify compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air-permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 2. This permit must expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen Page 1 of 14 4), COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 3. Upon issuance of this permit, the operator must install equipment necessary to monitor control device pilot light status and auto -igniter status as described in this permit. 4. The operator must complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The operator must retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants must not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO, VOC CO TNK 1-6 001 --- 2.4 26.9 11.1 Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant must not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants must not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants must apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, must be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder must calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The owner or operator must use the emission factors and calculation methods found in "Notes to Permit Holder" to calculate emissions and show compliance with the limits. The owner or operator must submit an Air Pollutant Emission Notice (APEN) and receive a modified permit prior to the use of any other method of calculating emissions. 8. The owner or operator must track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility potential 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, Page 2 of 14 C4* tzef COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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 VOC 9. 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.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled TNK 1-6 001 Emissions are routed to a bank of four (4) Enclosed Flares. Make: IES, Model: 96", SNs: 96-01-89, 96- 01-115, 96-01-116, 96-01-117 VOC and HAP PROCESS LIMITATIONS AND RECORDS 10. This source must be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates must be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit TNK 1-6 001 Condensate throughput 1,720,574 barrels The owner or operator must monitor monthly process rates based on the calendar month. Compliance with the annual throughput limits must be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder must calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 11. On a minimum of an hourly basis, the owner or operator shall monitor the control devices for the presence of a pilot light and an operational auto -igniter on each device. These monitoring records shall be used to calculate control device downtime. During periods without the presence of a pilot light and/or an operational auto -igniter, the flow volume from emissions source(s) shall be assigned a 0% control efficiency. These monitoring records must be maintained for a period of five (5) years, and a summary of monthly pilot light downtime and vapor flow during pilot light downtime shall be provided to the division upon request. Page 3 of 14 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado STATE AND FEDERAL REGULATORY REQUIREMENTS 12. 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) 13. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 14. 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) 15. The combustion device covered by this permit is subject to Regulation Number 7, Part D, Section II.B.2. General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section II, it must be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, Part D, Section II.A.23; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. This flare must be equipped with an operational auto -igniter according to the schedule in Regulation Number 7, Part D, Section II.B.2.d. 16. 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. 17. 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. 18. 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, Page 4 of 14 COLORADO Air Pollution Control Division (Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado owners or operators must maintain the information according to Regulation Number 7, Part D, Section V.C. for inclusion in the annual report. (Regulation Number 7, Part D, Section V) OPERATING Et MAINTENANCE REQUIREMENTS 19. Upon startup of these points, the owner or operator must follow the most recent operating and maintenance (OatM) 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 OFtM 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 20. The owner or operator must complete site specific sampling including a compositional analysis of the pre -flash pressurized condensate routed to these storage tanks and, if necessary for emission factor development, a sales oil analysis to determine RVP and API gravity. Testing must be in accordance with the guidance contained in PS Memo 05-01. Results of testing must be used to determine site -specific emissions factors for VOC and Hazardous Air Pollutants using Division, approved methods. Results of site -specific sampling and analysis must be submitted to the Division as part of the self -certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 21. The owner or operator must demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen -minute period during normal operation. (Regulation Number 7, Part D, Sections I.C, II.B.2. and II.A.23) 22. The owner or operator must conduct an initial source compliance test to measure the mass emission rates of the pollutants listed below, demonstrate compliance with the VOC emissions limit in this permit, and to demonstrate a minimum destruction efficiency of 98% for volatile organic compounds (VOC). During the test, the owner or operator must measure: • mass emission rates of VOC at the inlet of the control device (M;) using EPA or other division approved methods; • mass emission rates of VOC at the outlet of the control device (Mo) using EPA or other division approved methods; and • mass emission rates of NOx and CO at the outlet of the control device using EPA or other division approved methods. Additionally, the following parameters may be required to be measured during the test: • combustion chamber temperature; • gas flow rate; • supplemental fuel flow rate; • gas heat content; and • gas composition. Page 5 of 14 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado The destruction efficiency (DE) for VOC must be calculated using the following equation: DE (%) = 100*(M;-Ma)/M; The test protocol, test, and test report must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual. The test protocol must include testing under all operating scenarios of the control device. The test protocol must be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test will be conducted without prior approval from the Division. Within thirty (30) days following completion of the test(s), a compliance test report must be submitted to the Division for review. Additional time may be granted upon written request. Any compliance test conducted to demonstrate compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the Process Limit(s) for that averaging time as indicated in the Process Limitations and Records section of this permit. (Regulation Number 3, Part B., Section III.G.3) Results of the initial compliance tests must be submitted to the Division as part of the self - certification. Actual emissions calculations must be completed in accordance with the "Notes to Permit Holder" section of this permit. If the results of the initial compliance test do not demonstrate compliance with the emissions limits contained within this permit or do not demonstrate a minimum destruction efficiency of 98% for volatile organic compounds (VOC) for each operating scenario, the owner or 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 these inaccuracies. Periodic Testing Requirements 23. On an annual basis, the owner or operator must complete a site specific analysis ("Analysis"), including a compositional analysis of the pre -flash pressurized hydrocarbon liquid routed to the equipment covered in this permit. Testing must be in accordance with the guidance contained in PS Memo 05-01. Results of the Analysis must be used to demonstrate that the emissions factor established through the Analysis is less than or equal to the emissions 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 factors 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 these inaccuracies. 24. On an annual basis, the owner or operator must conduct a source compliance test to measure the mass emission rates of the pollutants listed below, demonstrate compliance with the VOC emissions limit in this permit, and to demonstrate a minimum destruction efficiency of 98% for volatile organic compounds (VOC). During the test, the owner or operator must measure: • mass emission rates of VOC at the inlet of the control device (M) using EPA or other division approved methods; • mass emission rates of VOC at the outlet of the control device (Mo) using EPA or other division approved methods; and • mass emission rates of NOx and CO at the outlet of the control device using EPA or other division approved methods. Page 6 of 14 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Additionally, the following parameters may be required to be measured during the test: • combustion chamber temperature; • gas flow rate; • supplemental fuel flow rate; • gas heat content; and • gas composition. The destruction efficiency (DE) for VOC must be calculated using the following equation: DE (%) = 100*(M;-Mo)/M; The test protocol, test, and test report must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual. The test protocol must include testing under all operating scenarios of the control device. The test protocol must be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test will be conducted without prior approval from the Division. Within thirty (30) days following completion of the test(s), a compliance test report must be submitted to the Division for review. Additional time may be granted upon written request. Any compliance test conducted to demonstrate compliance with a' monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the Process Limit(s) for that averaging time as indicated in the Process Limitations and Records section of this permit. (Regulation Number 3, Part B., Section III.G.3) Actual emissions calculations must be completed in accordance with the "Notes to Permit Holder" section of this permit. If the results of the periodic compliance test do not demonstrate compliance with the emissions limits contained within this permit or do not demonstrate a minimum destruction efficiency of 98% for volatile organic compounds (VOC) for each operating scenario, the owner or 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 these inaccuracies. ALTERNATIVE OPERATING SCENARIOS 25. The control device may be replaced with a like -kind control device in accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a revision to this permit or obtaining a new construction permit. A like -kind control device shall be the same make and model as authorized in this permit. All control device replacements installed and operated as authorized by this permit must comply with all terms and conditions of this construction permit. The owner or operator shall maintain a log on -site or at a local field office to record the start and stop dates of any control device replacement, the manufacturer, model number and serial number of the replacement control device. 26. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model, and serial number of the replacement control device must be filed with the Division within 14 calendar days of commencing operation of a replacement control device under the Alternative Operating Scenario provision. The APEN must be accompanied by the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an Alternative Operating Scenario and has replaced the control device. Page 7 of 14 COLORADO Au Pollution Control Division Department of Public Heath & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 27. Within one hundred and eighty days (180) of startup of the replacement control device in accordance with the Alternate Operating Scenario provision, the owner or operator must conduct an initial source compliance test to measure the mass emission rates of the pollutants listed below, demonstrate compliance with the emissions limit in this permit, and to demonstrate a minimum destruction efficiency of 98% for volatile organic compounds (VOC). During the test, the owner or operator must measure: • mass emission rates of VOC at the inlet of the control device (M) using EPA or other division approved methods; • mass emission rates of VOC at the outlet of the control device (MO using EPA or other division approved methods; and • mass emission rates of NOx and CO at the outlet of the control device using EPA or other division approved methods. Additionally, the following parameters may be required to be measured during the test: • combustion chamber temperature; gas flow rate; supplemental fuel flow rate; gas heat content; and gas composition. The destruction efficiency (DE) for VOC must be calculated using the following equation: DE (%) = 100*(M;-Mo)/M, The test protocol, test, and test report must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual. The test protocol must include testing under all operating scenarios of the control device. The test protocol must be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test will be conducted without prior approval from the Division. Within thirty (30) days following completion of the test(s), a compliance test report must be submitted to the Division for review. Additional time may be granted upon written request. Any compliance test conducted to demonstrate compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the Process Limit(s) for that averaging time as indicated in the Process Limitations and Records section of this permit. (Regulation Number 3, Part B., Section III.G.3) Actual emissions calculations must be completed in accordance with the "Notes to Permit Holder" section of this permit. If the results of the initial compliance test do not demonstrate compliance with the emissions limits contained within this permit or do not demonstrate a minimum destruction efficiency of 98% for volatile organic compounds (VOC) for each operating scenario, the owner or 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 these inaccuracies. Page 8 of 14 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado ADDITIONAL REQUIREMENTS 28. A revised Air Pollutant Emission Notice (APEN) must be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 3e whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NO), per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 29. The requirements of Colorado Regulation No. 3, Part D must apply at, such time that any stationary source or modification becomes a major stationary source or major modification solely by virtue of a relaxation in any enforceable limitation that was established after August 7, 1980, on the capacity of the source or modification to otherwise emit a pollutant such as a restriction on hours of operation (Reference: Regulation Number 3, Part D, V.A.7.B). 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 Page 9 of 14 COLORADO Air Pollution Control Division Department of Public Health & Enwonrnent Dedicated to protecting and improving the health and environment of the people of Colorado 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 operator's 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 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: DRAFT Ben Fischbach Permit Engineer Page 10 of 14 xN44;,R"�.� COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado Permit History Issuance Date Description Issuance 1 This Issuance Issued to PDC Energy, Inc. New Synthetic Minor Facility Page 11 of 14 J COLORADO Air Pollution Control Division Departmental Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder must pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator must notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. N AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 001 Benzene 71432 6,246 125 Toluene 108883 4,869 97 Ethylbenzene 100414 368 7 Xylenes 1330207 1,568 31 n -Hexane 110543 51,421 1,028 2,2,4- Trimethylpentane 540841 235 5 (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: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 0.0028 0.0028 AP 42 CO 0.0128 0.0128 VOC 1.564 0.0313 Promax 71432 Benzene 3.63 * 10-3 7.26 * 10"5 Page 12 of 14 COLORADO Air Pollution Control Division Department of Public Health fi Environment Dedicated to protecting and improving the health and environment of the people of Colorado CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source 108883 Toluene 2.83 * 10 3 5.66 * 10-5 100414 Ethylbenzene 2.14 *10-4 4.28 * 10-6 1330207 Xylene 9.11 *10-4 1.82 * 10-5 110543 n -Hexane 2.99* 10-2 5.98 * 10-4 540841 2'2'4-1.37* Trimethylpentane 104 2.74* 10"6 Note: The controlled emissions factors for this point are based on a control efficiency of 98%. NOx and CO emission factors are based on a gas heat content of 2572 Btu/scf. Actual controlled emissions shall be calculated using the following method: Monthly Actual Emissions = [(Vtotal — VPLX) X EF x (100% — CE)] + [VPLx x EF ] where: Vtotai = Total volume of condensate throughput (bbl) VPLx = Total volume of condensate throughput while pilot light was not lit or auto -igniter was not operational (bbl) EF = Most recent approved uncontrolled emission factor (lb/bbl) CE = 98% 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN must be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, CO, NOx, n -Hexane, Total HAP PSD Synthetic Minor Source of: VOC, CO, NOx NANSR Synthetic Minor Source of: VOC, NOx MACT HH Not Applicable 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: Page 13 of 14 COLORADO Air Pollution Control Division Department of Public Health Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado http://www.ecfr.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart UUUU NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart M - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ- Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX Page 14 of 14 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Package If: Received Date: Review Start Date: Ben Fischbach 414101 7/2/2019 9/11/2019 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? Yes If yes, for what pollutant? El Carbon Monoxide (Co) PDC Energy, Inc. 123 A069 Lincoln State 3-19 Pad Weld County Section 02 - Emissions Units In Permit Application Particulate Matter (PM) Quadrant Section Township Range NENW 18 6N 66 Ozone (NOu & VOC) AIRS Point# Emissions Source Type Equipment Name Emissions Control? Permit# Issuance# Self Cart Required? Action Engineering Remarks 001 Condensate Tank --- TNK 1-6 Yes 19WE0724 1 Yes Permit Initial Issuance Section 03 - Description of Project Applicant proposes the construction of this condensate tank battery, three engines (covered by GP02), one produced water tank battery (covered by GP08) and one liquid loadout point (covered by permit 19W E0725), all located a₹ a new E&P well pad site. Original application (received 7/2/19) was submitted on behalf of SRC Energy, Inc. During the processing of this project, ownership of this facility was transferred to PDC Energy, Inc. Permit will be issued to PDC Energy, Inc. Section 04 - Public Comment Requirements Is Public Comment Required? Yes If yes, why? Requesting Synthetic Minor Permit Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? No If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) No Yes SO2 NOx CO VOC PM2.5 PM10 TSP HAPs Is this stationary source a major source? If yes, explain what programs and which pollutants hen 502 Prevention of Significant Deterioration (PSD) _ Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) No NOx CO J J VOC PM2.5 PM10 TSP ❑J HAPs Condensate Storage Tank(s) Emissions inventory 001 Condensate Tank Facility AIRs ID: .`123 County A069 001 Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Six(6)400 bbl Fixed Roof Condensate Storage Tanks connected via liquid manifold. Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency A: ECD (4x IES 96") 98 Section a3 - Processing Rate Information for Emissions Estimates Primary Emissions -Storage Tank(s) Actual Condensate Throughput = Requested Permit Limit Throughput= 1,433,783 Barrels (bbl) per year 1,720,574 Barrels (bbl) per year Actual Condensate Throughput While Emissions Controls Operating = Requested Monthly Throughput= .,433',703 Barrels (bbl) per year 146131 Barrels (bbl) per month Potential to Emit (WE) 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 = Potential to Emit (PTE) heat content of waste gas routed to combustion device = Section 04 - Emissions Factors & Methodologies 1,720,574 Barrels (bbl) per year 2971.89 Btu/scf 16.13 scf/bbl Will this storage tank emit flash emissions? ^u .s 1 MMBTU per year r: 315 MMBTU per year .. 21' MMBTU per year Emission Factors Condensate Tank Emission Factor Source Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) (Condensate Throughput) (Condensate Throughput) VOC 1.564 -. 9 - Site Spec' Benzene 3.63E-03 a _' Site Spae ),' l .' Toluene 2.83E-03 :. Site Spedif 4_11 s y: Site Specific Site Specific Ethylhenzene 2.14E-04 4 2E.E.Cti, Xylene 9.11E-04 3.≥=2: Oo n -Hexane 2.99E-02 . 5.981-04 Site Specific LE oeosilash) �.,; 224TMP 1,37E-04 '.74 -06 Site Specific E.F.(includec fl ash} Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) (lb/bbl) Emission Factor Source (waste heat combusted) (Condensate Throughput) PM10 - ...0OC.5 PM2.5 C. 0`000 NOx 0.0680 C220123 AP -42 Chapter 13.5)ndustrla( Flares (5Ox) CO 0.3100 .. 3129 AP -42 Chapter 13.5 Industrial Flares (CO) ., Section OS - Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month) VOC 134H.16 1120 84 22 42 1345 16 26.0 4510 PM10 0.00 000 2.O 0.40 a0 2 PM2.5 2,90 000 ..\., • ;.'3 11.1 NOx 2 43 2.02 2.02 2.10 r IS -It 2 CO 11..F 9.12 5.22 _-..a tilt 145-I Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled fibs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year) Benzene 6246 5205 104 `244 129 Toluene 4869 411.9 61 4849 Ethylbenzene 368 __. 3111 Xylene n -Hexane 1368 :706 24 .o., 51421 929950 857 52421 ..20 224 TMP 235 01 4 235 S Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requticv a dernirt Regulation 7, Part D,Section LC, D, E, F Storage tank is robin, to Regulation 7, Pa:' D. 9e fon I C F Regulation 7, Part D,Section I.G, C Storage, Tank is not vUbieet to ,gulaeiov O1 Sectict' .1 Regulation 7, Part D,Section II.B, C.1, C.3 storage ta0k 5 subject to Reg.d_ticn 7, Part 0. Sect:on '•. B, ,.1 u 2 3 Regulation 7, Part D,Section ll.C.2 Storage tank is subject to Regulatov 1. Part,, 10131 .'.0.1 Regulation 7, Part D,Section ll.C.4.a.(i) Storage Tank :s no: aub,ect to Regulation 1, Part 3 buSy". _ -. Regulation 7, Part D,Section ll.C.4.a.(ii) Storage Tanknot sulkies. a 3 . ,., c. , Regulation 6, Part A, NSPS Subpart Kbto'119931 Regulation 6, Part A, NSP5 Subpart 0000 9501 -aye Tana :s dot subj11c• to :•;:,P5 00_ NSP5 Subpart OOOOa 5twr il Tank .,lot, 1-,, P01:1O--3OOa0 Regulation 8, Part E, MACT Subpart OH sfcragn "tank is at sur:,Fct to MAC, iti (See regulatory applicability worksheet for detailed analysis) 2 of 7 K:\PA\2019\19 W E0724.CP1 Condensate Storage Tank(s) Emissions Inventory Section 07 -Initial and Periodic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? If yes, the permit will contain en 'Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company use a site specific emissions factor to estimate emissions7 If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn et the facility being permitted? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it maybe appropriate to use an older site -specific sample. If no, the permit will contain. en "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based an inlet and outlet concentration sampling Section 08 - Technical Analysis Notes NOx and CO emissions differ slightly between APEN and this PA book, due to a difference in calculation methodology. As all yearly emission values for NOx and CO are within rounding error (between PA and APEN), will accept and permit based on APEN reported values. Promax model which was initially submitted with this project didn't change global atmospheric pressure from 14.7 psis to 12.12 pea (Denver's ambient pressure), which resulted in a pressurized liquid stream pressure specification which was slightly higher than it should have been, due to a pressure entry inpsig, and the global atmospheric pressure reflecting sea level (pressurized liquid showed an abs pressure of 30.2959 instead of the 27.72 psia (which would reflect an ambient 12.12 psia and a gauge pressure of 15.6 psig from the pressurized liquid sample). Operator submitted a revised Promax model demonstrating that the initial "mis-specification" resulted in a more conservative emission factor estimation, which is acceptable and will be used in permitting. While Promax predicted emission factors seem relatively low, they were further verified as conservative through a cursory EPA TANKS model, which itself is generally considered to yield overly -conservative results. - - - W&B emission factor estimation was also verified as accurate through use of TANKS 4.0.9d with conservative choices made for petroleum liquids. This facility is equipped with a LACT unit which hasen estimated 10% annual downtime. Section 09 - Inventory SCC Ceding and Emissions Factors r AIRS Paint If 001 Process It SCC Code 01 4-04-003-11 Fixed Roof Tank, Condensate working 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 NOx 0.07 0 lb/1,000 gallons condensate throughput VOC 37.2 98 lb/1,000 gallons condensate throughput CO 0.31 0 lb/1,000 gallons condensate throughput Benzene 0.09 98 lb/1,000 gallons condensate throughput Toluene 0.07 98 lb/1,000 gallons condensate throughput Ethylbenzene 0.01 98 lb/1,000:gallons condensate throughput Xylene 0.02 98 lb/1,000 gallons condensate throughput n -Hexane 0.71 98 lb/1,000 gallons condensate throughput 224 TMP 0.00 98 lb/1,000 gallons condensate throughput 3 of 7 - K:\PA\2019\19WE0724.CP1 Storage Tank Regulatory Analysis Worksheet The regulatory requirements below are determined based on requested emissions. Colorado Regulation 3 Parts A and B-APEN and Permit Requirements ATTAINMENT 1. Are uncontrolled actual emissions tram any criteria pollutants from this individual source greater than 2TPY (Regulation 3, Part A, Section l l.D.l.a)? Source Requires an APES. Go to 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See P5 Memo 05 01 Definitions 1.12 ard1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, Not greater than 10 TPY or CO emissions greaterthan lO TPY (Regulation?, Parts, Section 11.0317 Mee,. Atrvirimum Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than. 1 TPY (Regulation 3, Part A, Section!l.D.1.a)? 2. Is the construction date (service date) priorto 12/30/2002 and not modified after 12/31/2002 (See PS Memo 0501 Definitions 1.12 and1.14 and Section 2for additional guidance an grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 2TPY, NOxgreaterthan STPY or CO emissions greater khan to TPY (Regulation 3, Part B,Sedion 11.0.21? Colorado Regulation 7, Part O, Section I.Cf &G - 1. Is this storagetank located in the 8 -hr ozone control area or any ozone non- attainment area or attainment/maintenance area (Regulation?, Part D, Section [Al)? 2. Is this storage tank located at ail and gas operations that collect, store, or handle hydrocarbon liquids or produced water AND that are located at or upstream of a natural gas processing plant nteguletlon 7, Part D, Section I.A.1)? 3. Is this storage tank located at a natural gas processing plant (Regulation 7, Part D, Section I.0)? 4. Does thlistorage tank contain condensate? 5. Does this storagetank exhlbt"Flash" (e.g,storing non -stabilized liquids) emissions (Regulation 7, part 0, Seitlon I.G.2)? 6 Are uncontrolled actual emissionsf this storege tank equalto or greater than 2 tons per year VOC (Repletion 7, Part 0, Sectiono.3.a(ii)1? 1 obrametardI C.F Part D, Section I.C:1 -General Requirements for Air Pollution Control Equipment -Prevention of Leakage Part 0, Section 1.02- Emission Estimation Procedures Part D, Section I.D-Emlasions Control Requirements Part D, Section I.E - Monitoring Part 5, Section LF-Recordkeeping and Reporting not i Part 5, Section I.G.2- Emissions Control Requirements Part D,Section 1.C.1.a and b -General Requirements for Air Pollution Control Equipment -Prevention of Leakage Colorado Regulation 7, Part D, Section II 1. Is this storage tank located ata transmission/storage facility? 2. Is this storage tank' located at an oil and gas exploration and production operation , well production facility', natural gas compressorstadona or natural gas processing plant°(Regulation 7, Part 0, Section 11.C)?. 3. Does this storage tank have a fixed roof (Regulation 7, Part D, Section I I.A.20)? 4. Are uncontrolled actual emissions of this storage tank equal to or greater than 2 tons per year VOC(Reguletion 7, Parte, Section lI.C1.c? IMe € oil Part e, Section be— Provisions for Air Pollution Control Equipment and Prevention of Emissions Part 0, Section 11.0.3 - Emissions Control and Monitoring Provisions Part 0, Section II.C.3- Recordkeeping Requirements 5 Does the storage tank contain only st bl d liquids (Regulation 7, Pert D, Section IlC.2.b)? Part e, Section II.C.2- Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment Is the controlled storagetank located at a well production facility, natural gas compressor station, or natural gas processing plant constructed on or after May 1, 2020 or located et a facility that was modified on or after May 1,2020,such 6. that an additional controlled storage vessel is constructed to receive anantidpated increase In throughput of hydrocarbon liquids or produced water (Regulation 7, Part 0, Section ll.C.4.a.(i)? Is the controlled storage tank located at a well production facility, natural gascompress t natural gas processing plant coustructedon or after January 1, 2021 or located at a falltythat was modified on or after January 1, 7. 2021, such that an additional controlled storagevessel is constructed to receive an anticipated Incren throughput of hydocarhon liquids or d dwater(Regulation 7, Part 0,Section ll.C4.a.{)? 40 CFR. Part 60, Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the individual storage vessel capacity greater than or equal to 75 cubic meters (m') ('472 BBIs] (40 CFR 60.115h(a))? 2. Does the storage vessel meet the following exemption in 60.111b(d)(4)7 a. Does the vessel has a design capacity less than or equal to 1,589.8744' ['10,000 BBL] used for petroleum' orcondensate stored,processed, or treated prior to custody transfer' as defined in -60.111b? 3. Wasfhb atoragevessel constructed,reconstructed, or modified (see definitions 40 CFR, 60.2) afterluly23, 1984(40 CFR60.11ob(a))? 4. Does the tank meet the definition of "storage vessel"' in 60.1116? 5. Does tha storage vessel store a"volatile organic liquid (VOL)'"°as defined in 60.1116? 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 ['-29.7 psi) and without emissions to the atmosphere (60.110b(d)(2))?; ar b. The design capacity is. greaterthan or equal to 151 mr(`950 BBL] and stores a liquid with a maximum true vapor pressure lessthan 3.5 kPa (60.1106(6))?; or c. Ore design capacity is greater than or equal to 75 M. ('472 BBL] but less than 151 me ('555 BBL] end stores: a liquid with a maximum true vapor pressure• Iessthan 15.0 kPa(60.110b(b))? Does the storagetank meet either one of the following exemptions from control requirements: a. The design capacity is greater than or equal to 151 m' (`950 BBL] and stores a liquid with a maxlmumtrue vapor pressure greater than or equal to 35 kPa but less than 5.2 kPa?; or b. The design capacity is greater than orequal to 75 M. (`472 BBL) but less than 151 ms ('950 BBL] and stores a liquid with a maximum true vapor pressure greaterthan or equal to 15.0 kPa but Iessthan 27.6 kPa? NAM 90 CFR, Part 60, subpart 0000/0000a, Standards of. Performance far Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this storage vessel located at a facility In the onshore all and natural gas production segment, natural gal processing segment or natural gas transmission and storage segment of the industry? 2 Wasthastorage vessel constructed,reconstructed, or modified (see definitions 40 CFR. 60.2) between August23, 2011 and September 18, 2015?. 3. Wasthis storage vessel constructed, reconstructed, or modified (see defin@ions 40 CFR, 60.2) after September 18, 2015? 4. Are potential VOC embsions'from the individual storage vessel greater than or equal to 6 tons per year? 5. Does this storage vessel meet the definition of "storage vessel"a per 60.5430/60.5430a? 6. Is the storage vessel subiect to and controlled in accordance with re u,rements for storage vessels in 40 CFR Part 60 Sub art Kb or 40 CFR Part 63 Sub art NH? Go to next question Source Requires a permit Source Requires an APEN. Go to Go to next question Source Requires a permit Continue- You have indicated tit Continue - You have indicated th Storage Tank is nn[subject to Re continue -you have indicated tit Go to the next question -You ha Go to the next question Source is subjedto parts of Reg. Nn E, 7w- i Sources subject toall provision. Storage Tank is not subject NSPS [Note: If a storage vessel Is previously determined to besubjed m NSPS 0000/0000a due to emissions above 6 tons per year VOC on the applicability determination date, it should remake subject to NSPS 000510000a per 6o.S365(el(2)/60.5365a(e)(2)even It potential VOC emissions drop below 6 tons per Year] 40 CFR, Part 63. Subpart MAR HH, Oil and Gas Production Facilities 1. Is the.. storage tank boated at an oil and natural gas. production faclidythat meetseither of the following criteria; a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)l; OR b. A facility thatprocesses, 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(2)(39? 2. lsthe tank located at a facility that is major' for HAP,? 3. Does the tank meet the definition of "storage vessel"`in 63.761? 4. Does the tank meet the definition of"storage vessel with the potential for flash emissions"' per 63.761? 5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb. ornubpart 0000? Continue -You have indicated th Storage Tank Is not subject NSPS Ga to the next question Storage Tan k is not subject NIPS I's (continue- You have indicated t1 Subpart A, General provisions per 563.764 (a) Table 2 §63.766 - Emissions Control Standards 563.773, Monitoring §63.774-Recordkeeping §63.775 -Reporting RACT Review RACT review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. It the tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis if contains may hot 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 -mandatary language such as "recommend,"'may,"'should,"and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must"and "required"'are Intended to describe controlling requirements under She 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 Tank is not subject MAC COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION FACILITY EMISSION SUMMARY Company Name County AIRS ID Plant AIRS ID Facility Name SRC Energy, Inc. 123 A069 Lincoln State 3-18 Pad History File Edit Date 9/28/2020 Ozone Status Non -Attainment EMISSIONS - Uncontrolled (tons per year EMISSIONS With Controls (tons oer year POINT AIRS ID PERMIT Description PM10 PM2.5 H2S SO2 NOx VOC Fug VOC CO Total HAPs PM10 PM2.5 H2S SO2 NOx VOC Fug VOC CO Total HAPs REMARKS Previous FACILITY TOTAL 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 New Facility - No Previous Total Previous Permitted Facility total 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 001 19WE0724 Six (6) 400 bbl Condensate Tanks - 2.4 1,345.2 11.1 32.4 2.4 26.9 11.1 0.6 002 19WE0725 Hydrocarbon Liquid Loading 0.1 43.5 0.2 1.0 0.1 2.2 0.2 0.0 003 GP08 Two (2) 400 bbl Produced Water Tanks 0.2 20.8 1.0 1.2 0.2 5.9 1.0 0.1 004 GP02 Waukesha L5794 GSI, 1380 hp, 4SRB, (an: C-17764/1) 0.4 0.4 193.1 6,0 146,5 1.4 0.4 0.4 6.7 2.7 10.0 1.4 005 GP02 Doosan D21.9L, 550 hp, 4SRB, (sn: EZYOF8030B0) 0.2 0.2 39.7 3.7 66.9 0.5 0.2 0.2 3.7 3.7 8.0 0.5 006 GP02 Doosan D21.9L, 550 hp, 4SRB, (sn: EZYOF702179) 0.2 0.2 39.7 3.7 66.9 0.5 0.2 0.2 3.7 3.7 8.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 APEN Exempt/Insignificants 0.0 0.0 XA (26) Heaters 0.680 0.680 9.0 0.5 7.6 0.2 0.680 0.680 9.0 0.5 7.6 0.2 XA Fugitive Emissions 0.2 0.0 0.2 0.0 0.0 0.0 FACILITY TOTAL 1.5 1.5 0.0 0.0 284.2 1,423.4 0.2 300.0 37.2 1.5 1.5 0.0 0.0 25.8 45.6 0.2 45.8 3.5 VOC: Syn Minor (NANSR and OP) NOx: Syn Minor (NANSR and OP) CO: Syn Minor (PSD and OP) HAPS: Syn Minor n -Hexane & Total HH: Syn Minor + affected Area ZZZZ: Syn Minor Permitted Facility Total 0.8 0.8 0.0 0.0 275.2 1,422.9 0.0 292.4 37.0 0.8 0.8 0.0 0.0 16.8 45.1 0.0 38.2 3.3 Excludes units exempt from permits/APEN5 (A) Change in Permitted Emissions . _ 0.8 0.8 0.0 0.0 16.8 45.1 0.0 38.2 Pubcom & modeling (not) required based on change in emissions) (n, Note 1 Total VOC Facility Emissions (point and fugitive) (A) Change in Total Permitted VOC emissions (point and fugitive) 45.8 Facility is eligible for GP02 because < 90 tpy at time of GP02 submittal (July 2019). Project emissions greater than 25 tpy in NM 45.1 Note 2 Page 5 of 7 Printed 9/28/2020 " COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY - HAPs Company Name SRC Energy, Inc. County AIRS ID 123 Plant AIRS ID A069 Facility Name Lincoln State 3-18 Pad Emissions - uncontrolled (Ibs per year POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane McOH 224 TMP H2S TOTAL(tpy) (Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 19WE0724 Six (6) 400 bbl Condensate Tanks 6246 4869 368 1568 51421 235 32.4 002 19WE0725 Hydrocarbon Liquid Loading 129 107 35 1669 7 1.0 003 GP08 Two (2) 400 bbl Produced Water Tanks 1066 624 40 132 492 0 1.2 004 GP02 Waukesha L5794 GSI, 1380 hp, 4SRB, (sn: C-17764/1) 1900 259 244 146 284 1.4 005 GP02 Doosan D21.9L, 550 hp, 4SRB, (sn: EZYOF803080) 737 100 95 57 110 0.5 006 GP02 Doosan D21.9L, 550 hp, 4SRB, (sn: EZYOF702179) 737 100 95 57 110 0.5 0.0 0.0 0.0 0.0 0.0 0.0 APEN Exempt/Insignificants 0.0 XA (26) Heaters 14 0 1 324 0.2 XA Fugitive Emissions 2 5 1 6 14 0.0 0.0 TOTAL (tpy) 1.7 0.2 0.2 3.9 2.8 0.2 0.9 27.0 0.3 0.1 0.0 0.0 37.2 `Total Reportable = all HAPs where uncontrolled emissions > de minimus values Red Text uncontrolled emissions < de minimus 6 19WE0724.CP1 E0724. CP 1 9/28/2020 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY - HAPs Company Name SRC Energy, Inc. County AIRS ID 123 Plant AIRS ID A069 Facility Name Lincoln State 3-18 Pad Emissions with controls (Ibs per year POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane McOH 224 TMP H2S TOTAL (tpy) 'Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 19WE0724 Six (6) 400 bbl Condensate Tanks 125 97 7 31 1028 5 0.6 002 19WE0725 Hydrocarbon Liquid Loading 6 5 0 2 84 0 0.0 003 GP08 Two (2) 400 bbl Produced Water Tanks 53 31 2 7 25 0 0.1 004 GP02 Waukesha L5794 GSI, 1380 hp, 4SRB, (sn: C-17764/1) 1900 259 244 146 284 1.4 005 GP02 Doosan D21.9L, 550 hp, 4SRB, (sn: EZYOF803080) 737 100 95 57 110 0.5 006 GP02 Doosan D21.9L, 550 hp, 4SRB, (sn: EZYOF702179) 737 100 95 57 110 0.5 0.0 0.0 0.0 0.0 0.0 0.0 APEN Exempt/Insignificants 0.0 XA (26) Heaters 14 0 1 324 0.2 XA Fugitive Emissions 2 5 1 6 14 0.0 0.0 TOTAL (tpy) 1.7 0.2 0.2 0.2 0.1 0.0 0.0 0.7 0.3 0.0 0.0 0.0 3.5 7 19WE0724.CP1 9/28/2020 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado CONSTRUCTION PERMIT Permit number: 19WE0725 Issuance: Date issued: Issued to: PDC Energy, Inc. Facility Name: Plant AIRS ID: Physical Location: County: Description: Lincoln State 3-18 Pad 123/A069 NENW SEC 18 T6N R66W Weld County Well Production Facility Equipment or activity subject to this permit: 1 Equipment ID AIRS Point Equipment Description Emissions Control Description LOAD -1 002 Truck loadout of condensate by submerged fill Enclosed Flare This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit must be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self - certify compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air-permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 2. This permit must expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the Page 1 of 11 AID COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 3. The operator must retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit atone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 4. Emissions of air pollutants must not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4) Annual Limits: Equipment ID AIRS Point Tons per Year Emission T e yP pM2.5 NOX VOC CO LOAD -1 002 --- --- 2.2 --- Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant must not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants must not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants must apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, must be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder must calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 5. The owner or operator must use the emission factors found in "Notes to Permit Holder" to calculate emissions and show compliance with the limits. The owner or operator must submit an Air Pollutant Emission Notice (APEN) and receive a modified permit prior to the use of any other method of calculating emissions. 6. The 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.) Page 2 of 11 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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 VOC. 7. The emission points in the table below must be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Equipment ID AIRS Point Control Device Pollutants Controlled LOAD -1 002 Enclosed Flare VOC and HAP PROCESS LIMITATIONS AND RECORDS 8. This source must be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate must be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, Section II.A.4) Process/Consumption Limits Equipment ID AIRS Point Process Parameter Annual Limit LOAD -1 002 Condensate Loaded 172,057 barrels The owner or operator must calculate monthly process rates based on the calendar month. Compliance with the annual throughput limits must be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder must calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 9. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Regulation Number 1, Section II.A.1. a 4.) 10. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) Page 3 of 11 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 11. Hydrocarbon liquids loadout from storage tanks to transport vehicles must be controlled by using (a) submerge fill and (b) a vapor collection and return system and/or air pollution control equipment. Compliance with Section II.C.5. must be achieved in accordance with the following schedule: (Regulation Number 7, Part D, Section II.C.5.a.) • Facilities constructed or modified on or after May 1, 2020, must be in compliance by commencement of operation. • Facilities constructed before May 1, 2020, must be in compliance by May 1, 2021. • Facilities not subject to Sections II.C.5.a.(i)(A) or II.C.5.a.(i)(B) that exceed the hydrocarbon liquids loadout to transport vehicles throughput of greater than or equal to 5,000 barrels per year on a rolling 12 -month basis must control emissions from loadout upon exceeding the loadout threshold. 12. Storage tanks must operate without venting at all times during loadout. (Regulation Number 7, Part D, Section II.C.5.a.(ii)) 13. The owner or operator must, as applicable (Regulation Number, 7, Part D, Section II.C.5.a.(iii)): • Install and operate the vapor collection and return equipment to collect vapors during the loadout of hydrocarbon liquids to tank compartments of outbound transport vehicles and to route the vapors to the storage tank or air pollution control equipment. • Include devices to prevent the release of vapor from vapor recovery hoses not in use. • Use operating procedures to ensure that hydrocarbon liquids cannot be transferred to transport vehicles unless the vapor collection and return system is in use. • Operate all recovery and disposal equipment at a back -pressure less than the pressure relief valve setting of transport vehicles. • The owner or operator must inspect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or vapor loss during loadout. These inspections must occur at least monthly, unless loadout occurs less frequently, then as often as loadout is occurring. 14. The owner or operator must perform the following observations and training (Regulation Number 7, Part D, Section II.C.5.a.(iv)): • The owner or operator must observe loadout to confirm that all storage tanks operate without venting when loadout operations are active. These inspections must occur at least monthly, unless loadout occurs less frequently, then as often as loadout is occurring, • If observation of loadout is not feasible, the owner or operator must document the annual loadout frequency and the reason why observation is not feasible and inspect the facility within 24 hours after loadout to confirm that all storage tank thief hatches (or other access point to the tank) are closed and latched. Page 4 of 11 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado • The owner or operator must install signage at or near the loadout control system that indicates which loadout control method(s) is used and the appropriate and necessary operating procedures for that system. • The owner or operator must develop and implement an annual training program for employees and/or third parties conducting loadout activities subject to Section II.C.5. that includes, at a minimum, operating procedures for each type of loadout control system. 15. The owner or operator must retain the records required by Regulation Number 7, Part D, Section II.C.5.a.(v) for at least two (2) years and make such records available to the Division upon request. • Records of the annual facility hydrocarbon liquids loadout to transport vehicles throughput. Inspections, including a description of any problems found and their resolution, required under Sections II.C.5.a.(iii) and II.C.5.a.(iv) must be documented in a log. Records of the infeasibility of observation of loadout. Records of the frequency of loadout. Records of the annual training program, including the date and names of persons trained. 16. Air pollution control equipment used to comply with this Section II.C.5.must comply with Section II.B., be inspected in accordance with Sections II.C.1.d.(ii) through (v), and achieve a hydrocarbon control efficiency of 95%. (Regulation Number 7, Part D, Section II.C.5.a.(vi)) (vi)) 17. On or before June 30th, 2021 (and on June 30th each year thereafter), the owner or operator of oil and natural gas operations and equipment at or upstream of a natural gas processing plant in Colorado must submit a single annual report that includes actual emissions and specified information in the Division -approved report format. The information included in the annual report must be in accordance with the general reporting requirements of Regulation Number 7, Part D, Section V.B. Beginning July 1, 2020, and each calendar year thereafter, owners or operators must maintain the information according to Regulation Number 7, Part D, Section V.C. for inclusion in the annual report. (Regulation Number 7, Part D, Section V) OPERATING a MAINTENANCE REQUIREMENTS 18. Upon startup of these points, the owner or operator must follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements Page 5 of 11 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 19. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements 20. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 21. A revised Air Pollutant Emission Notice (APEN) must be filed: (Regulation Number 3, Part A, Section II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOx) in ozone nonattainment areas emitting less than 100 tons of VOC orNO,t per' year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or for sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted. For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 22. The requirements of Colorado Regulation Number 3, Part D shall apply at such time that any stationary source or modification becomes a major stationary source or major modification solely by virtue of a relaxation in any enforceable limitation that was established after August 7, 1980, on the capacity of the source or modification to otherwise emit a pollutant such as a restriction on hours of operation (Reference: Regulation Number 3, Part D, V.A.7.B). Page 6 of 11 COLORADO Air Pollution Control Division Department of Public Health & "Environment Dedicated to protecting and improving the health and environment of the people of Colorado GENERAL TERMS AND CONDITIONS 23. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 24. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 25. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 26. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 27. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof must constitute a rejection of the entire permit and upon such occurrence, this permit must be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 28. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. Page 7 of 11 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado 29. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: DRAFT Ben Fischbach Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to PDC Energy, Inc. New Synthetic Minor Facility Page 8 of 11 COLORADO Air Pollution Control Division Department at Public Health fl Environment Dedicated to protecting and improving the health and environment of the people of Colorado Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder must pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator must notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (ib/yr) Controlled Emissions (lb/yr) 002 Benzene 71432 129 6 Toluene 108883 107 5 Ethylbenzene 100414 9 0 Xylenes 1330207 35 2 n -Hexane 110543 1,670 83 224 TMP 540841 7 0 Note: All non -criteria reportable pollutants in the table above with uncontrolled emiss'on rates above 250 pounds per year ( b/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. Page 9 of 11 COLORADO Air Pollution Control Division f Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 5) The emission levels contained in this permit are based on the following emission factors: Pollutant CAS # Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 5.89 * 10-4 5.89 * 10-4 AP -42: Ch. 13.5 CO 2.68 * 10-3 2.68 * 10-3 VOC 5.06 * 10-1 2.53 * 10"2 ProMax/AP- 42 Ch. 5.2, Equation 1 Benzene 71432 7.49 * 10-4 3.74* 10-5 Toluene 108883 6.22 * 10"4 3.11 * 10"5 Ethylbenzene 100414 5.06 * 10"5 2.53 * 10-6 Xylene 1330207 2.04 * 10"4 1.02 * 10-5 n -Hexane 110543 9.70 * 10-3 4.85 * 10-4 224 TMP 540841 4.09 * 10"5 2.04 * 10"6 The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46*S*P*M/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 18.6 psia M (vapor molecular weight) = 45.57 lb/lb-mol T (temperature of liquid loaded) = 526 °R The uncontrolled non -criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the VOC emission factor by the ratio of the mass fraction of each NCRP in the vapors to the mass fraction of VOC in the vapors. Controlled emission factors are based on a flare efficiency of 95% and a collection efficiency of 100%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN must be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each Page 10 of 11 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, CO, NOx, n -Hexane, Total HAP PSD Synthetic Minor Source of: VOC, CO, NOx NANSR Synthetic Minor Source of: VOC, NOx 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://www.ecfr.Rovi Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A Subpart UUUU NSPS Part 60, Appendixes Appendix A - Appendix Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX Page 11 of 11 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Ben Fischbach Package ti: 414101 Received Date: 7/2/2019 Review Start Date: 3/12/2019 Section 01 - Facility Information Company Name: PDC Energy, Inc. County AIRS ID: 123 Plant AIRS ID: 4069 Facility Name:Lincoln State 3-18 Pad 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? Yes If yes, for what pollutant? O carbon Mcnoode (Co) ❑ Parbcmate Matter (PM) EI Ozone (NOx & VOC) Weld County Quadrant Section Township Range NENW 18 6N 66 Section 02 - Emissions Units In Permit Application AIRs Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks 002 Liquid Loading LOAD -1 Yes 19WE0725 1 Yes Permit Initial Issuance Section 03 - Description of Project Applicant proposes the construction of one condensate tank battery (covered by permit 19WE0724), three engines (covered by GP02), one produced water tank battery (covered by GP08) and this liquid loadout:point,: all located at a new E&P well pad site..: Original application (received 7/2/19) was submitted on behalf of SRC Energy, Inc. During the processing of this project, ownership of this facility was transferred to PDC Energy, Inc. Permit will be issued to PDC Energy, Inc. Section 04 - Public Comment Requirements Is Public Comment Required? If yes, why? Requesting Synthetic Minor Permit 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. Yes Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) SO2 Is this stationary source a major source? If yes, explain what programs and which pollutants hen SO2 Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) No Yes NOx CO VOC No NOx CO J J VOC PM2.5 PM2.5 PM10 TSP HAPs ❑ ❑J PM10 TSP HAPs ❑ ❑ , Hydrocarbon Loadout Emissions Inventory 002 Liquid Loading Facility AIRS ID: 123 County A069 Plant PRSiag Section 02 - Equipment Description Details Detailed Emissions Unit Contingency loading of condensate from storage tanks. Description: Emission Control Device ECD (teed 48") Description: Is this loadout controlled? Collection Efficiency: Control Efficiency: Requested Overall VOC & HAP Control Efficiency %: Yes 100.0 95 Section 03- Processing Rate Information for Emissions Estimates Primary Emissions - Hydrocarbon Loadout Actual Volume Loaded = Requested Permit Limit Throughput = Potential to Emit (PTE) Volume Loaded = 95.00 143,378 Barrels (bbl) per year 172,057. Barrels (bbl) per year 172,057 Barrels (bbl) per year Actual Volume Loaded While Emissions Controls Operating= Requested Monthly Throughput= 14=13 Barrels (bbl) per month 143,378' Barrels (bbl) per year Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per year = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = 2577.2 Btu/scf -. _... , scf/year Potential to Emit (PTE) heat content of waste gas routed to combustion device = Secondary Emissions - Combustion Device(s) Pilot Fuel Annual volume (PTE) of Pilot Fuel to Combustion Devices = Annual Heat Content of Pilot Fuel to Combustion Devices (PTE) _ Section 04 - Emissions Factors & Methodologies Does the company use the state default emissions factors to estimate emissions? N Are the emissions factors based on a stabilized hydrocarbon liquid sample drawn at the facility being permitted? Loading Loss Equation L = 12.46.5'P'M/T 3:12 MMBTU per year 375 MMBTU per year _70 MMBTU per year 020 MMscf/yr 5)0 MMBTU per year Yes Factor Meaning Value Units Source S Saturation Factor ._ ,s %,'E�.p� ; lam AP -42 Chapter 5.2 Fable 5.2-1 Submerged Loading: Dedicated Normal Service (1=6) '. P True Vapor Pressure 18.6 psia ProMax Stream Analysis M Molecular Weight of Vapors 45.57 Ib/Ib-mol Promax T Liquid Temperature 526 Rankine Promax L Loading Losses _.:54090199 lb/1000 gallons :`.505970002 lb/bbl Component Mass Fraction Emission Factor Units Source Benzene 1.48E-03 `,-00741. _ lb/bbl Promax W&B Stream - Ratio of HAP/VOC in WAR Gas Stream Toluene 1.23E-03 )000 - lb/bbl Promax WAR Stream - Ratio of HAP/VOC in W&B Gas Stream Ethylbenzene 1.00E-04 Ib/bbl. Promax W&B Stream - Ratio of HAP/VOC in WAR Gas Stream.. Xylene 4.04E-04 lb/bbl Promax WAR Stream - Ratio of HAP/VOC in W&B GasStream n -Hexane 1.92E-02 .. lb/bbl PromaxWAR Stream - Ratio of HAP/VOC in W&B Gas5tream. 224TMP 8.08E-05 .... lb/bbl Promax WAR Stream - Ratio of HAP/VOC in W&B Gas Stream Emission Factors Hydrocarbon Loadout Pollutant Uncontrolled Controlled (Ib/bb0 (Ib/bbl) (Volume Loaded) (Volume Loaded) 2.53E-03 _ 3.11E-00 2.530.06 1.92E -OS 4.85E-04 0.040.06 Emission Factor Source VOC 0.06E-01. Benzene Toluene Ethylbenzene Xylene n -Hexane - 224 TMP ;AP -42: Chapter 5.2, AP -42: ChapterS _ SP -42: Chapter 5:_ AP -42: Chapter 40-42: Chapter P.4Zi Chapter 5 P-42: Chapter5.2 Pollutant Control Device Uncontrolled Uncontrolled (Ib/MMBtu) (Ib/bbl) (Volume Loaded) (waste heat combusted) Emission Factor Source PM10 PM2.5 SOx NOx CO 0.0680 0.3100 2 of 7 K:\PA\2019\19 W E0725. C P1 Hydroc rbon Loadout Emissions Inventory Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Atrial Emissions Uncontrolled Controlled (tons/year), (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) hone/yearl Requested Monthly Limits Controlled (lbs/month) PM10 PM2.5 5Ox NOx VOC CO 0.00 999 ,.9G 0.00 -^: -0 0.9C ., 0.01E C 9 0,03 .-.i ._.:.'3 .... _._5 .. 43.53 .4.,._., 2.59 ., . -, -. _7 .__ ,-'1 ___ ,. Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 125 107 __ —30 i .... ... ;.. le; ry Section 06 - Regulatory Summary Analysts Regulation 3, Parts A, B ombustion Emission Factors Including Pilot Fuel EF (lb/bbl) NOx 5.89E-04 0 2.68E-03 RACT - Regulation 3, Part B, Section III.D.2.a ACT. Regulation 7, Part D, Section II.C5 (See regulatory applicability worksheet for detailed analysi ) Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company request acortrol device efficiency greater than 95% fora flare or combustion device? '•,ti�IJ , If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes Operator chose parameters of P, M, and T from Promax model outputs and stream analysis. Promax estimates that the condensate outlet/loadout liquid stream has an RVP of 11.5, and a7VP of 18.6 psia (PIP =10.6 psia used for value "P" in loading calculation). The calculation methodology described and used above results in seemingly conservative emission factors (site specific VOC EF much larger than state default for loadout), likely due to Promax outputs. I have discussed this with the operator, and they are confident in the values attained. As JR calculations are conservative, will accept and use in permitting. Annual emissions calculations differ slightly between PA and APEN due torounding differences. As all differences are negligible, will accept APEN listed values and permit based on those. Actual and Requested Heat Content of Waste Gas Routed to Combustors (Cells E25 & E20) are based on the Promax output for standard vapor volumetric flow of the loading losses stream.: While this method results in different calculated annual emissions for NOx and CO, differences are negligible, with both methods yielding annual emissions <itpy for each combustion product. Will therefore accept Promo', methodology and use in permitting. NOx and CO requested emissions include emissions from pilot fuel usage. Per operator calculations sheet: "Vapors from truck loading are only generated and sent to the dedicated combustor during LACT unit downtime, which is estimated to be 10% annually." This assumption is the basis for the difference in permitted throughput limits between this loadout point and the condensate tank point. Per facility description, loadout emissions are routed to an individual combustion device, separate from the bank of ECDs used to control the condensate and produced water points at this facility. Therefore, this point is Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 002 Process # 01 SCC Code Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.90 0 lb/1,000 gallons transferred PM2.5 0,D0 0 lb/1,000 gallons transferred SOx :..., 0 lb/1,000 gallons transferred NOx 0.00 0 lb/1,000 gallons transferred VOC 12.0 95 lb/1,000 gallons transferred CO 6.06 0 lb/1,000gallons transferred Benzene 0.02 95 lb/1,000 gallons transferred Toluene 0.01 95 ' lb/1,000 gallons transferred Ethylbenzene 1 00 95 113/1,088 gallons transferred Xylene . -C_ OR lb/1,000 gallons transferred n -Hexane 0.06 95 lb/1,000 gallons transferred 224 TMP 5.03 95 lb/1,000 gallons transferred 3 of 7 K:\PA\2019\19 W E0725.CP1 Hydrocarbon Loadout Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Rguirements_ halrce Is In the Non -Ant e „ as ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section l 1.0.1.a)? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.1)? 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled VOCemissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part 8, Section 11.0.3)? XtraArbb IYc t SCUM.s.n the hot-Attaor e'. Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than l TPY (Regulation 3, Part A, Section 11.0.1.8)? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section 11.0.1.1)? 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? 5. I Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled V0C emissions from the greater than 2 TPY, NOx greater than 5 TPY or C0 emissions greater than 10 TPY (Regulation 3, Part 8, Section 11.0.2)? 'Source requires a permit 7. RACr- Are uncontrolled VOCemissions from the loadout operation greater than 20 tpy (Regulation 3, Part B, Section 111.0.2. a)? 'The loadout must operate withvua z t .rosin „_- ,.... 1 to ,ore satisfy_.. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations. and Air Ovally Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply toe 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 documentend the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," "may,""should,"and "can,"is intended to describe APCD interpretations and recommendations. Mandatory terminology such as 'must" and 'required"are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations. but this document does not establish legally binding requirements in and of itself. No'sk`rYyfY Go to next Go to then Go to next Go to next Go to next The loadou Yes.. The loadou COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION FACILITY EMISSION SUMMARY Company Name County AIRS ID Plant AIRS ID Facility Name SRC Energy, Inc. 123 A069 Lincoln State 3-18 Pad History File Edit Date 9/28/2020 Ozone Status Non -Attainment EMISSIONS - Uncontrol ed (tons per year) EMISSIONS With Controls (tons per year) POINT AIRS ID PERMIT Description PM10 PM2.5 H2S SO2 NOx VOC Fug VOC CO Total HAPs PM10 PM2.5 H2S SO2 NOx VOC Fug VOC CO Total HAPs REMARKS Previous FACILITY TOTAL 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 New Facility - No Previous Total Previous Permitted Facility total 0.0 0.0 0.0 0.0 0,0 0,0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 001 19WE0724 Six (6) 400 bbl Condensate Tanks 2.4 1,345.2 11.1 32.4 2.4 26.9 11.1 0.6 002 19WE0725 - Hydrocarbon Liquid Loading 0.1 43.5 0.2 1.0 0.1 2.2 0.2 0.0 003 GP08 Two (2) 400 bbl Produced Water Tanks 0.2 20.8 1.0 1.2 0.2 5.9 1.0 0.1 004 GP02 Waukesha L5794 GSI, 1380 hp, 4SRB, (sn: C-1776411) 0.4 0.4 193.1 6.0 146.5 1.4 0.4 0.4 6.7 2.7 10.0 1,4 005 GP02 Doosan D21.9L, 550 hp, 4SRB, (sn: EZYOF803080) 0.2 0.2 39.7 3.7 66.9 0.5 0.2 0.2 3.7 3.7 8.0 0.5 006 GP02 Doosan D21.9L, 550 hp, 4SRB, (sn: EZYO F702179) 0.2 0.2 39.7 3.7 66.9 0.5 0.2 0.2 3.7 3.7 8.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 APEN Exempt/Insignificants 0.0 0.0 XA (26) Heaters 0.680 0.680 9.0 0.5 7.6 0.2 0.680 0.680 9.0 0.5 7.6 0,2 XA Fugitive Emissions 0.2 0.0 0.2 0.0 0.0 - 0.0 FACILITY TOTAL 1.5 1.5 0.0 0.0 284.2 1,423.4 0.2 300.0 37.2 1.5 1.5 0.0 0.0 25.8 45.6 0.2 45.8 3.5 VOC: Syn Minor (NANSR and OP) NOx: Syn Minor (NANSR and OP) CO: Syn Minor (PSD and OP) HAPS: Syn Minor n -Hexane & Total HH: Syn Minor + affected Area 7777: Syn Minor Permitted Facility Total 0.8 0,8 0,0 0.0 275.2 1,422.9 0.0 292.4 37.0 0.8 0.8 0.0 0.0 16.8 45.1 0.0 38.2 3.3 Excludes units exempt from permits/APENs (4) Change in Permitted Emissions 0.8 0.8 0.0 0.0 16.8 45.1 0.0 38.2 Pubcom & modeling (not) required based on (A change in emissions) Note 1 Total VOC Facility Emissions (point and fugitive) (A) Change in Total Permitted VOC emissions (point and fugitive) 45.8 Facility is eligible for GP02 because < 90 tpy at time of GP02 submittal (July 2019). Project emissions greater than 25 tpy in NAA 45.1 Note 2 Page 5 of 7 Printed 9/28/2020 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY - HAPs Company Name SRC Energy, Inc. County AIRS ID 123 Plant AIRS ID A069 Facility Name Lincoln State 3-18 Pad Emissions - uncontrolled (Ibs per year POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane McOH 224 TMP H2S TOTAL (tpy) (Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 19WE0724 Six (6) 400 bbl Condensate Tanks 6246 4869 368 1568 51421 235 32.4 002 19WE0725 Hydrocarbon Liquid Loading 129 107 9 35 1669 7 1.0 003 GP08 Two (2) 400 bbl Produced Water Tanks 1066 624 40 132 492 0 1.2 004 GP02 Waukesha L5794 GSI, 1380 hp, 4SRB, (sn: C-17764/1) 1900 259 244 146 284 1.4 005 GP02 Doosan D21.9L, 550 hp, 4SRB, (sn: EZYOF8030B0) 737 100 95 57 110 0.5 006 GP02 Doosan D21.9L, 550 hp, 4SRB, (sn: EZYOF702179) 737 100 95 5r" 110 0.5 0.0 0.0 0.0 0.0 0.0 0.0 APEN Exempt/Insignificants 0.0 XA (26) Heaters 14 t) 1 324 0.2 XA Fugitive Emissions 2 S 1 6 14 0.0 0.0 TOTAL (tpy) 1.7 0.2 0.2 3.9 2.8 0.2 0.9 27.0 0.3 0.1 0.0 0.0 37.2 'Total Reportable = all HAPs where uncontrolled emissions > de minimus values Red Text: uncontrolled emissions < de minimus 6 19WE0725.CP1 9/28/2020 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY - HAPs Company Name SRC Energy, Inc. County AIRS ID 123 Plant AIRS ID A069 Facility Name Lincoln State 3-18 Pad Emissions with controls (Ibs per year POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane McOH 224 TMP H2S TOTAL (tpy) !Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 19WE0724 Six (6) 400 bbl Condensate Tanks 125 97 7 31 1028 5 0.6 002 19WE0725 Hydrocarbon Liquid Loading 6 5 0 2 84 0 0.0 003 GP08 Two (2) 400 bbl Produced Water Tanks 53 31 2 7 25 0 0.1 004 GP02 Waukesha L5794 GSI, 1380 hp, 4SRB, (sn: C-17764/1) 1900 259 244 146 284 1.4 005 GP02 Doosan D21.9L, 550 hp, 4SRB, (sn: EZYOF803080) 737 100 95 57 110 0.5 006 GP02 Doosan D21.9L, 550 hp, 4SRB, (sn: EZYOF702179) 737 100 95 57 110 0.5 0.0 0.0 0.0 0.0 0.0 0.0 APEN Exempt/lnsignificants 0.0 XA (26) Heaters 14 0 1 324 0.2 XA Fugitive Emissions 2 5 1 6 14 0.0 0.0 TOTAL (tpy) 1.7 0.2 0.2 0.2 0.1 0.0 0.0 0.7 0.3 0.0 0.0 0.0 3.5 7 19WE0725.CP1 9/28/2020 Condensate Storage Tank(s) APEN Form APCD-205 JUL - 2 21}19 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/pacific/cdphe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: / vie -0 MRS ID Number: 123 ii400 / 6 O( [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: SRC Energy, Inc. Lincoln State 3-18 Pad Site Location NENW Sec. 18 T6N R66W County: Weld Mailing Address: (Include Zip Code) 5400 W. 11th Street, Suite C Greeley, CO 80634 NAICS or SIC Code: 211111 Contact Person: Phone Number: E -Mail Address2: Brad Rogers (970) 475-5242 brogers@srcenergy.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. 19-6 `I'll Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 COLORADO 1 I Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source ❑r Request coverage under traditional construction permit O Request coverage under a General Permit O GP01 O GP08 If General Permit coverage is requested, the General Permit registration fee of $312.50 must be submitted along with the APEN filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment O Change company name3 ❑ Change permit limit O Transfer of ownership' O Other (describe below) OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ID APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info it Notes: 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: Company equipment Identification No. (optional): For existing sources, operation began on: Storage of condensate from production wells TNK 1-6 For new or reconstructed sources, the projected start-up date is: 04/04/2019 Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Storage tank(s) located at: Exploration & Production (E&P) site O Midstream or Downstream (non E&P) site Will this equipment be operated in any NAAQS nonattainment area? O 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 GI ■ If "yes", identify the stock tank gas -to -oil ratio: 0.00285 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 ■ Are you requesting a 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions a 6 ton/yr (per storage tank)? Yes No ri ■ Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 2 IA® COLORADO Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 4 - Storage Tank(s) Information ICondensate Throughput: Actual Annual Amount (bbl/year) 1,433,783 From what year is the actual annual amount? 2019 Average API gravity of sales oil: 42.7 degrees Requested Annual Permit Limits (bbl/year) Tank design: 0 Fixed roof 0 Internal floating roof 1,720,574 RVP of sales oil: 7.4 0 External floating roof Storage Tank ID of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbt) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) TNK 1-6 6 2,400 03/2019 4/2019 Wells Serviced by this Storage Tank or Tank Batten/6 (MP Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 46732 Lincoln 4N -13C -M O 05 - 123 - 46733 Lincoln 4N -13B -M 0 05 - 123 - 46734 Lincoln 30C -13-M ISI 05 - 123 - 46735 Lincoln 4C -13-M 0 05 - 123 - 46736 Lincoln 30N -13B -M 12 5 Requested values wilt become permit limitations. Requested limit(s) should consider future growth. 6 The E&P Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitde/Lazgitude or UTM) 40.49143/-104.82356 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) Indicate the direction of the stack outlet: (check one) ❑ Upward O Downward ❑ Horizontal O Other (describe): O 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-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 COLORADO 3 I A IMYIN 6 [a+ananmw.. Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and MRS ID] Section 6 - Control Device Information 0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor ❑ Recovery Unit (VRU): Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: ❑ Combustion Device: Pollutants Controlled: VOCs and HAPs Rating: 278.66 TN/Pe: ECD Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: MMBtu/hr Make/Model: (4) I ES 96" 98 98 Minimum Temperature: 1,076°F Waste Gas Heat Content: 2,572 Btu/scf Constant Pilot Light: El Yes 0 No Pilot Burner Rating: 0.059 MMBtu/hr O 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)? 15.6 Describe the separation process between the well and the storage tanks: (24) 36" Worthington 3 -phase separators each rated at 0.5 MMBtu/hr, psig (6) non -fired 2 -phase vertical separators, and (2) 60" Worthington gas busters rated at 1.25 MMBtu/hr each. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 COLORADO . Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant Description of Control Methods) Overall Requested Control Efficiency (% reduction in emissions) VOC Enclosed Combustor 98% NOx CO HAPs Enclosed Combustor 98% Other: From what year is the following reported actual annual emissions data? 2019 Criteria Pollutant Emissions Inventory Pollutant Emission Factor? Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Units (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions8 (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tars/year) VOC 1.564 lbs/bbl ProMax 1,120.94 22.42 1,345.16 26.90 NOx 0.068 Ib/MMBtu AP -42 N/A 2.01 N/A 2.43 CO 0.31 Ib/MMBtu AP -42 N/A 9.16 N/A 11.07 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract service ( ) Number Emission. Factor? Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions8 (Pounds/ year) Benzene 71432 3.63E-03 lbs/bbl ProMax 5,204.63 104.09 Toluene 108883 2.83E-03 lbs/bbl ProMax 4,057.60 81.15 Ethylbenzene 100414 2.14E-04 lbs/bbl ProMax 306.83 6.14 Xylene 1330207 9.11E-04 lbs/bbl ProMax 1,306.18 26.12 n -Hexane 110543 2.99E-02 lbs/bbl ProMax 42,849.48 856.99 2'2,4- Trimethylpentane 540841 1.37E-04 lbs/bbl ProMax 196.43 3.93 5 Requested values will become permit limitations. Requested limit(s) should consider future growth. 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 emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-205 Condensate Storage Tank(s) APEN - Revision 7/2018 COLORADO 5 I AV .ems f6�sX# b b Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID) Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit 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. 6 - Zn -Zo /9 Signature of Legally Authorized Person (not a vendor or consultant) Brad Rogers Name (print) Date Health and Environmental Manager Title Check the appropriate box to request a copy of the: Draft permit prior to issuance O Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $312.50, 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 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-205 Condensate Storage Tank(s) APEN - Revision 7/2018 WV COLORADO 6 ,d= E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Form' Company Name: SRC Energy, Inc. Source Name: Lincoln State 3-18 Pad - Condensate Tanks Emissions Source AIRS ID2: / / Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 46737 Lincoln 5N -13C -M ►4 05 -123 - 46738 Lincoln 31C -13-M /1 05 - 123 - 46739 Lincoln 31N -13C -M .1 05 - 123 - 46740 Lincoln 31N -13B -M // 05 - 123 - 46741 Lincoln 5N -13A -M /1 05 - 123 - 46742 Lincoln 32N -13A -M .1 05 - 123 - 46748 Lincoln State 59 -08N -17B -M 4 05 - 123 - 46749 Lincoln State 59 -12N -17B -M 11 05 -123 - 46750 Lincoln State 59 -06N -17A -M /1 05 - 123 - 46751 Lincoln State 59 -0941N -17C -M .1 05 - 123 - 46752 Lincoln State 59 -07C -17-M .1 05 - 123 - 46753 Lincoln 32N -13B -M ►1 05 - 123 - 46754 Lincoln State 59-I IC -17-M ./ 05 - 123 - 46755 Lincoln State 59 -04N -17B -M /I 05 - 123 - 46756 Lincoln State 59 -10N -17A -M ►1 05 -123 - 46757 Lincoln State 59 -03C -17-M .1 05 -123 - 46758 Lincoln State 59 -05N -17C -M ./ 05 - 123 - 46759 Lincoln State 59 -14N -17A -M /1 05 - 123 - 46760 Lincoln State 59 -13N -17C -M ►1 - - ❑ Footnotes: ' 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 APCD-212-COND Tank-Addendum.docx Hydrocarbon Liquid Loading APEN Form APCD-208 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: JUL-220' ( 1 AIRS ID Number: 1 13 /A a 6, gi ©6),i, [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': SRC Energy, Inc. Site Name: Lincoln State 3-18 Pad Site Location: NENW Sec. 18 T6N R66W Mailing Address: (Include Zip Code) 5400 W. 11th Street, Suite C Greeley, CO 80634 Site Location County: Weld NAICS or SIC Code: 211111 Contact Person: Phone Number: E -Mail Address2: Brad Rogers (970) 475-5242 brogers@srcenergy.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that wilt appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-208 Hydrocarbon Liquid Loading APEN - Revision 7/2018 COLORADO o.,.�..* Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source 0 Request coverage under construction permit O Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $312.5O must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name3 ❑ Change permit limit O Transfer of ownership4 O Other (describe below) - OR • APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info & Notes: Truck loading emissions controlled by ECD with DRE of 95%. Truck loading emissions are only expected to occur during LACT unit downtime. 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: Contingency loading of condensate from storage tanks. Company equipment Identification No. (optional): LOAD -1 For existing sources, operation began on: N/A For new or reconstructed sources, the projected start-up date is: 04/04/2019 Will this equipment be operated in any NAAQS nonattainment area? Yes No p ■ Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Yes No • J Does this source load gasoline into transport vehicles? Yes No ■ 15 Is this source located at an oil and gas exploration and production site? 0 Yes O No If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Yes No a p Does this source splash fill less than 6750 bbl of condensate per year? O Yes 0 No Does this source submerge fill less than 16308 bbl of condensate per year? Yes 0 No ■ Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 � COLORADO 2 1 AV Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: 0 Condensate 0 Crude Oil 0 Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: 172,057 bbl/year Actual Volume Loaded: This product is loaded from tanks at this facility into: Tank Trucks (e.g. "rail tank cars" or "tank trucks") 143,378 bbl/year If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: 0.60 Average temperature of bulk liquid loading: 66 °F True Vapor Pressure: 1 8.60 Psia @60 °F Molecular weight of displaced vapors: 45.57 lb/lb mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: bbl /year Actual Volume Loaded: bbl/year Product Density: lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume: I ft3/truckload 5 Requested values will become permit limitations. Requested timit(s) should consider future process growth. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 AV COLORADO 3 I . �.. Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.49143/-104.82356 Level met} . F') Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): O Upward with obstructing raincap 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. O Loading occurs using a vapor balance system: Requested Control Efficiency: O Combustion Device: Used for control of: VOCs and HAPs Rating: 15.03 Type: ECD MMBtu/hr Make/Model: Leed 48" Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: 1,076 'F Waste Gas Heat Content: 2,577 Constant Pilot Light: 0 Yes 0 No Pilot Burner Rating: 0.059 Btu/scf MMBtu/hr O Other: Pollutants Controlled: Description: Requested Control Efficiency: Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 A7,--=, COLORADO 4I lld�.", Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (X reduction in emissions) PM SOx NOx CO VOC ECD 95% HAPs 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 octuo( annual emissions data? 2019 Criteria Pollutant Emissions Inventory 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 Emissions6 (tans/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tarns/year) PM N/A N/A N/A N/A N/A N/A N/A SOx N/A N/A N/A N/A N/A N/A N/A NOx 0.068 lb/MMBtu AP -42 N/A 0.03 N/A 0.05 CO 0.31 Ib/MMBtu AP -42 N/A 0.13 N/A 0.23 VOC 5.06E-01 lbs/bbl ProMax 36.26 1.81 43.51 2.18 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract service CAS (us) ) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (pormds/year) Controlled Emissions6 (potmdslyear) Benzene 71432 7.48E-04 lbs/bbl ProMax 107.18 5.36 Toluene 108883 6.21E-04 lbs/bbl ProMax 88.98 4.45 Ethylbenzene 100414 5.07E-05 lbs/bbl ProMax 7.26 0.36 Xylene 1330207 2.04E-04 lbs/bbl ProMax 29.31 1.47 n -Hexane 110543 9.70E-03 lbs/bbl ProMax 1,390.90 68.55 2'2'4- Trimethylpentane 540841 4.08E-05 lbs/bbl ProMax 5.86 0.29 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 COLORADO //��!� 5 1 iii. arakr Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit 11 and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP07. fo Z-01', Signature of Legally Authorized Person (not a vendor or consultant) Brad Rogers Date Health and Environmental Manager Name (print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance O Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $312.50, 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 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 l COLORADO 6 Av Itape.emum «. Hello