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Home My WebLink About20210057.tiffCOLORADO Department of Public Health b Environment Weld County - Clerk to the Board 1150 O St PO Box 758 Greeley, CO 80632 December 30, 2020 Dear Sir or Madam: RECEIVED JAN 0 4 2021 WELD COUNTY COMMISSIONERS On December 31, 2020, the Air Pollution Control Division will begin a 30 -day public notice period for Bonanza Creek Energy Operating LLC - Longhorn 14-11 Production Facility. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission - regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Public Notice Coordinator 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe Jared Polis, Governor Jill Hunsaker Ryan, MPH', Executive Director Pubr c Rev:eci 01/13/21 CC : PI -C17), HI.(DS/ R),RA(aM/aR/cFI/cK), OG(51M) O1 /a7/2t 2021-0057 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Bonanza Creek Energy Operating LLC - Longhorn 14-11 Production Facility - Weld County Notice Period Begins: December 31, 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: Bonanza Creek Energy Operating LLC Facility: Longhorn 14-11 Production Facility Oil and Gas well production facility SWSW Section 11 T3N R63W Weld County The proposed project or activity is as follows: Applicant proposes to modify synthetic minor facility to remain under the new non -attainment area major source limit of 50 tpy to remain a synthetic minor 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 18WE0355 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Comments may be submitted using the following options: • Use the web form at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. This page also includes guidance for public participation • Send an email to cdphe.commentsapcd@state.co.us • Send comments to our mailing address: Christopher Kester Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 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 Permit number: Date issued: Issued to: CONSTRUCTION PERMIT 18WE0355 Issuance: 2 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Bonanza Creek Energy Operating Company, LLC Longhorn 14-11 Production Facility 123/9FB0 SWSW Section 11 T3N R63W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description CNDTK-01 001 Three (3) 500 barrel fixed roof storage vessels used to store condensate. Enclosed Combustor PWT-01 002 One (1) 500 barrel fixed roof storage vessel used to store produced water. Enclosed Combustor ECD-01 003 Produced natural gas routed to enclosed combustor Enclosed Combustor L-1 004 Hydrocarbon Liquid Loading Enclosed Combustor This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, l submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.Rov/cdphetair/manage-permit. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) COLORADO Air Pollution Control Division Department of Public Health b Environment Page 1 of 13 Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self - certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air-permit-self-certification. (Regulation Number 3, Part B, Section III .G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III. F.4. ) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section I I.A.4. ) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO CNDTK-01 001 --- --- 10.1 --- Point PWT-01 002 --- --- 0.1 --- Point ECD-01 003 --- 2.0 29.2 9.1 Point L-1 004 --- --- 0.4 --- Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. COLORADO Air Pollution Control Division Department of Public Health 8 Environment Page 2 of 13 The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The owner or operator must use the emission factors found in "Notes to Permit Holder" to calculate emissions and show compliance with the limits. The owner or operator must submit an Air Pollutant Emission Notice (APEN) and receive a modified permit prior to the use of any other method of calculating emissions. 8. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled CNDTK-01 001 Enclosed Combustor (Make: Crimson Model: CE1000) VOC and HAP PWT-01 002 Enclosed Combustor (Make: Crimson Model: CE1000) VOC and HAP ECD-01 003 Enclosed Combustor (Make: Crimson Model: CE1000) VOC and HAP L-1 004 Enclosed Combustor (Make: Crimson Model: CE1000) VOC and HAP PROCESS LIMITATIONS AND RECORDS 9. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4. ) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit CNDTK-01 001 Condensate throughput 65,700 barrels PWT-01 002 Produced Water throughput 9,125 barrels ECD-01 003 Natural gas venting 37.9 MMscf L-1 004 Condensate loaded 65,700 barrels The owner or operator shall monitor monthly process rates based on the calendar month. COLORADO Air Pollution Control Division Department of Public Health & Environment Page 3 of 13 Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 10. Point 003: The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from this point using the flow meter. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. 11. The owner or operator must operate a flame detection system that monitors the combustor pilot system for the presence of a pilot light flame. If a flame is not detected, the facility will shut-in all of the wells serviced by this facility, such that the wells cannot produce to the facility. 12. At a minimum of a weekly basis, the owner or operator must monitor the control device for the presence of a pilot light and an operational auto -igniter. 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. STATE AND FEDERAL REGULATORY REQUIREMENTS 13. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/9FB9/xxx) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 14. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 15. Point 001 and 002: This source is subject to Regulation Number 7, Part D, Section I. The operator must comply with all applicable requirements of Section I and, specifically, must: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for storage tanks; and • Ensure that the combustion device controlling emissions from this storage tank be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. (Regulation Number 7, Part D, Section I.C.) (State only enforceable) 16. Points 001, 002, 003, and 004: The combustion device covered by this permit is subject to Regulation Number 7, Part D, Section II.B.2. General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section II, it must be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, Part D, Section II.A.23; and be designed so that an observer can, by means of visual COLORADO Air PoAution Control Division Department of Public HealtFrb Environment Page 4 of 13 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. 17. Point 001 and 002: The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Part D, Section II.C.1. The owner or operator must install and operate air pollution control equipment that achieves an. average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons except where the combustion device has been authorized by permit prior to March 1, 2020. The source must follow the inspection requirements of Regulation Number 7, Part D, Section II.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. 18. Point 001 and 002: The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Part D, Section II.C.2. 19. Point 004: 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. 20. Point 004: Storage tanks must operate without venting at all times during loadout. (Regulation Number 7, Part D, Section II.C.5.a.(ii)) 21. Point 004: 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. COLORADO Air Pollution Control Division Department of Public Health b Environment Page 5 of 13 • 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. 22. Point 004: The owner or operator must perform the following observations and training (Regulation Number 7, Part D, Section II.C.5.a.(iv)): • The owner or operator must observe loadout to confirm that all storage tanks operate without venting when loadout operations are active. These inspections must occur at least monthly, unless loadout occurs less frequently, then as often as loadout is occurring, • If observation of loadout is not feasible, the owner or operator must document the annual loadout frequency and the reason why observation is not feasible and inspect the facility within 24 hours after loadout to confirm that all storage tank thief hatches (or other access point to the tank) are closed and latched. • The owner or operator must install signage at or near the loadout control system that indicates which loadout control method(s) is used and the appropriate and necessary operating procedures for that system. • The owner or operator must develop and implement an annual training program for employees and/or third parties conducting loadout activities subject to Section II.C.5. that includes, at a minimum, operating procedures for each type of loadout control system. 23. Point 004: 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. 24. Point 004: 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)) 25. Point 003: The separator covered by this permit is subject to Regulation 7, Part D, Section II.F. On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the commencement of operation by air pollution control equipment that achieves an COLORADO Air Pollution Control Division Department of Public Health Et Environment Page 6 of 13 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. 26. On or before June 30th, 2021 (and on June 30th each year thereafter), the owner or operator of oil and natural gas operations and equipment at or upstream of a natural gas processing plant in Colorado must submit a single annual report that includes actual emissions and specified information in the Division -approved report format. The information included in the annual report must be in accordance with the general reporting requirements of Regulation Number 7, Part D, Section V.B. Beginning July 1, 2020, and each calendar year thereafter, owners or operators must maintain the information according to Regulation Number 7, Part D, Section V.C. for inclusion in the annual report. (Regulation Number 7, Part D, Section V) OPERATING £t MAINTENANCE REQUIREMENTS 27. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OFtM) 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 OItM 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 28. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements 29. This source is not required to conduct periodic. testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 30. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or COLORADO Air Pollution Control Division Department of Public Health b Environment Page 7 of 13 For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. GENERAL TERMS AND CONDITIONS 31. 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. 32. 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. 33. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operators agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 34. 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. 35. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. COLORADO Air Pollution Control Division Department of Public Health Er Environment Page 8 of 13 36. 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. 37. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Christopher Kester Permit Engineer Permit History Issuance Date Description Issuance 2 This Issuance Issued to Bonanza Creek Energy Operating Company, LLC Updated all points - updated process limits, and associated emission limits. Addition of Point 004 Issuance 1 September 27, 2018 Issued to Bonanza Creek Energy Operating Company, LLC. COLORADO Air Pollution Control Division Department of Public Health b Environment Page 4 of 13 Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https: / /www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 001 Benzene 71432 710 35 Toluene 108883 729 36 Ethybenzene 100414 59 3 Xylenes 1330207 177 9 n -Hexane 110543 20,196 1,010 003 Benzene 71432 3826 192 Toluene 108883 4572 230 Ethybenzene 100414 698 36 Xylenes 1330207 2070 104 n -Hexane 110543 25744 1288 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. COLORADO Air Pollution Control Division Department of Public Health b Environment Page 10 of 13 5) The emission levels contained in this permit are based on the following emission factors: Point 001: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 0.0680 (lb/MMBtu) 0.0680 (lb/MMBtu) AP -42 Ch. 13.5 CO 0.3100 (lb/MMBtu) 0.3100 (lb/MMBtu) VOC 6.1120 0.3056 VMGSim model based on a site - specific pressurized liquid sample. 71432 Benzene 0.0108 0.0005 108883 Toluene 0.0111 0.0006 100414 Ethylbenzene 0.0009. 0.00004 1330207 Xylene 0.0027 0.0001 110543 n -Hexane 0.3094 0.0155 Note: The controlled emissions factors for this point are based on the flare control efficiency of 98%. Point 002: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 0.262 0.0052 Default for Weld County 71432 Benzene 0.007 0.00014 110543 n -Hexane 0.022 0.00044 Note: The controlled emissions factors for this point are based on the flare control efficiency of 98%. Point 003: CAS # Pollutant Uncontrolled Emission Factors (lb/MMscf) Controlled Emission Factors (lb/MMscf) Source NOx 0.0680 (lb/MMBtu) 0.0680 (lb/MMBtu) AP -42 Ch. 13.5 CO 0.3100 (lb/MMBtu) 0.3100 (lb/MMBtu) VOC 30,782.1 615.642 Mass Balance on a site -specific gas sample 71432 Benzene 101.0 2.020 108883 Toluene 120.7 2.414 100414 Ethylbenzene 18.4 0.368 1330207 Xylene 54.7 1.094 110543 n -Hexane 679.9 13.598 Note: The controlled emissions factors for this point are based on the flare control efficiency of 98%. COLORADO Air Pollution Control Division Department of Public Health 8 Environment Page 11 of 13 Point 004: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 0.236 0.00472 State default emission factors n -Hexane 0.0036 0.00072 Controlled emission factors are based on a combustor efficiency of 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 shall be submitted no later than 30 days before the five- year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, HAPs NANSR Synthetic Minor Source of: VOC MACT HH Area Source Requirements: 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: http: //ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart X00000( COLORADO Air Pollution Control Division Department of Public Health Fr Environment Page 12 of 13 COLORADO Air Pollution Control Division Department of Publtc Health 8 Envonment Page 13 of 13 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Package #: Received Date: Review Start Date: For Division Use Only Christopher Kester 428391 3/'0/2020 '2/16/?029 Section 01- Facility Information Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Location: County: Type of Facility: 'Exploration & Product±o≥tWfefl What industry segment? 0:, & Natural Gas Production & Processing - - Is this facility located in a NAAQS non -attainment area? Yes If yes, for what pollutant? ozone (NOx& WC), Bonanza Creek Energy Operating Company LLC 123 SFB9 .• on'ghorn 14-11 Production faot(ity �,2:08tilt quadrant C __:.- -, Weld County Section 02 - Emissions Units In Permit Application Leave Blank - For Division Use Oray AIRS Point # (Leave blank unless APCD has already assigned) Emissions Source Type Equipment Name Emissions Control? Permit # (Leave blank unless APCD has already assigned) Issuance # Self Cert Required? Action Er�ineering Remarks 001 - - Storage Tank - CNDTK-O7. Yes EG355 2 - Yes Permit - Modification. Condensate 002 _ Storage Tank - - PWT-01 Yes sA./E0355 2 -Yes Permit ModifiCatlan oL�t CO3 - _ Separator Venting - ECD-01 - .- Yes 18AJE0355 2 --Yes Permit- Modifications. -. 004 Liquid Loading L-1 Yes 18WE0355 - fes Permit ' Modification Quadrant Section Township Range SWSW 3N 63 Section 03 - Description of Project Applicant is modifying permit to stay below new non -attainment area meier-source threshold %Oil be a new synthetic m SOtpy or permit under the new limit of Sections 04, 05 & 06- For Division Use Only Section 04 - Public Comment Requirements Is Public Comment Required? Yes - If yes, why? :Requesting Synthetic Minor Permit - Section OS - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? No If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Yes - - - is this stationary source a synthetic minor? Yes If yes, indicate programs and which pollutants: SO2 NOx CO VOC PM2.5 Prevention of Significant Deterioration (PSD) _ CIEIDOCI Title V Operating Permits (OP) ❑ ❑ ❑ M ❑ Non -Attainment New Source Review (NANSR) ❑ M Is this stationary source a major source? _ No If yes, indicate programs and which pollutants: SO2 NOx CO VOC PM2.5 Prevention of Significant Deterioration (PSD) ❑ ❑ ❑ ❑ ❑ Title V Operating Permits (OP) ❑ ❑ ❑ ❑ ❑ Non -Attainment New Source Review(NANSR) O O PM30 TSP ❑ ❑ ❑ PM10 TSP ❑ ❑ ❑ ' HAPs Gal HAPs ❑ - _ torageTank(s) Emissions Inventory Section 01- Administrative Information 'Facility AlRs ID: 123 9F60 County Plant Poin Section 02 - Equipment Description Details Storage Tank Liquid Detailed Emissions Unit Three Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency Y: Limited Process Parameter t Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions -Storage Tank(s) Actual Throughput= Requested Permit Umit Throughput= 21,90GA Barrels (bbl) per year 65,700.0Barrels (bbl) per year Requested Monthly Throughput= 5580.0 Barrels (bbl) per month Potential to Emit (PTE) Condensate Throughput = Secondary Emissions - Combustion Device(s) Heat content of waste gas = Volume of waste gas emitted per BBL of liquids produced = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = Barrels (bbl) per year 2442.0 Btu/scf 67.9 scf/bbl Potential to Emit (PTE) heat content of waste gas routed to combustion device = Control Device 3,631.3 MMBTU per year 10,893.3 MMBTU per year 10,893. MMBTU per year Pilot Fuel Use Rate; Pilot Fuel Gas Heating Value: scfh Btu/scf C.0 MMscf/yr MMBTU/yr Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Emission Factors Condensate Tank Pollutant Uncontrolled Controlled. (lb/bbl) (lb/bbl) (Condensate (Condensate Throughput) Throughput) VOC 6.1120 0.3056 0.00054 0.90056 0.00005 0,00014 0.01537 9.00010 Benzene 0.0102.:::. Toluene Ethylbenzene Xylene n -Hexane 0.3074."' 224 TMP 0.062D Pollutant Control Device Uncontrolled Uncontrolled (Ib/MMBtu) (11z/bbl) (waste heat (Condensate combusted) Throughput) PM10 PM2.5 0 607 0.0012 0.0012 0.0000 0.0113 0.65'14 SOx NOx 0.9659 CO 0.3130 Pollutant Pilot Ligh Emissions Uncontrolled Uncontrolled (Ib/MMBtu) (Ib/MMscf) (Pilot Gas Heat (Pilot Gas Combusted) Throughput) PM10 PM2.5 9.0000 0.0000 0.0000 0.0000 0.0000 09000 SOx NOx VOC CO Section OS - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) - Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (Ibs/month) PM10 PM2.5 SOx NOx VOC CO p.[7 0,0 09 0.0 3.0 6.9 .._ 0,0 0.E 0.0 =._ 6.9 ..,. 0.0 0.0 0.0 .... 0.0 ,..» 0.1 GA 0.37 --.- 52,9 200.8 66.9 3.3 200.8 1705.2 1.7 0.6 0.6 1.7 _., .,.... Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (Ihs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (Ibs/year) Benzene Toluene Ethylbenzene 709.6 ...,... '_1.3 710 35 724.3 ._ 12.2 71.9 3a' 59.1 ... _. 1.0 59 3 2 of 18 K:\PA\2018\18W E0355.CP2 Eitorage Tank(s) Emissions inventory Xylene 'I. -Hexane 224 TMP 177.4` s,7 177 20126.2 5732.'_ 4'3.8 336.6 20156 1012 1314 22 131. 3 of 18 ICAPA\2018\18WE0355.CP2 Emissions Inveeitory Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source re wires apeman Regulation 7, Part D,Section I.C, D, E, F Storage tank:_ subject tot Regulation 7, Part C. Section 1 Regulation 7, Part D,Section I.G, C Storage Tong is not an blest to Regulation 7, Seaton .-_ Regulation 7, Part D,Section ll.B, C.1, C.3 sic a._t„s -_, u,".t Cn7 ... B. C..,93._ Regulation 7, Part D,Section II.C.2 Storage k le subject to Regulation ,.Pain ,,, _.. Regulation 7, Part D,Section II.C.4.a.(i) Stonage r.nk3 not gnninnt.o Regination 7. Pant D. Seeing-1listioleii3 Regulation 7, Part D,Section II.C.4.a.(ii) Storage Tanis is mg subject so R _u iation 7. Past D Sac -lino itilibbialilj, la -. Regulation B, Part A, NSPS Subpart Kb Storage Tanks not -r to y oS Y:':_ ' Regulation 6, Part A, NSPS Subpart 0000 Not t F men Gemini, - NSPS Subpart 0000a NotieboingnInfcrmatien Regulation 8, Part E, MACr Subpart HH Sterna Tank is not 5Vbiecl to MAO" H (See regulatory applicability worksheet for detailed analysis) Section 07- Initial and Periodic Sampling and Testing Requirements For condensate or crude ml tanks, does the company use the state default emissions factors to estimate emissions? 'Eyes, are the uncontrolled actual or requested emissions for a crude oil tank estimated to be greater than or equal to 20 tons VOC per year OR are the uncontrolled actual or requested emissions for a condensate storage tank estimated to be greater than or equal to 80 tpy? If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03. Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted (for produced water tanks, a pressurize liquid sample must be analyzed using flash liberation analysis)? This sample should be considered representative which generally means site -specific and collected within ace year of the application received date. However, if the facility has not been madified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02 Section 08 - l echnical Analysis Notes Emission factors have not been changed.. Only AIRS Point If 001 Section 09 -SCC Coding and Emissions Factors (For Inventory Use Only) Process it SCC Code O1 Uncontrolled Emissions Pollutant Factor Control % Units PM10 0Ci3 0 16/1,000 gallons Condensate throughput PM2.5 lb/1,000 gallons Condensate throughput SOx annEgi 0 Ib/1,000 gallons Condensate throughput NOx G.27 0 16/1,000 gallons Condensate throughput VOC _. 5_ 16/1,000 gallons Condensate throughput CO -1.23 o lb/1,000 gallons Condensate throughput Benzene 329 95 16/1,000 gallons Condensate throughput Toluene 0.26 95 16/1,000 gallons Condensate throughput Ethylbenzene 0_32 55. lb/1,000 gallons Condensate throughput Xylene 0.06 95 I6/1,000 gallons Condensate throughput n -Hexane 732 95 lb/1,000 gallons Condensate throughput 224 TMP C.05 35 lb/1,000 gallons Condensate throughput 4 of 18 KAPA\2018\18WE0355.CP2 Storage Tank Regulatory Analysis Worksheet The regulatory requirements below are determined based on requested emissions. Colorado Regulation 3 Parts A and B -ADEN and Permit Requirements au..e in the Nontsettetymem A-ecr ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY(Regulrtion 3, Part A,Sertion ll.O.Lal7 ®Source Requires an APEN. Go to 2. Isthe construction date (service date) prior. 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability(? 3 Are total facility uncontrolledVOC emissions greater thanSTPY, NOxgemer than 10 TPY or CO emissions greater than to TPY (Regulation 3, Part%Section ll.D.3)? NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than 1TPY(Regulation 3, Part A,Section ll.D.S.a)? 2. Is the construction date (service date) prior. 12/30/2002 and nnt modified after 12/31/2002 (See P5 Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? - 3. Are total facility uncontrolled VOC emissions greaterthan 2TPY, NOx greater than 5 TPY nr CO emissions greater than 10 TPY (Regulation 3, Part%Section 11.0.2)? eartph Colorado Regulation 7. Part D. Section I.C-F & G 1. Is thisstorage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area (Regulation 7, Part 0, Section IA.1)2 2. Is this storage tank located at oil and gas operations that collect, store, or handle hydrocarbon liquids or produced water AND that are located at or upstream of a natural gas processing plant (Regulation 7, Part 0, Section I.A.1)7 3. Is this storage tank located at a natural gas processing plant (Regulation 7, Part D, Section I:G)7 4. Does this smragetank contain condensate? 5. Does this storage tank exhibit "Flash" (e.g. staring non -stabilized liquids) emissions (Regulation 7, part D, Section l.G.2)7 6. Are uncontrolled actual emissionsof this storage tank equal to or greaterthan 2 -tons per year VOC (Regulation 7, Part D, Section l.D.3.a ii))? Part D, Section I.C.1 —General Requirements for Air Pollution Control Equipment —Prevention of Leakage Part D, Section I.C.2—Emission Estimation Procedures Part D, Section I.D— Emissions Control Requirements Part D, Section LE —Monitoring Part D, Section hF—Recordkeeping and Reporting Part D, Section I.G.2- Emissions Control Requirements Part D,Section I.C.1.a and h —General Requirements for Air Pollution Control Equipment —Prevention of Leakage Colorado Regulation 7. Part D, Section II 1. Is this storage tank located at a transmission/storage facility? 2. Isth65torage tanks located at an of and gas exploration and production operation, well production facility', natural gas compressor stations or natural gas processing plant' (Regulation 7, Part D, Section lLC)? 3. Does this storage tank have afixed roof (Regulation 7, Part D,Section LAID)? 4. Are uncorhralled actual emissionsof this storagetank equal to or greater than 2 tons per year VOC (Regulation 7, Part D, Section ll.C.S.c)2 If;c 7.P CS C.1&C,9 Part D, Section %B. —General Provisions for Air Pollution Control Equipment and Prevention of Emissions Part 0, Section II.C.1- Emissions Control and Monitoring Provisions Party], Section II.C.3 - Recordkeeping Requirements S Does the storage tank contain only "stabilized' liquid (Regulation J Part D, Section ll.C.2.b)? Part D, Section II.C.2- Capture and Monitoring for Storage Tanks fisted with Air Pollution Control Equipment Is the controlled storage tank located at a well production facility, natural gas compressor station, or natural gas processing plant constructed on or after May 1, 2020 or located at a facility that was modified on or after May 1, 2020, such 6. that an additional controlled storage vessel Is constructed to receive an anticipated Increase in throughput of hydrocarbon liquids or produced water (Regulation 7, Part D, Section ll.C.4.a.(87 _ '..s Storage Tank iz not subject to Re 1+a Ws fAd3?�r 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 th Continue - You have indicated th Storage Tank b not subject to Rc e Continue -You have indicated th Go to the next question - You ha Go to the next quertion Source Is subjectto parts of Regi ITV, source issubject to allprovision: Is the controlled storage tank located at a well producton facility, natural gas compressor station, or natural gas processing plant constructed on or after -January 1, 2021 or located at a facility that was modified on or afterlanuary 1, e� 7 2021, such that an additional controlled storage vessels constructed to receive an anticipated increase nthroughput of hydromrbonlguids or produced water (Regulation 7, Part D,Section llC4.a.l-I)? 40 CFR, Part 60. Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1 Is the individual storage vessel capacity greater than equal to 75 cubic meters (m)(-472 BBLsj(40CFR 60.1106(a))? 2. Does thestorage vessel meet the following exemption in 60.111b(d)(4)7 a. Does the vessel hasa design capacity less than or equal to 1,509.874m'(-10,000 BBL] used for petroleums or condensate stored,processed, or treated prior to custody transfer' as defined in 60.11lb? 3. Was thls storage vessel constructed,reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23, 1984(40 CFR 60.11Ob(a))? 4. Does the tank meet the definition of "storage vessel.' in 60.111b7 5. Does the storage vessel store a"volatile organic liquid(VOL)ssas defined in 60.1116? 6. Does the storage vessel meet any one of the following additional exemptions: a. Is thestorage vessel a pressure vessel designed to operate in excess of 204.9 kPa r2,9.7 psi] aad without emissions to the atmosphere (60.1106(d)(2))7; or b. The design capacity is greaterthan prequel. 151 ma [-95D BBL] and stares a liquid with a mmimumtrue vapor pressure' lessthan 3.5 kPa (60.1106(bl)?; or c. The design capacity is greaterthan or equal to 75 Ms [-472 BBL] but less than 151 m' I" 950 BBL] and stores a liquid with a maximum true vapor pressures less than 15.0 kPa(60.11ob(b))7 7. Dees the storage tank meet either one of thefollowing exemptions from control requirements; a. The design capacity is greaterthan or equal to 151 ms [-950 BBL] and stores a liquid with a maximum true vapor pressure greaterthan or equal to 3.5 kPa but less than 5.2 kPa7; o b. The design capacity is greater than or equal to 75 M° ["472 BBL] but less than 151 m' j`950 BBL] and stores a liquid with a maximum true vapor pressure greater than or equal to 15.0 kPa but less than 27.6 kPa? `AM -5** Storage Tank Is not subject NSPS 40 CFR, Part 60, subpart 0000/Oo00a, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Isthis storage vessel located at a facility in the onshore oil and natural gas produrtion segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2] between August 23, Hill and September 18, 20357 3. Was this storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after September 18, 20157 4, Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? S. Does this storage vessel meet the definition of"storage vessel"' per 60.5430/60.5430a? 6. Isthe storage vessel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Part GO Subpart Kb or 40 CFR Part 63 Subpart HH7 I WWww,w, [Nate: If a storage vessel is previously determined to be subject to NSPS 0000/0000a due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS 0000/0000a per 60.5365(e)(2)/60.5365Me)(2) even if potential VOC emissions drop below 6 tons per year] 40 CFR, Part 63, Subpart MAC' UN, Oil and Gas Production Facilities 1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. Afacility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR. b. Afacility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas. transmission and storage source category or is delNeredto a final end user' (63.7600)(3))7 2. Is the tank located at a facility that is major' for HAPs? 3. Does the tank meet the definition of"storage vessels° In 63.761? 4. Does the tank meet the defintion of"storage vessel with the poteMialfor flash emasions"'per 63.7617 S. Is the tank subjectto control re uirements under 40 CFR Part 60, Subpart Kb or Subpart 00007 "P° SMIU Continue- You have indicated th i`,,0 i*aft Ices 'Continue- You have indicated th Subpart A, General provisions per 463.764 (a) Table 2 563.766 -Emissions Control Standards 463,773 -Monitoring 463.774- Recordkeeping 463.775 -Reporting RAC' Review RACE review Is required If Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meet both criteria, then review RACE requirements. Disclaimer Storage Tank Is not subject MAC This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing' regulations, and Air Quality Control Commission regulations. This document is not rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ ifs implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use ofnorimendatory language such es'recommend,"'may,"'should,"and "can,"is intended to describe APCD interpretations and recommendations. Mandatary terminology such as'musCand "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. i ErT),S>irons inventory Section 01 -Administrative Information 'Facility AIRS ID: County Plant Point Section 02 - Equipment Description Details Storage Tank Liquid Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency b: Limited Process Parameter Section 03- Processing Rate Information for Emissions Estimates Primary Emissions -Storage Tank(s) Actual Throughput = 'Requested Permit Limit Throughput= Potential to Emit (PTE) Condensate Throughput = Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquids produced = Actual heat content of waste gas routed to combustion device= Requested heat content of waste gas routed to combustion device = Barrels (bbl) per year Barrels (bbl) per year Requested Monthly Throughput= 1a Barrels(bbl) per year Btu/scf scf/bbl Potential to Emit (PTE) heat content of waste gas routed to combustion device = Control Device - -; MMBTU per year 491.3 MM BTU per year _.. » MMBTU per year Section 04 - Emissions Factors.& Methodologies Will this storage tank emit hash emissions? Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tans/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (Ibs/month) PMSD PM2.5 SOx NOx VOC CO 1.„ 0.0 0._ ".,, 0.0 0.0 _.., .a 0 0.0 0.0 4.0 0.0 0.¢ 0.0 0.0 0.02 0.0 2.3 1.2 0.5 0..r ..._ 0-1 10.2 AI 0.0 k.,, 0-.08 0.1 12:9 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (Ills/year) (Ibs/year) Benzene Toluene Ethylbenzene 6's.a 25 6 1.3 63-3 3.19 0.0 0.0 0,0 .., 0.0 0.0 775,0 Barrels (bbl) per month 7 of 18 K:\PA\2018\18 W E0355. CP2 Storage Tanks; Emissions Inventory xylene n -Hexane 224 TMP 0.0 0.0 0.0 nos 0.0 0.0 8 of 18 K\PA\201S\1SWE0355.CP2 ! enter Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Sour, requires permit Regulation 7, Part D,Section I.C, 0, E, F 3tara�re canit is Wussjed to flea€rfaeicn 7, Part O, Section I.C-F Regulation 7, Part D,Section I.G, C — Storage Tarn, is rut subject to ensquierian- [,Simon E� Regulation 7, Part D,Section II.B, C.1, C.3 Storage tank is subject to Re uiatton 7, Part D, Se=tier i`, B, C.1 St C.3 Regulation 7, Part D,Section II.C.2 Storage tank 15 subject terRegu nation 7, Part la, Section i'.=".,2 Regulation 7, Part D,Section II.C.4.a.(i) Storage Tank in rat SitAbj to Reg. ation r. Pont D, ..,.i.rou i_Cakaliii Regulation 7, Part D,Section II.C.4.a.(ii)' Sternge Tank in ant stinkers TO Beattie -ken 7. Park ID Si c „ - Regulation 6, Part A, NSPS Subpart Kb Storage , in ont nuking, ._ kret PS irn Regulation 6, Part A, NSPS Subpart 0000 rentennugl, >rfnines in N5P5 Subpart 0000a Not enot,o ininr^satiar Regulation B, Part E, MACF Subpart HH Prc;t___a._,e.Ste rune rank is not S,.or_Ct I,_..._'d See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements For condensate or crude ail tanks, does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions for a crude oil tank estimated to be greater than or equal to 20 tons VOC peryear OR are the uncontrolled actual or requested emissions for a condensate storage tank estimated to be greater than or equal to 80 tpy? If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03. Does, the company use a site specific emissions factor to estimate emissions? Ryes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted (far produced water tanks, a pressurize liquid sample must be analyzed using flash liberation analysis)? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. ' If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo i4-03. Does the company request a control device efftiency greater than 95% for a flare or combustion device? If yes, the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02 Section 09 - SCC Coding and Emissions Factors ( For Inventory Use Only) AIRS Point fI 002. Process SCC Code O1 Uncontrolled Emissions Pollutant Factor Control % Units PM10 C.G. C lb/1,000 gallons Produced Water throughput PM2.5 Cl 16/1,000 gallons Produced Water throughput 5Ox ,.._ lb/1,000 gallons Produced Water throughput NOx5,.,_ n lb/1,000 gallons Produced Water throughput VOC 5,27 93 lb/1,000 gallons Produced Water throughput CO ^4,0 0 lb/1,000 gallons Produced Water throughput Benzene x.17 45 lb/1,000 gallons Produced Waterthroughput Toluene C �� 95 lb/1,000 gallons Produced Water throughput Ethylbenzene 0,00 55 lb/1,000 gallons Produced Water throughput Xylene a.oc ._ lb/1,000gallons Produced Water throughput - n -Hexane 0.52 95 16/1,000 gallons Produced Water throughput 224 TMP .OG 95 16/1,000 gallons Produced Water throughput 9 of 18 KAPA\2018\18WE0355.CP2 Storage Tank Regulatory Analysis Worksheet The regulatory requirements below are determined based on requested emissions. Colorado Regulation 3 Parts A end B - APEN and Permit Reauirements �is mine iforvRtreimuss, Arta ATTAINMENT 1 Are uncontrolled actual emPsIonsfrom any criteria pollutants from the Individual source greater than 2TPY(Regulaton 3, Part A, Section llDl.a)7 2 Produced WatTanks hgrandfatheringp 3 Are totalfacility uncontrolledVOC emissions greater h 5TPY NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.3)7 `P!..ave irdiftme that source =>rrPas ,._., rrinmetArea NON -ATTAINMENT 1, Are uncontrolled emissions from any criteria pollutants from this individual source greater than l TPY (Regulation 3, Part A, Section ILD.l.a)7 2. Produced Water Tanks have no grandfathering provisions 3. Are total facility uncontrolled VOC emissions greater than 2TPY, NOx greater than 5 TPY or CO emissions greater than 10TPY(Regulation 3, Part 0, Section 11.0.2)7 !Source Requires an APEN. Go to Go to next quertion Source Requires a permit Source Requires an APEN. Go. Source Requires a permit Continue- You have indicated th Continue - You have indicated th Storage Tank is not subject to Re Colorado Regulation 7, Part D. Section l.C-F & G 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area (Regulation 7, Part Et Section IA.1)7 • 2. Is this storage tank located at oil and gas operations that collect, store, or handle hydrocarbon liquids or produced water ANOthat are located at or upstream of a natural gas processing plant (Regulation 7, Part D, Section IA.1)? 3. Is this storage tank located at a natural gas processing plant (Regulation 7, Part D, Section I.G)7 4. Does this storage tank contain condensate? 5. Does this storage tank exhibit "Flash" (e.g. storing non -stabilized liquids) emissions (Regulation 7, part 0, section 1.6.2)? 6. Are uncontrolled actual emissions of this storage tank equal to orgreaterthan 2 tons per year VOC Regulation 7, Part 0, Sertion Part D, Section I.C.1 —General Requirements for Air Pollution Control Equipment —Prevention of Leakage Part D, Section I.C,2—Emission Estimation Procedures Part D, Section I.D — Emissions Control Requirements Part D, Section 1.5 —Monitoring Part 0, Section I.F — Recordkeeping and Reporting I Part D, Section I.G.2- Emissions Control Requirements Pert D, Section I.C.I.a and b — General Requirements for Air Pollution Control Equipment —Prevention of Leakage Colorado Regulation 7. Part D. Section', 1. Is this storage tank located at a transmission/storage facility? 2. Is this storage tank' located at an all and gas exploration and production operation, well production facility', natural gas compressor stations or natural gas processing plane(Reguletion 7, Part D, Section ITC)? 3. Dees this storage tank have a fixed roof (Regulation 7, Part D,Section lLA20)? 4. Are uncontrolled actual emissions of thB sorage tank equal to or greater than 2 tons per year VOC (Regulation 7, Part D, Section lLGl.c)? I. Part 0, Section II.B—General Provisions for Air Pollution Control Equipment and Prevention of Emissions Part D, Section II.C.1- Emissions Control and Monitoring Provisions Part 0, Section II.C.3 - Recordkeeping Requirements 5. Does the storage tank contain only "stabilized" liquids (Regulation 7, Part D, Section 11.[.2.6)7 Continue -You have indicated th Go to the next question -You ha Go to the next question Source is subject to parts of Reg Source is subject to all provisions Part 0, Section II.C.2- Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment is the controlled storage tank located at a well production facility, natural gas compressor station, or -natural gas processing plant constructed on or after May 1, 2020 or located at a facility that was modified on or after May 1, 2020, such 6. that an additional controlled storage vessel is constructed to receve an anticipated increase in throughput of hydrocarbon liquids or produced water (Regulation 7, Part 0, Section ll.C.4.a.()? Nu.....:.',, Storage Tank is not subject to RE Is the controlled storage tank located at a well production facility, natural gas compressor'tatIon, of -natural gas processing plant constructed on or after January 1, 2021 or located at a facility that was modified on or after January 1, ^,I 7 21121 such that an additional controlled storage vessel's constructed to receive an anticipated increase in throughput of hydrocarbon liquids or produced water(Regulation 7, Part D, Section ll.C4a.()7 I'Sf : f 40CFR Part 60, subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the Individual storage vessel rapacity greaterthan or equal to 75 cubic meters (m') ['"472 Bats] (40 CFR 60.1106(a))? 2. Does the storage vessel meet the following exemption in 60.111b1d1(4)7 'fns Storage Tank is not subject NSPS a. Does the vessel has a design capacity less than or equal to 1,589.874 m(-10,000 BBL) used for petroleum' or condensate stored,processed, or treated prior. custodytransferz as defined in60.111b? 3. Was this storage vessel constructed,reconstructed, or modified (see definitions 40 CFR, 60.2)after July 23,1984(40 CFR60.110b(a))7 4. Does the tank meet the definition of"storage vessel' In 60.111b7 5. Does the storage vessel store a"volatile organic liquid(VOleas defined In 60.111b7 6. Does the storage vessel meet any one ofthefallowing additional exemptions: a. Ls the storage vessel a pressure vessel designed to operate In excess of 204.9 kPa 1-29.7 psi) and without emissions to the atmosphere(60.Slob(d)(2))7; or - b. The design capacity is greater than or equalto 151 ma ["950 BBL) and stores a liquid with a maximumtme vapor pressures less than 3.5 kPa (60.11ob(b))7; ar c. The design capacity is greater than or equalto 75 NI' [-472 BBL] but less than 151 m' [`9S0 BBL] and stores a liquid with a maximum true vapor pressure• less than 15.0 kPa(60.110b(b))? 7. Does the storage tank meet either one of the following exemptions from control requirements: a The design capacity is greaterthan or equal to 151 in'[ -950 BBL] and stores a liquid with a maximum true vapor pressure greater thanor equal to 35 kPa but less than 5.2 kPa7; or b. The design p ity is greater than or equalto 75 M'(-472 BBL) but less than 151 m'['950 BBL) and stores a liquid with a maximum true vapor pressure greater than or equalto 150 kPa but less than 27.6 kna? Y Iitorageiis 40 CFR, Part 60, Subpart 0000/0000e. Standards of Performance for Crude Oil and Natural Gas Praduction,Trensmisian and Distribution 1. Is this storage vessel located at a facility In the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the Industry? 2. Was this storage vessel constructed,reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Was this storage vessel constructed,reconstructed, or modified (see definitions 40 CFR, 60.2) after September 18, 20/5? 4. Are potential VOC emissions' from the individual storage vessel greater than or equalto 6 tons per year? 5. Does this storage vessel meet the definition of"storage vessel"' per 60.5430/60.5430a7 6. Is the storage vessel subject to and controlled in accordance with requirements for storage vessels In 40 CFR Part 605ubpart Kb or 40 CFR Part 63 Subpart NH? Yes >>ti'1W�Cenz& -wait MOW 1NotsttaUglt brta[m-nlnn [Note: If a storage vessel is previously determined to be subject. NSPS 0000/0000a due to emissions above 6 tons per year VOC on the applicability determination date, Ftshould remain subject. NSPS 0000/0000a per 60.5365(e)(2)/60.5365a(e)(2) even if potential VOC emissions drop below 6 tons per year] 40 CFR, Part 63, Subpart MAR HH, 011 and Gas Production Facilities 1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. Afacility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR b. A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end user2(63.76a(a)(3))7 2. Is the tank located at a facility that is major' for RAPS? 3. Does the tank meet the definition of"storage vesselx' in 63.761? 4. Does the tank meet the deflndion of storage. vessel with the potential for flash emissions"' per 63.7617 5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or Subpart 00007 Subpart A, General provisions per 463.764 (a) Table 2 463.766- Emissions Control Standards 463.773 -Monitoring 463.774-Recordkeeping 463.775 -Reporting RAC' Review RACT review is required if Regulation 7 does not apply AND lithe tank is in the non -attainment area. If the tank meets both criteria, then review RAC' requirements. Disclaimer Storage Tank is not subject MAC gam u ra Continue - You have indicated th Continue -You have indicated th This document assists operators wifh determining applicability of certain requirements of the Clean Air Act, ifs implementing regulations, end Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains. may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control The use of non -mandatory language such as"recommend,""may""should,"and "can,"is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "musCand "required"are intended to describe controlling requirements under the terms of the Clean Air Act and Air Qualify Control Commission regulations, but this document does not establish legally binding requirements in and of itself. Separator Venting Erniss;cns inventory Section 01- Administrative Information Facility AIRS ID: 123 County 9F80 Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: gas routed to enclos Emission Control Device Description: frtclosed Combustor Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter Gas meter Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions -Separator Actual Throughput= 37.9 MMscf per year 37.9 MMscf per year Requested Monthly Throughput= Requested Permit Limit Throughput = 3.2 MMscf per month Potential to Emit (PTE) Throughput = .,' MMscf per year Secondary Emissions - Combustion Device(s) for Air Pollution Control Separator Gas Heating Value: Volume of waste gas emitted per BBL o liquids throughput: scfh Btu/scf Control Device Pilot Fuel Use Rate: Pilot Fuel Gas Heating Value: 0,9 MMscf/yr Section 04 -Emissions Factors & Methodologies MW Weight Helium CO2 N2 methane ethane propane isobutane n -butane isopentane n -pentane cyclopentane n -Hexane cyclohexane Other hexanes heptanes methylcyclohexane 224-TMP Benzene Toluene Ethylbenzene Xylenes C8+ Heavies Total VOC Wt Ib/Ih-mol Displacement Equation Ex=q'MW•Xx/C 12 of 18 K:\PA\2018\18WE0355.CP2 ` Emission Factors Separator Venting Emission Factor Source Pollutant Uncontrolled Controlled (Ib/MMscf) (Ib/MMscf) (Gas Throughput) (Gas Throughput) VOCrr -.. ' Benzene ,.�';' Toluene __ _ Ethylbenzene Xylene � n -Hexane _".�' 224 TMP __ Pollutant Primary Control Device Emission Factor Source Uncontrolled Uncontrolled (Ib/MMBtu) Ib/MMscf (Waste Heat Combusted) (Gas Throughput) PM10 , r PM2.5 0.0+375 SOx , 4.0006: NOx "0.0680: CO Pollutant Pilot Light Emissions Emission Factor Source Uncontrolled Uncontrolled (Ib/MMBtu) Ib/MMscf (Waste Heat Combusted) (Pilot Gas Throughput) PM10 PM2.5 SOx._§ NOx Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (Ibs/month) PM10 PM2.5 SOx NOx VOC CO ..._ .. .... ,..:. .... a .3_ 535 7 553.7 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (Ihs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 IMP 335, 35:=3... 1;' _ 55_: Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Part D, Section 11.8, F Regulation 7, Part D, Section 1I.8.2.e (See regulatory applicability worksheet for detailed analysis) 13 of 18 KAPA\2018\18WEO355.CP2 Separator Venting EmissiQris: !riventQry Section 08 - Technical Analysis Notes Section 07 - Initial and Periodic Sampling and Testing Requirements Using Gas Throughput to Monitor Compliance Does the company use site specific emission factors based on a gas sample to estimate emissions? This sample should represent the gas outlet of the equipment covered under this AIRS ID, and should have been collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -speck sample. If no, the permit will contain an "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to theemissions factors established with this application. Are facility -wide permitted emissions of VOC greater than or equal to 40 tons per year in the ozone nonattainment area OR are emissions greater than or equal to 90 tons per year in the ozone attainment area? If yes, thepermit will contain: -An "Initial Testing Requirement" to collect a. site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. -A "Periodic Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that theemission factors are less than or equal to the emissions factors established with this application on an annual basis. Will the operator have a meter installed and operational upon startup of this point? Ve= If no, the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational (not to exceed 180 days). This condition will use the "Volume of waste gas emitted per BBL of liquids throughput" (scf/bbl) value in section 03. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02 ti*ai Section 09 - SCC Coding and Emissions Factors (For Inventory Use Only) AIRS Point # Process # SCC Code 003 01 3-10,00.60 Flares Pollutant Uncontrolled Emissions Factor Control PM10 1,_ PM2.5 50x S 0 NOx 504.5 VOC 35752-.1 CO 4?E.3 Benzene Toluene Ethylbenzene _ Xylene n -Hexane 224 TMP 10,4 54,7 0.4 Units 14 of 18 K:\PA\2018\18 W E0355.CP2 Separator Venting Regulatory Analysis Worksheet The regulatory requirements below are determined based on requested emissions. Colorado Regulation 3 Parts A and B - APEN and Permit Requirements In the N.n-n*'talram^a Art. ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section ll.D.l.a)7 2. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than lO TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 1(.0.3)7 You indiiraied is In tha 't ta: rE;2reg NON -ATTAINMENT 1 Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section ll.Dl.a)7 2 Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.2)7 Colorado Regulation 7, PartD, Section II 1. Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 20142 1= a ,,,ti-<Regulati-on7 Section 11.B.2— General Provisions for Air Pollution Control Equipment Used to Comply with Section II Section II.F - Control of emissions from well production facilities Alternative. Emissions Control (Optional Sectlanl a.Isthis separatort II dby a hack -up It t combustion d ( not the primary control deuce) that is not enclosed? Section II.B.2.e—Alternative emissions control equipment Qisclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the,analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as'recommend,"'may,"'should,"and "can,"is intended to describe APCD interpretations and recommendations. Mandatory terminology such as'must"and "required"are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself re S ce Re 'V`t'i�`;`'.;,d Source Re Source is s The contra arbor Loadout Emissions Inventory Section 01 -Administrative Information Facility AIRS ID: Plant Point Section 02- Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Is this loadout controlled? Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Hydrocarbon Loadout Actual Volume Loaded = Requested Permit Limit Throughput= Potential to Emit (PTE) Volume Loaded = Barrels (bbl) per year yi",'?Jv''+` so Barrels(bbl) per year Requested Monthly Throughput= 5580 Barrels (bbl) per month Secondary Emissions - Combustion Device(s) Heat content of waste gas= Actual Volume of waste gas emitted per year = Requested Volume of waste gas emitted per year = Actual heat content of waste gas routed to combustion device = Requested heat content of wastegas routed to combustion device = Barrels (bbl) per year Btu/scf 1176E0i scf/year 117693 scf/year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 1.79 MMBTU per year -S:a MMBTU per year 220 MMBTU per year Control Device Pilot Fuel Use Rate: Pilot Fuel Gas Heating Value: scfh Btu/scf .3 MMscf/yr _.� MMBTU/yr Section 04- Emissions Factors & Methodologies Does the company use the state default emissions factors to estimate emissions? Does the hydrocarbon liquid loading operation utilizesubmerged fill? Emission Factors Pollutant VOC Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP Pollutant Hydrocarbon Loadau Uncontrolled (lb/bbl) (Volume Loaded) Control Device Controlled (lb/bbl) (Volume Loaded) Uncontrolled Uncontrolled (Ib/MMBtu) aste he combusted) (Ib/bbl) (Volume Loaded) Pilot Light Emissians Uncontrolled Uncontrolled Pollutant (Ib/MMBW) (Waste Heat Combusted) PM10 PM2.5 SOx NOx VOC CO (Ib/MMscf) (Pilot Gas Throughput) Emission Factor Source Emission Factor Source Emission Factor Source 16 of 18 K:\PA\2018\18W E0355.CP2 Hydrocarbon Loadout Emissions Mve to :ry Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tans/year) Actual Emissions Uncontrolled Controlled (ions/year) (tans/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (ions/year) Requested Monthly Limits Controlled (Ibs/month) PM10 PM2.5 SOX NOx VOC CO 0.00 ,....,r ...,,_ 0.00 _..30 0 o.ea 0.70 0.00 . _ 0 ,,..: _ ,,.i90 , . _ 0.00 .. _ .,..,. 0.01 3.01 0.01 , -_ 2 .. _. __- 7-7_s 3.77 _ 0.04 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (Ibs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP ... 27 0 _ 0 0 _., _,. 237 y__ G Section 06-Regulato Summa Anal sis Regulation 3, PartsA, B permit Regulation 7 Part D Section II.C.5. 77, hydrocarbon loos -loot sour,)- is sublert :o Resolution 7'Sart Section Ii.Ci. (See regulatory applicability worksheet for detailed analysis) Section 07 -Initial and Periodic5ampling and Testing Requirements F' Does the company request a control device efficiency greater than 95%for a flare or combustion device? If yes, the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02 Section 08 Technical Analysis Notes Switching to state default eernission factors Section 09 -SCC Coding and Emissions Factors ( For Inventory Use Only), AIRS Point p 004 Process # 01 SCC Code 4-09401-32 Crude Oil: Submerged Loading Normal Service iS0 Gl Uncontrolled Emissions Pollutant Factor Control% Units. PM10 0 lb/1,000 gallons transferred PM2.5 0 lb/1,000 gallons transferred 5Ox _,.. 0 lb/1,000 gallons transferred NOx .,:, 0 lb/1,000 gallons transferred VOC :. 95 lb/1,000 gallons transferred CO _. 0 1b/1,000 gallons transferred Benzene 95 lb/1,000 gallons transferred Toluene 0-00 95 lb/1,000 gallons transferred Ethylbenzene a.no 95 lb/1,000 gallons transferred Xylene v.37 95 lb/1,000 gallons transferred n -Hexane 1.09 95 lb/1,000 gallons transferred 224 TMP 0--0 95 lb/1,000 gallons transferred 17 of 18 K:\PA\2018\18WE0355.CP2 Hydrocarbon Lando. Regulatory Analysis Worksheet The regulatory requirements below are determined based an requested emissions and throughput. Colorado Regulation 3 PertsA and B-APFN and Permit Requirements M„e,,,,.„,1x111.1: wee ATTAINMENT 1.. Are uncontrolled actual emissions from any criteria pollutant Sorgthis individual source greater than 2 TPY [Regulation 3, Part A, Section u.0.l.al? 2. Is the load. located at an emlom0on and production Me (e.g., well pad) [Regulation 3, Part 3, Section 11.0.1.11, 3. Is tie loadout operation loading less than 10,000 gallons (238 BMA Mamie. per day on an annual average basis? 4. Is Me loadout operation loading less than 6,]50 bbls per yearof condensate via splash fill, 5. Is the loac. operation loading less than 16,308 bbis per year ofemdensate via submerged fill procMure? 6. Are total facility uncontrolled VOcemisslons greater than STPY, NO8 greater than lO TPY or CO emissions greater than lO TPY(Mgulation 3, Part 8, Section 11.0.317 _,,,a.,. mdirme_. atmu.. lc In th. r.>...,.twnmms.._sa I NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria genus. from this individual sourcegreaMr than l TPY (Regulation 3, Part A, Sectan 0.0.1.47 2. Is the loadout located at an e:mloration and production site (eg., well W d1(Regulaton 3, Part %Section 11.63.11? 3. t the loadout operation loading less than 10,000 gallons (238 B.) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 6,]50 bbh per yearof cordensae via splash 'Si? 5. Is the loadout operation loading less than 18,308 bblspryearof condensate ...erg. fill pros ure? R. Are totalfacllity uncontrolled VOCemisslonsfrom the greater than 2TPY,N['xgreater than 5 TPY or. emisslons greater Nan 107PY(Begulatton 3, Part g, Section 11.0: 2). eoMredo Regulation ] Part ['Section is this condensate storage tote hydrocarbon Squids badout lorated a[a vrell producu'on facility, wemal gascompresorstaq'on ornatural gas processing plant? 2. Oros the facility have a throughput of hydrocarbon liquids load. to transport vehicles greater Manor equal to 5,000 barrels? Section II.C.5,a.111- Compliance schedule Section .a.Operation without Venting sa.liiil loadout Equipment operatlon and Maintenance secenn Itics.a.U.l- IwEonmbservations and Operator Training Moon n.C.5.a.IV1-Record: Secapn n.es.a.lyll-Requirement for Air Pollution Control Equipment Oisclalmer This document assists operators Mgt determining applicability or cedain requirements &fire Clean Pined, its Implementing regulations, and Air Quality Cadrel Commission regulations. This document is not a rule 0,ov/ellen, and the anelysisltcontains may not apply toe particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation,w any other legally binreng requirement and is not legally enforceable, In the event Many cadge, between the language of this axone. and the language ow the Clean Air Act„ its Implementing regulations, and Air Qualify CenbdCommission emulations, the language d the statute en regulation will control. Tin use dm'hmerdatoy language such as"recommend,' Inay,"'should."and 'ban,' is intended to describe APCD interpretations and recommendations. Mandatory terminology such...must'and-regrered'are intended bdescnbe controlling requirements and the terms & the Clean Air Act and Air Quality Control Commission regulations, but this document dces not establish legally bindrg mluitements in and Nifsel{. Go to next Go to . next guestion Go to nest gumlion Go to nest Theo nest gum,. Imdoutrequires a permlt Source is subject to Regulation ] Part ['Section II.C5. Condensate Storage Tank(s) APEN Form APCD-205 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 1 8WE03J5 AIRS ID Number: 123 / 9FB0 /001 Section 1 - Administrative Information Company Name': Bonanza Creek Energy Operating Company, LLC Site Name: Longhorn 14-11 Production Facility (COGCC #451353) Site Location: SWSW, Section 11, T3N, R63W Mailing Address: (Include Zip Code) 410 17th Street, Suite 1400 Denver, CO, 80202 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Alisson Soehner Phone Number: (303) 803-1752 E -Mail Address2: asoehner@bonanzacrk.com ' Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 428296 � COLOB,►DO d nem Ne,IU 6 Nrirm„ru Permit Number: 18VVE0355 AIRS ID Number: 123 /9m0/001 Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source ❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP01 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $312.50 must be submitted along with the APEN filing fee. -OR- CI MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name3 Q Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: Updating with new throughput and emission limits. 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. ' For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Company equipment Identification No. (optional): For existing sources, operation began on: Tank battery for storage of condensate prior to being trucked out. CNDTK-01 01/10/2018 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: Storage tank(s) located at: 24 hours/day 7 El Exploration & Production (EEO) site days/week 52 weeks/year ❑ Midstream or Downstream (non E&P) site Will this equipment be operated in any NAAQS nonattainment area? GI Yes ❑ No Are Flash Emissions anticipated from these storage tanks? GI Yes ■ No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? ■ Yes p No If "yes", identify the stock tank gas -to -oil ratio: m'/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 El Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actualII emissions ≥ 6 ton/yr (per storage tank)? Yes No D COLORADO De -parry.. Public NNW", 6 EPYIIannv.l Q Circular ❑ Square/rectangle ❑ Other (describe): 0 Upward ❑ Horizontal Permit Number: 18WE0355 AIRS ID Number: 123 / 9FB0 i 001 Section 4 - Storage Tank(s) Information Condensate Throughput: Actual Annual Amount (bbl/year) 21,900 Requested Annual Permit Limits (bbUyear) 65,700 From what year is the actual annual amount? 2019 Average API gravity of sales oil: 39.3 degrees ❑ Internal floating roof Tank design: Q Fixed roof RVP of sales oil: 8.4 ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (monthlyear) Date of First Production (month/year) CNDTK-01 Three (3) 500 bbl 1,500 12/2017 01/2018 Wells Serviced by this Storage Tank or Tank Battery's (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 45086 State Longhorn D14-11-12XRLNB • El ■ 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. 6 The MP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.23465, -104.413903 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) ECD-01 35 500 TBD TBD Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) Interior stack diameter (inches): 96 ❑ Upward with obstructing raincap Interior stack width (inches): Interior stack depth (inches): C A LOR�O n.wn..em d Permit Number: 18WE0355 AIRS ID Number: 123 /9R30/OO1 Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: % ❑ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 1.28 Type: Enclosed Combustor Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: 500 MMBtu / hr Make/Model: 95 98 % Crimson CE 1000 Waste Gas Heat Content: Constant Pilot Light: 0 Yes ❑ No Pilot Burner Rating: 2,442 0.05 Btu/scf MMBtu/hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 - Gas/Liquids Separation Technology Information (MP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? —60 Describe the separation process between the well and the storage tanks: psig Well produces to single stage 3 -phase separator where condensate is separated out and routed to the condensate tank battery. godF Hd h b {.M1r�1blNIN COLORADO Permit Number: 18WE0355 AIRS ID Number: 123 / 9FB0 / 001 Section 8 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form'. Is any emission control equipment or practice used to reduce emissions? (] Yes ❑ No If yes, describe the control equipment AND state the collection and control efficiencies (report the overall, or combined, values if multiple emission control methods were identified in Section 6): Pollutant Control Equipment Description Collection Efficiency (X of total emissions captured by control equipment) Control Efficiency (% reduction of captured emissions) VOC ECD 100 95 NOx CO HAPs ECD 100 95 Other: From what year is the following reported actual annual emissions data? 2019 Use the following table to report the criteria pollutant emissions from source: Pollutant Emission Factor' Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (AP 42, Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissions° (tons/year) Uncontrolled Emissions (tans/year) Controlled Emissions (tons/year) VOC 6.1120 Ib/bll Permit 11 66.93 3.35 200.78 10-04 NO. 0.068 Ib/MMBtu AP -42 0.14 0.14 0.39 0.39 CO 0.310 Ib/MMBtu AP -42 062 0.67 175 1.75 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. 7 Attach condensate liquid laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Section 9 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? (] Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name Chemical Abstract Service (CAS) Number Emission Factor' Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (Ibs/year) Controlled Emissions° (Ibs/year) Benzene 71432 0.0109 lb/bbl Permit 11 De Minimis De Minimis Toluene 108883 0.0112 Ibbbl Permit 11 De Minimis De Minimis Ethylbenzene 100414 0 0009 lb/bbl Permit 11 De Minimis De Minimis Xylene 1330207 0.0028 lb/bbl Permit 11 De Minimis De Minimis n -Hexane 110543 0.3095 Iblbbl Permit 11 6778 340 2,2,4-Trimethylpentane 540841 0.0020 10/bbi Permit 11 De Minimis De Minimis 7 Attach condensate liquid laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions: COLORADO wnn�n. RAW Permit Number: 18WE0355 AIRS ID Number: 123 i 9FB0 / 001 Section 10 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. ;tee -- 3/23/2020 Signature of Legally Authorized Person (not a vendor or consultant) Date Alisson Soehner Environmental Engineer, Air Quality Name (print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance Q Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of $312.50, if applicable, to: 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 Small Business Assistance Program (303)692-3175 OR (303)692-3148 APCD Main Phone Number (303) 692-3150 COLORADO c.y.r<mentl of Hah66. rmmn CDPHE Produced Water Storage Tank(s) APEN Form APCD-207 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for tanks that store produced water associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, condensate storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number:. 18WE0355 AIRS ID Number: 123 / 9FB0 / 002 Section 1 - Administrative Information Company Name: Bonanza Creek Energy Operating Company, LLC Site Name: Longhorn 14-11 Production Facility (COGCC #451353) Site Location: SWSW, Section 11, T3N, R63W Mailing Address: (Include Zip Code) 410 17th Street, Suite 1400 Denver, CO, 80202 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Alisson Soehner Phone Number: (303) 803-1752 E -Mail Address2: asoehner@bonanzacrk.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 wilt be issued by the APCD via e-mail to the address provided. 428297 COLORADO twim Permit Number: 18WE0355 AIRS ID Number: 123 / 9FB0 / 002 Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source ❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP05 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $312.50 must be submitted along with the APEN filing fee. - Oft - Q MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name3 Ej Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable lirtiit on Potential To Emit (PTE) Additional Info E Notes: Updating with new throughput and emission limits. 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: Tank battery for storage of produced water prior to being trucked out PWT-01 01/10/2018 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 ❑ Exploration E Production (EEP) site days/week 52 weeks/year ❑ Midstream or Downstream (non EEO) site Will this equipment be operated in any NAAQS nonattainment area? p Yes ■ No Are Flash Emissions anticipated from these storage tanks? Yes ■ No Are these storage tanks located at a commercial facility that accepts oil production wastewater for processing? Yes No • el Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? GI Yes ■ No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)• 805 series rules? If so, submit Form APCD-105. Yes No SI Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual• emissions ≥ 6 ton/yr (per storage tank)? Yes No CI irsCOLORADO x['apartment.m cs..�., Q Upward ❑ Horizontal Permit Number: 18WE0355 AIRS ID Number: 123 / 9FB0 / 002 Section 4 - Storage Tank(s) Information Produced Water Throughput: Actual Annual Amount (bbUyear) 3,650 Requested Annual Permit Limits (bbl/year) 9,125 From what year is the actual annual amount:' Tank design: 0 Fixed roof 2019 ❑ Internal floating roof ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) PWT-01 One (1) 500 bbl 500 12/2017 01/2018 Wells Serviced by this Storage Tank or Tank Batteryb (MP Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 45086 State Longhorn D14-11-12XRLNB ■ ■ ■ ■ 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. 6 The E&P Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.23465; -104.413903 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) ECD-01 35 500 TBD TBD Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) El Circular Interior stack diameter (inches): 96 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): s COLORADO °eph tr& dWq.c ifalU, tr En.vw,v,en Permit Number: 18WE0355 AIRS ID Number: 123 i 9FB0 / 002 Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: ❑ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 0.06 MBtu/hr Type: Enclosed Combustor Make/Model: Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 95 % Minimum Temperature: N/A Crimson Waste Gas Heat Content: 1,496 Btu/scf Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating: N/A MMBtu/hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 - Gas/Liquids Separation Technology Information (E&tP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? —60 Describe the separation process between the well and the storage tanks: psig Well produces to single stage 3 -phase separator where water is separated out and routed to the produced water tank battery. COLORADO .. Heil b 6 8nranmmi Permit Number: 18WE0355 AIRS ID Number: 123 /9FB0/002 Section 8 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form7. Is any emission control equipment or practice used to reduce emissions? Yes ❑ No If yes, describe the control equipment AND state the collection and control efficiencies (report the overall, or combined, values if multiple emission control methods were identified in Section 6): Pollutant Control Equipment Description Collection Efficiency (% of total emissions captured by control equipment) Control Efficiency (% reduction of captured emissions) V0C ECD 10G 95 NOx CO HAPs ECD 100 95 Other: From what year is the following reported actual annual emissions data? 2019 Use the following table to report the criteria pollutant emissions from source: Pollutant Emission Factor? Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (Z. Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissions8 (tons/year) Uncontrolled Emissions (tars/year) Controlled Emissions (tons/year) VOC 0.262 tb/bbl State EF 0.48 0.02 1.20 0.06 NUx 0.0037 Ib/bbl State EF 0.01 0.01 0.02 0.02 CO 0.0167 lb/WA State EF 0.03 0.03 098 0.08 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. 7 Attach produced water laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Section 9 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name Chemical Abstract Service CAS ( Number Emission Factors Actual Annual Emissions Uncontrolled Basis Units Source (AP 42, Mfg., etc.) Uncontrolled Emissions (Ibs/year) Controlled Emissions8 (Ibs/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 2,2,4-Trimethylpentane 540841 Yes ID No 7 Attach produced water laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. COLORADO ee�alNbEn �A�ine.0 Permit Number: 18VVE0355 AIRS ID Number: 123 / 9FB0 i 002 Section 10 - Applicant Certification 1 hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP05 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. 3/23/2020 Signature of Legally Authorized Person (not a vendor or consultant) Date Alisson Soehner Environmental Engineer, Air Quality Name (print) Title Check the appropriate box to request a copy of the: Q Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, ILC. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of $312.50, if applicable, to: 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 Small Business Assistance Program (303) 692-3175 OR (303) 692-3148 APCD Main Phone Number (303) 692-3150 COLORADO at nit+k x.mn a,aa+mxm Gas Venting APEN - Form APCD-211 Air Pollutant Emission Notice (APEN) and Application for Construction Permit Alt sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 18WE0355 AIRS ID Number: 123 / 9FB0 /003 Section 1 - Administrative Information Company Name': Bonanza Creek Energy Operating Company, LLC Site Name: Longhorn 14-11 Production Facility (COGCC #451353) Site Location: SWSW, Section 11, T3N, R63W Mailing Address: 410 17th Street, Suite 1400 {Include Zip Code} Denver, CO, 80202 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Alisson Soehner Phone Number: (303) 803-1752 E -Mail Address2: asoehner@bonanzacrk.com ' Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. `i2829'° COLORADO bpnwen� of Pubib: HrIM 6 4rvvon.Kru Permit Number: 1 8WE0355j AIRS ID Number: 123 / 9F6o / 003 Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source -OR- Q MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit ❑� Change permit limit ❑ Transfer of ownership^ ❑ 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 8 Notes: Updating throughput and emission limits. 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: Produced gas venting controlled by EC',D Company equipment Identification No. (optional): For existing sources, operation began on: 01/10/2018 For new, modified, or reconstructed sources, the projected start-up date is: Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area? Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions? Is this equipment subject to Colorado Regulation No. 7, Section XVII.G? days/week weeks/year ❑Q Yes ❑ No ❑ Yes No Yes ❑ No SC COLORADO Heal. Ewae wdr NWU! mmnmert Permit Number: 18WE0355 AIRS ID Number: 123 / 9Fi30 / 003 Section 4 - Process Equipment Information 0 Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: ❑ Other Description: Serial #: # of Pistons: Volume per event: Capacity: Leak Rate: gall min Scf/hr/pist MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? 0 Yes Gas Venting Process Parameters5: Liquid Throughput Process Parameters5: Vented Gas Properties: ❑ No Vent Gas Heating Value: 1 538 , BTU/SCF Requested: 37.86 MMSCF/year Actual: 37.86 MMSCF/year -OR- Requested: bbl/year Actual: bbl/year Molecular Weight: 27.1 VOC (Weight %) 43.0178 Benzene (Weight %) 0.1412 Toluene (Weight %) 0.1687 Ethylbenzene (Weight %) 0.0257 Xylene (Weight %) 0.0764 n -Hexane (Weight %) 0.9502 2,2,4-Trimethylpentane (Weight %) 0.0006 Additional Required Documentation: O Attach a representative gas analysis (including BTEX 8 n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. g COLORADO EePoRencN at nlbiee Haa1U 6 En.nmmen, Permit Number: 18VVE0355 AIRS ID Number: 123 / 9F80 / 003 Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.23465, -104.413903 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. ©perator Stack iD Na. Discharge Height Above Ground Level (meet} Temp. (•} Flaw Rate , (Acr MI YtEaci#y _ ECD-01 35 500 TBD TBD Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): ✓❑ Upward ❑ Horizontal ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): 96 ❑ Square/rectangle Interior stack width (inches): ❑ Other (describe): Interior stack depth (inches): Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section . ❑ VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency: VRU Downtime or Bypassed: % ❑ Combustion 1 Device: Pollutants Controlled: VOC, HAPs Rating: 6.65 MMBtu/hr Type: Enclosed Combustor Make/Model: Crimson CE 1000 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 % Minimum Temperature: 500 Waste Gas Heat Content: 1,538 Btu/scf Constant Pilot Light: ❑ Yes ❑✓ No Pilot burner Rating: N/A MMBtu / hr ❑ Other: Pollutants Controlled: Description: Requested Control Efficiency: au COLORADO n,�c�r,rn„ak Permit Number: 18WE0355 AIRS ID Number: 123 / 9FB0 / 003 Section 7 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑� Yes ❑ No If yes, describe the control equipment AND state the collection and control efficiencies (report the overall, or combined, values if multiple emission control methods were identified in Section 6): Pollutant Control Equipment Description Collection Efficiency (X of total emissions captured by control equipment) Control Efficiency (X reduction of captured emissions) PM SO. NO. CO VOC ECD 100 95 HAPs ECD 100 95 Other: From what year is the following reported actual annual emissions data? 2019 Use the following table to report the criteria pollutant emissions from source: Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (2r Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissionsb (tons/year) Uncontrolled • Emissions (tonslyear) Controlled Emissions (tons/year) PM 40.0 ug/l AP -42 0.51 0.51 0.51 0.51 SOx 0.00027 Ib/MMBtu AP -42 0.01 0.01 0.01 0.01 NO), 0.068 Ib/MMBtu AP -42 199 1.99 199 1.99 CO 0.310 Ib/MMBtu AP -42 903 9.03 9.03 9.03 VOC 30.782.1 Ib/bbl Permit 11 582 73 29.14 58273 29.14 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (lbs/year) Controlled Emissionsb (Ibslyear) Benzene 71432 101.0 lb/bbl Permit 11 3.926 192 Toluene 108883 120.7 IIAbl Permit 11 4.572 230 Ethylbenzene 100414 18.4 lb/bbl Permit 11 698 36 Xylene 1330207 547 lb/bbl Permit 11 Z070 104 n -Hexane 110543 679.9 lb/bbl Permit 11 25,744 1.288 2,2,4-Trimethylpentane 540841 0.4 Ib/bbi Permit 11 De Minimis De Minimis Other: ❑ Yes ❑ No 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Aso COLORADO Department a. NeKul.6lnrmanirmevm Permit Number: 18WE0355 AIRS ID Number: 123 /9F60/ 003 Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. 3/23/2020 Signature of Legally Authorized Person (not a vendor or consultant) Date Alisson Soehner Environmental Engineer, Air Quality Name (print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance 0 Draft permit prior topublic notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303)692-3175 OR (303) 692-3148 APCD Main Phone Number Make check payable to: (303) 692-3150 Colorado Department of Public Health and Environment ize COLORADO xgamsmoe tr��,.a„MM Hydrocarbon Liquid Loading APEN Form APCD-208 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: TaEt-'" AIRS ID Number: 123 / 9FB0 / 004 Section 1 - Administrative Information Company Name: Bonanza Creek Energy Operating Company, LLC Site Name: Longhom 14-11 Production Facility (COGCC #451353) Site Location: SWSW, Section 11, T3N, R63W Mailing Address: (Include Zip Code) 410 17th Street, Suite 1400 Denver, CO, 80202 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Alisson Soehner Phone Number: (303) 803-1752 E -Mail Address2: asoehner@bonanzacrk.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 428299 ,. COLOR:DO allIP erxdnar Permit Number: TBD AIRS ID Number: 123 /9FB0/004 Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source ❑ Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $312.50 must be submitted along with the APEN filing fee. -OR - ID MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 Change permit limit ❑ Transfer of ownership"' ❑ Other (describe below) - OR ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: construction permit. Updating with new throughput and emission limits. Requesting coverage under traditional 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Condensate IOadout by tank truck Company equipment Identification No. (optional): t_-01 For existing sources, operation began on: 01/10/2018 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? El Yes No ■ Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Yes 0 No ■ Does this source toad gasoline into transport vehicles? Yes ❑✓ No ■ Is this source located at an oil and gas exploration and production site? Yes ❑ No El If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Yes Na O ■ Does this source splash fill less than 6,750 bbl of condensate per year? Yes No GI IN Does this source submerge fill less than 16,308 bbl of condensate per year? ❑ Yes ❑� No illaktirpl COLORADO tkrywramen. aPubl. Melt II0W n+a<n s Enratormtra Permit Number: TBD AIRS ID Number: 123 /9FB0/004 Section 4 - Process Equipment Information Product Loaded: 0 Condensate ❑ Crude Oil ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: 65,700 bbl/year Actual Volume Loaded: This product is loaded from tanks at this faci ity into: tank trucks (e.g. "rail tank cars" or "tank trucks") 65,700 bbl/year If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: N/A Average temperature of bulk liquid loading: N�A F True Vapor Pressure: N/A Psia ® 60 'F Molecular weight of displaced vapors: N/A lb/lb-mot 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: ft'/truckload 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. Section 5 - Geographical/Stack Information Geographical Coordinates (LotitudeJLongitude or UTM) 40.23465,-104.413903 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. r Flow Rate (ACFM) Velocity allsec) ECD-01 35 500 TBD TBD Indicate the direction of the stack outlet: (check one) r❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): 96 ❑ Square/rectangle interior stack width (inches): ❑ Other (describe): Interior stack depth (inches): Permit Number: TBD AIRS ID Number: 123 /9FB0/004 Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. ✓❑ Loading occurs using a vapor balance system: Requested Control Efficiency: 100 % ❑ Combustion 1 Device: Used for control of: VOC, HAPs Rating: 0.03 MMBtu/hr Type: Enclosed Combustor Make/Model: Crimson CE 1000 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 % Minimum Temperature: N/A F Waste Gas Heat Content: 2,450 Btu/scf Constant Pilot Light: ❑ Yes ❑Q No Pilot Burner Rating: N/A MMBtu/hr ❑ Other: Pollutants Controlled: Description: Requested Control Efficiency: 0 Section 7 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ✓❑ Yes ❑ No If yes, describe the control equipment AND state the collection and control efficiencies (report the overall, or combined, values if multiple emission control methods were identified in Section 6): Pollutant Control Equipment Description Collection Efficiency (X of total emissions captured by control equipment) Control Efficiency (% reduction of captured emissions) PM SOX NO. CO VOC ECD 100 95 HAPs ECD 100 95 Other: ❑✓ Using State Emission Factors (Required for GP07) VOC Benzene n -Hexane E] Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL ❑ Crude 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? 2019 Use the following table to report the criteria pollutant emissions from source: Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (AP 41, Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissionsb (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) PM 40 ug/L AP -42 0.002 0.002 0.002 0.002 SOx 0.00023 Ib/MMBtu AP -42 <0.001 <0.001 <0.001 <0.001 NO. 0068 -Ib/MMBtu AP -42 0.010 0.010 0.010 0.010 CO 0.310 Ib/MMBtu AP -42 0.045 0.045 0.045 0.045 VOC 0,236 lb/bbl State EF 777 0.39 7.77 0.39 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. COLORADO no Department m wmm Heal.6 Enwronme t Permit Number: TBD AIRS ID Number: 123 /9FB0/004 Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria 0 Yes pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (tbslyear) Controlled Emissionsb (ibslyear) Benzene 71432 0.00041 lb/lob' State EF De Minimis De Minimis Toluene 108883 N/A N/A N/A NA N/A Ethylbenzene 100414 N/A N/A N/A NIA N/A Xylene 1330207 N/A N/A N/A NIA N/A n -Hexane 110543 0.0036 Ib/bbt State EF De Minimis De Minimis 2,2,4-Trimethylpentane 540841 N/A NIA N/A NIA NIA Other: El No 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP07. 3/23/2020 Signature of Legally Authorized Person (not a vendor or consultant) Date Alisson Soehner Environmental Engineer, Air Quality Name (print) Title Check the appropriate box to request a copy of the: ❑� Draft permit prior to issuance El Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) 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-61 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 4 COLORADO Hello