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Home My WebLink About20202909.tiff „: COLORADO � • ti �,,'� Department of Public U:i Health&Environment RECEIVED SEP 18 2020 WELD COUNTY COMMISSIONERS Weld County - Clerk to the Board 1150O St PO Box 758 Greeley, CO 80632 September 14, 2020 Dear Sir or Madam: On September 15, 2020, the Air Pollution Control Division will begin a 30-day public notice period for Bayswater Exploration and Production LLC - Leffler 13, 14, 23, 24-26NHZ, B-26CHZ, P-26NHZ Tank Battery. 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 6 coo` 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe I c °k•- Jared Polls, Governor I Jill Hunsaker Ryan,MPH, Executive Director Pvb t;G Rev;ec.J cc:PL,.(TP) HL(Ds)PcJ(sM/6R/cat/c ) 2020-2909 09/21/20 oG(3M) , oct/21/2O C . Air Pollution Control Division '" = Notice of a Proposed Project or Activity Warranting Public CDPHE Comment Website Title: Bayswater Exploration and Production LLC - Leffler 13, 14, 23, 24-26NHZ, B-26CHZ, P-26NHZ Tank Battery - Weld County Notice Period Begins: September 15, 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: Bayswater Exploration and Production LLC Facility: Leffler 13, 14, 23, 24-26NHZ, B-26CHZ, P-26NHZ Tank Battery Oil and Gas Well Production Facility NWNW SEC 26 T7N R66W Weld County The proposed project or activity is as follows: Applicant proposes to modify this existing permit to incorporate existing point at the facility (produced water tanks), update existing points at the facility already on the permit (hydrocarbon loadout), and incorporate new points at the facility (Produced water loadout, vapor recovery tower, low pressure separator) The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 14WE0997 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 1 Ig Health b Eavtronn nt CDPHE COLORADO CO V Air Pollution Control Division Department of Public Health&Environment CONSTRUCTION PERMIT Permit number: 14WE0997 Issuance: 4 Date issued: Issued to: Bayswater Exploration Et Production, LLC Facility Name: Leffler 13, 14, 23, 24-26NHZ, B-26CHZ, P-26NHZ Tank Battery Plant AIRS ID: 123/9CD3 Physical Location: NWNW SEC 26 T7N R66W County: Weld County General Description: Well Production Facility Equipment or activity subject to this permit: Facility AIRS Emissions Control Equipment Point Equipment Description Description ID PW-001 - 002 Four (4) 300 bbl fixed roof produced Enclosed combustors PW-004 water storage tanks Condensate loadout from storage TL-001 006 vessels to tank trucks using Enclosed combustors submerged fill. Produced water loadout from storage TL-002 010 vessels to tank trucks using Enclosed combustors submerged fill. VRT-001 011 One (1) vapor recovery tower (VRT) Vapor recovery unit and enclosed combustors LP-SEP-001 012 Fifteen (15) low pressure separators Enclosed combustors 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. CDPHE ( COLORADO t Air Pollution Control Division Page 1 of 14 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, bir 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.gov/cdphe/air/manage-permit. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) 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 must expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. Point 012: Upon issuance of this permit, the operator must install a flow meter to monitor and record volumetric flow rate of natural gas routed to 'the enclosed combustors from all of the low pressure separators covered by this permit. 5. The operator must complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Regulation Number 3, Part B, Section III.E.) 6. The operator must retain the permit final authorization letter issued by the Division, after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. j CDPHE COLORADO 'T '". Air Pollution Control Division Page 2 of 14 EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4) Annual Limits: Facility Tons per Year Emission Equipment AIRS Point ID PM2.5 NO. VOC CO Type PW-001 002 --- 0.1 1.0 0.2 Point PW-004 TL-001 006 --- 1.3 - Point TL-002 010 --- --- 0.4 --- Point VRT-001 011 - 0.2 3.5 0.8 Point LP-SEP-001 012 --- 0.8 10.0 3.7 Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Compliance with the annual limits for criteria 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. 8. 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. 9. 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 AIRS Equipment Point Control Device Pollutants Controlled ID PW-001 002 Enclosed combustors VOC and HAP PW-004 TL-001 006 Enclosed combustors VOC and HAP TL-002 010 Enclosed combustors VOC and HAP VRT-001 011 Vapor recovery unit and enclosed VOC and HAP combustors LP-SEP-001 012 Enclosed combustors VOC and HAP COPHE COLORADO CO �, Air Pollution Control Division r i Page 3 of 14 PROCESS LIMITATIONS AND RECORDS 10. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, Section II.A.4) Process/Consumption Limits Facility AIRS Equipment Point Process Parameter Annual Limit ID PW-001 002 Produced water throughput 1,920,000 barrels PW-004 TL-001 006 Condensate loaded 152,164 barrels TL-002 010 Produced water loaded 1,920,000 barrels VRT-001 011 Condensate throughput - during 128,592 barrels VRU downtime LP-SEP-001 012 Natural gas routed to enclosed 18.25 MMscf combustors The owner or operator shall monitor monthly process rates based on the calendar month. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 11. Point 011: The owner or operator must continuously monitor and record Vapor Recovery Unit (VRU) downtime while emissions are routed to the control device. 12. Point 011: The owner or operator must use monthly VRU downtime records, daily condensate/crude oil throughput records, and the emission factors established in the Notes to Permit Holder to demonstrate compliance with the process and emissions limits specified in this permit. 13. Point 012: Upon issuance of this permit, the owner or operator must continuously monitor and record the volumetric flow rate of natural gas vented from the separator(s) using the flow meter. The flow meter must be calibrated and maintained per the manufacturer's specifications and schedule. The owner or operator must use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 14. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 15. Point 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: CDPH� ' COLORADO Air Pollution Control Division Page 4 of 14 • 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. The combustion device covered by this permit is subject to Regulation Number 7, Part D, Section II.B.2. General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section II, it must be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, Part D, Section II.A.23; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. This flare must be equipped with an operational auto-igniter according to the schedule in Regulation Number 7, Part D, Section II.B.2.d. 17. Point 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 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. Points 006 Et 010: Hydrocarbon liquids loadout from storage tanks to transport vehicles must be controlled by using (a) submerge fill and (b) a vapor collection and return system and/or air pollution control equipment. Compliance with Section II.C.5. must be achieved in accordance with the following schedule: (Regulation Number 7, Part D, Section II.C.5.a.) a. Facilities constructed or modified on or after May 1, 2020, must be in compliance by commencement of operation. b. Facilities constructed before May 1, 2020, must be in compliance by May 1, 2021. c. Facilities not subject to Sections II.C.5.a.(i)(A) or II.C.5.a.(i)(B) that exceed the hydrocarbon liquids loadout to transport vehicles throughput of greater than or equal to 5,000 barrels per year on a rolling 12-month basis must control emissions from loadout upon exceeding the loadout threshold. CDPHEler COLORADO I Par Pollution Control Division Page 5 of 14 20. Points 006 & 010: Storage tanks must operate without venting at all times during loadout. (Regulation Number 7, Part D, Section II.C.5.a.(ii)) 21. Points 006 Et 010: The owner or operator must, as applicable (Regulation Number 7, Part D, Section II.C.5.a.(iii)): a. Install and operate the vapor collection and return equipment to collect vapors during the loadout of hydrocarbon liquids to tank compartments of outbound transport vehicles and to route the vapors to the storage tank or air pollution control equipment. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Use operating procedures to ensure that hydrocarbon liquids cannot be transferred to transport vehicles unless the vapor collection and return system is in use. d. Operate all recovery and disposal equipment at a back-pressure less than the pressure relief valve setting of transport vehicles. e. The owner or operator must inspect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or vapor loss during loadout. These inspections must occur at least monthly, unless loadout occurs less frequently, then as often as loadout is occurring. 22. Points 006 & 010: The owner or operator must perform the following observations and training (Regulation Number 7, Part D, Section II.C.5.a.(iv)): a. The owner or operator must observe loadout to confirm that all storage tanks operate without venting when loadout operations are active. These inspections must occur at least monthly, unless loadout occurs less frequently, then as often as loadout is occurring, b. If observation of loadout is not feasible, the owner or operator must document the annual loadout frequency and the reason why observation is not feasible and inspect the facility within 24 hours after loadout to confirm that all storage tank thief hatches (or other access point to the tank) are closed and latched. c. The owner or operator must install signage at or near the loadout control system that indicates which loadout control method(s) is used and the appropriate and necessary operating procedures for that system. d. The owner or operator must develop and implement an annual training program for employees and/or third parties conducting loadout activities subject to Section II.C.5. that includes, at a minimum, operating procedures for each type of loadout control system. 23. Points 006 & 010: The owner or operator must retain the records required by Regulation Number 7, Part D, Section II.C.5.a.(v) for at least two (2) years and make such records available to the Division upon request. • a. Records of the annual facility hydrocarbon liquids loadout to transport vehicles throughput. CDPHE COLORADO 0 wir Air Pollution Control Division Page 6 of 14 b. Inspections, including a description of any problems found and their resolution, required under Sections II.C.5.a.(iii) and II.C.5.a.(iv) must be documented in a log. c. Records of the infeasibility of observation of loadout. d. Records of the frequency of loadout. e. Records of the annual training program, including the date and names of persons trained. 24. Points 006 £t 010: 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. Points 011 £t 012: The separator covered by this permit is subject to Regulation 7, Part D, Section II.F. On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the commencement of operation by air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. 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 Ft MAINTENANCE REQUIREMENTS 27. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division • approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 28. Point 012: The owner/operator must complete an initial site specific extended gas analysis ("Analysis") within one hundred and eighty days (180) after commencement of operation or issuance of this permit, whichever comes later, of the natural gas vented from this emissions unit in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream. Results of the Analysis must be used to calculate site-specific emission factors for the pollutants referenced in this permit (in units of lb/MMSCF gas vented) using Division approved methods. Results of the Analysis must be submitted to the Division as part of the self-certification and must demonstrate the emissions factors ,j COPH•E ; COLORADO + Air Pollution Control Division . _ Page 7 of 14 established through the Analysis are less than or equal to, the emissions factors submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site-specific emissions factor developed through this Analysis is greater than the emissions factors submitted with the permit application and established in the "Notes to Permit Holder"the operator must submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address these inaccuracies. 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. All previous versions of this permit are cancelled upon issuance of this permit. 31. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, Section II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NO. per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted. For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 32. The requirements of Colorado Regulation Number 3, Part D shall apply at such time that any stationary source or modification becomes a major stationary source or major modification solely by virtue of a relaxation in any enforceable limitation that was COPHE COLORADO y Air Pollution Control Division Page 8 of 14 established after August 7, 1980, on the capacity of the source or modification to otherwise emit a pollutant such as a restriction on hours of operation (Regulation Number 3, Part D, V.A.7.B). GENERAL TERMS AND CONDITIONS 33. 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. 34. 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. 35. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 36. 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. 37. 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. 38. 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. 39. 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, CDPHE COLORADO CO Air Pollution Control Division " Page 9 of 14 civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Christopher Kester Permit Engineer Permit History Issuance Date Description Issuance 1 September 24, Issued to Synergy Resources Corporation. 2014 Issuance 2 July 12, 2018 Issued to Bayswater Exploration Et Production, LLC. Modified permitted throughput and emission factors. Issued as final approval. Issuance 3 April 2, 2019 Issued to Bayswater Exploration a Production, LLC Addition of control device to control loadout emissions. Increase requested throughput from 46,000 bbl/year to 55,200 bbl/year. Issue as initial approval. Issuance 4 This Issuance Issued to Bayswater Exploration Et Production, LLC Modification of Point 003 Addition of Point 002, 006, 010, 011 a 012 CDPHE COLORADO Air Pollution Control Division Page 10 of 14 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 Uncontrolled Controlled Point Pollutant CAS # Emissions Emissions (lb/yr) (lb/yr) Benzene 71432 649 32 002 Toluene 108883 470 23 n-Hexane 110543 782 39 006 n-Hexane 110543 291 28 Benzene 71432 375 19 011 Toluene 108883 348 17 n-Hexane 110543 2,602 130 Benzene 71432 1,198 60 Toluene 108883 1,567 78 012 Xylenes 1330207 729 36 n-Hexane 110543 9,268 463 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. CDPHE COLORADO Air Pollution Control Division Page 11 of 14 5) The emission levels contained in this permit are based on the following emission factors: Point 002: Uncontrolled Controlled CAS # Pollutant Emission Factors Emission Factors Source lb/bbl lb/bbl VOC 0.019912 0.0009956 71432 Benzene 0.000338 0.0000169 Flash liberation 108883 Toluene 0.000245 0.0000122 sample analysis 110543 n-Hexane 0.000408 0.0000204 Note: The controlled emissions factors for this point are based on a control efficiency of 95%. Point 006: Uncontrolled Controlled Pollutant CAS # Emission Emission Source Factors Factors lb/bbl lb/bbl VOC 0.1707 0.00853 AP-42 Chapter 5.2 n-Hexane 110543 0.00191 0.00010 Equation 1 The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46*S*P*M/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 4.2 psia M (vapor molecular weight) = 66 lb/lb-mol T (temperature of liquid loaded) = 509.9 °R Controlled emission factors are based on a combined control efficiency of 90.25%. The combined efficiency accounts for an enclosed combustor efficiency of 95% and a collection efficiency of 95%. The combined control is calculated as follows: Combined Efficiency = (0.95)*(0.95)*100 = 90.25%. Point 010: Uncontrolled Controlled Pollutant CAS # Emission Emission Source Factors Factors lb/bbl lb/bbl VOC 0.00341 0.000333 AP 42 Chapter 5.2 Equation 1 The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46*S*P*M/T* (weight fraction of VOC) S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 4.2 psia M (vapor molecular weight) = 66 lb/lb-mol T (temperature of liquid loaded) = 509.9 °R Weight fraction of VOC = 0.02 isk COLORADO CO Y Au Pollution Control Division Page 12 of 14 Controlled emission factors are based on a combined control efficiency of 90.25%. The combined efficiency accounts for an enclosed combustor efficiency of 95% and a collection efficiency of 95%. The combined control is calculated as follows: Combined Efficiency = (0.95)*(0.95)*100 = 90.25%. Point 011: Uncontrolled Controlled CAS # Pollutant Emission Emission Source Factors Factors (lb/bbl). (lb/bbl) VOC 1.0724 0.0538 Promax simulation 71432 Benzene 0.00288 0.00014 based on upstream 108883 Toluene 0.00271 0.00014 pressurized 110543 n-Hexane 0.02035 0.00102 sample analysis Note: The controlled emissions factors for this point are based on a control efficiency of 95%. Point 012: Uncontrolled Controlled CAS # Pollutant Emission Emission Source Factors Factors (lb/MMscf) (lb/MMscf) NOx 0.068 lb/MMBtu 0.068 lb/MMBtu AP 42 CO 0.31 lb/MMbtu 0.31 lb/MMbtu VOC 21,599.5 1079.97 71432 Benzene 65.64 3.282 Representative gas 108883 Toluene 85.86 4.293 1330207 Xylene 39.97 1.998 sample analysis 110543 n-Hexane 507.83 25.391 Note: The controlled emissions factors for this point are based on a control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five- year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: CO, NOx Et VOC NANSR Synthetic Minor Source of: NOx a VOC PSD Synthetic Minor Source of: CO cDPME COLORADO Air Pollution Control Division Page 13 of 14 8) 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, Appendix A - Appendix I Appendixes Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ- Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980-End Subpart NNNNN - Subpart XXXXXX cDP' COLORADO co i Air Pollution Control Division Page 14 of 14 • Colorado Air Permittolig Project PRELIMINARY ANALYSIS-PROJECT SUMMARY Project Details For Division Use Only Review Engineer: Christopher Kester Package#: 431465 Received Date: 5/5/2020 Review Start Date: /7/2020 Section 01-Facility Information Company Name: Bayswater Exploration and P:ducthon Quadrant Section Township Range County AIRS ID: 123 NWNW 26 7N 66 Plant AIRS ID: 9CD3 Facility Name: Leffler 13,14,23,?4 .;Is t?? 2aiHZ,P-?6501 Tank Batter¢ _ , t Physical Address/Location: -. County: Weld County Type of Facility: Exploration&Production Well Foe. What industry segment?006 Natural Gas Production&Processing Is this facility located in a NAAQS non-attainment area? Yes If yes,for what pollutant? Ozone(NOx&000) Section 02-Emissions Units In Permit Application Leave Blank-For Division Use Only Permit# AIRS Point# Emissions Source Type Equipment Name Emissions (Leave blank unless Issuance Self Cart Action Engineering Control? APCD has already # Required? Remarks assigned) Originally Permit permitted with _.._ Storage Tank TK-001-TK-014 Yes 0.605. Modification GP66 Origirinily Permit permitted with 002 Storage Tank PW-001-PW-004 Yes ."=c? 4 Yes Modification GPO8 Permit .Condensate. 006 Liquid Loading TL-001 Yes 14WE09P; 4 Yes Modification Loaodut Permit Initial New Point-PW 010 , Liquid Loading - TL-002 - - Yes 14W00997 4 Yes issuance Loadout Permit Initial 011 Separator Venting - VRT-001 Yes 14W60497 4 Yes Issuance New Point Permit Initial 012 Separator Venting LP-SEP001 Yes __t 4 Yes - Issuance New Point Section 03-Description of Project Addition of se-e:a: ;so nts to the facility wide pers , Sections 04,05&06-For Division Use Only Section 04-Public Comment Requirements Is Public Comment Required? Yes If yes,why? R=questing Synthetic Minor Pe raft Newly permitted points must go through public comment. Section 05-Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? ic. If yes,for what pollutants? If yes,attach a copy of Technical Services Unit modeling results summary. Section 06-Facility-Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes,indicate programs and which pollutants: SO2 NOx CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration(PSD) 000000 Title V Operating Permits(OP) O ® O Q O O ❑ O Non-Attainment New Source Review(NANSR) II Is this stationary source a major source? Nu If yes,indicate programs and which pollutants: SO2 NOx CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration(POD) ❑ ❑ ❑ ❑ O O Title V Operating Permits(OP) 00000 000 Non-Attainment New Source Review(NANSR) ❑ 0 Storage Tack(s)Emissions inventory Section 01-Administrative Information 'Facility AlRs ID: 323 9(1)3n13'2 County Plant Point Section 02-Equipment Description Details Storage Tank Liquid Detailed Emissions Unit Four(4)300 bb pr8Pused water storage tanks - " Description: --`'i Vic . . _ �.. Emission Control Device - Enclosed Cu star Description: Requested Overall VOC&HAP Control Efficiency%: Limited Process Parameter \ xr un Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Storage Tanks) Actual Throughput= :1,083.9 Barrels(bbl)per year Requested Permit LimitThroughput= 7,920,000.0 Barrels(bbl)per year Requested Monthly Throughput= 0030'035 Barrels(hbl)per month Potential to Emit(PTE)Condensate Throughput= 1;900,000.Barrels(bbl)per year Secondary Emissions-Combustion Device(s) Heat content of waste gas= 1469.0 Btu/scf Volume of waste gas emitted per BBL of liquids produced= 0.5 scf/bbl Actual heat content of waste gas routed to combustion device= .3 MMBTU per year Requested heat content of waste gas routed to combustion device= MMBTU per year Potential to Emit(PIE)heat content of waste gas routed to combustion device= MMBTU per year Control Device Pilot Fuel Use Rate: scth _.0 MMscf/yr Pilot Fuel Gas Heating Value: Btu/scf MMBTU/yr Section 04-Emissions Factors&Methodologies Will this storage tank emit flash emissions? tit Emission Factors Produced Water Tank Uncontrolled Controlled Pollutant (lb/bbl) (lb/bbl) Emission Factor Source (Produced Water (Produced Water Throughput) Throughput) VOC 0.01991E S °' nei4des flash) 3'-,." Benzene Toluene S Ethylbenzene 00000154 }-ud5lne ., Xylene 0.0000904 ;2?G. > n-Hexane 0.00(14075 @)uda hash) 224 TMP 0.0000000 .r_O S �pNdes{last+) -.- Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) (lb/bbl) Emission Factor Source (waste heat (Produced Water combusted) Throughput) PM10 ,0.9570 -'CO2 r ` PM2.5 o 6.It 0 : SOx C t Tfr40£1G kaWatirrni2M ,.s. NOx r %'00680 --5 { Pilot Light Emissions Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (lb/MMscf) Emission Factor Source (Pilot Gas Heat (Pilot Gas Combusted) Throughput) PM10 )OciL a. PM2.5 C.O030 SOx C0,3- 0.3400 NOx 0.Cr;F4 0,0000 VOC 4.00,4 0.0000 _. S CO 0.31D0 0.0000 Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lhs/month) PM10 _.. 0,00,C 6 0 0.' PM2.5 0 9 0.0 03,3 0.0 0.3 SOx 0.0 0.0 00 30 C _., NOx 0.0 0.0 _._ 0.3 ._ 3.1 VOC 19-1 0.0 _._ _... ..,._ CO 0.2 0.' _._ 31.1 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ihs/year) (lbs/year) (Ibs/year) (lbs/year) (lbs/year) • Benzene 640,0 9.40 0 040 Toluene 400.0 0.3 -._ 430 Ethylbenzene 37.3 0.0 00 37 _ 2 of 22 K:\PA\2014\14WE0997.CP4 Storage Tank(s)Emissions inventory Xylene 131.4 0.1 0.0 131 7 n-Hexane 782.4 0.4 0.0 782 19 224TMP 0.0. 0.0 00 0 0 • 3 of 22 K:\PA\2014\14WE0997.CP4 Section 06-Regulatory Summary Anal sis Regulation 3,Parts A,B ..-. .,.- Regulation 7,Part D,Section I.C,D,E,F .. Regulation 7,Part D,Section LG,[ Regulation 7,Part D,Section II.B,C.1,C.3 Regulation 7,Part D,Section II.C.2 - - Regulation 7,Part D,Section II.C.4.a.(i) ._ .. Regulation 7,Part D,Section II.C.4.a.(ii) .. Regulation 6,Part A,NSPS Subpart Kb s,. ,_ , , Regulation 6,Part A,NSPS Subpart 0000 I-is r..- to NSPS O. NSPS Subpart 0000a is LAMPS 0000.. Regulation B,Part E,MACT Subpart HH Ee-S . xank is not subvert.#.; , (See regulatory applicability worksheet far detailed analysis) Section 07-Initial and Periodic Sampling and Testing Requirements For condensate or crude oil tanks,does the company use the state default emissions factors to ---- estimate emissions? 600 _ If yes,are the uncontrolled actual or requested emissions for a crude ail 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? Yesr If yes and if there are flash emissions,are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted(for produced water tanks,a pressurize liquid sample must be analyzed using flash liberation analysis)?This sample should be considered representative which generally means site-specific and collected within one year of the application received date.However,if the facility has not been modified(e.g.,no new wells brought on-line),then it maybe appropriate to use an older site-specific sample. Yes If no,the permit will contain an"Initial Compliance"testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03. Does the company request a control device efficiency greater than 95%for a flare or combustion device? If yes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02 Section 08-Technical Analnui N tes M,. o. . Section 09-SCC Coding and Emissions Facto.(Far Inventory Use Only) Uncontrolled Emissions AIRS Point# Process# SCC Code Pollutant Factor Control% Units 9i 01 -18 Fixed Roof Tank.Prod }Water.warturveheathm9aBashtog losoes _ PM10 2.C=' R lb/1,000 gallons Produced Water throughput PM2.5 n_C 1611,000 gallons Produced Water throughput SOx rte---. lb/1,000 gallons Produced Water throughput NOB lb/1,000 gallons Produced Water throughput VOC ., Ile/1,000 gallons Produced Water throughput CO lb/1,000 gallons Produced Water throughput Benzene lb/1,000 gallons Produced Water throughput Toluene _. lb/1,000 gallons Produced Water throughput Ethylbenzene .,, lb/1,000 gallons Produced Water throughput Xylene lb/1,000 gallons Produced Water throughput n-Hexane lb/1,000 gallons Produced Water throughput 224 TMP f.i -_ lb/1,000 gallons Produced Water throughput 4 of 22 K:\PA\2014\14W E0997.CP4 Separator Vent ng Emissions Inventory Section 01-Administrative Information - _ (Facility AlRs ID: 123?; " 9CD3 002 - County Plant Point Section 02-Equipment Description Details - Detailed Emissions Unit Description: 'flash Ltberati Anu1ysis e _ _, >_x... . Emission Control Device Description: s ,�_ f ,�� - a „� Requested Overall VOC&HAP Control Efficiency%: Limited Process Parameter �t-s, �_,y 'a Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Separator Actual Throughput= "Barrels(bbl)per year Requested Permit Limit Throughput= 1320,&30.0 Barrels(bbl)per year Requested MonthlyThroughput= -.:.,^a8.5 Barrels(bbl)per month I Potential to Emit(PTE)Throughput= _ Barrels(bbl)per year Secondary Emissions-Combustion Devices)for Air Pollution Control Separator Gas Heating Value: 1459,0 Btu/scf Volume of waste gas emitted per BBL of liquids throughput: 0.5 scf/bbl Control Device Pilot Fuel Use Rate: scfh 3. MMscf/yr Pilot Fuel Gas Heating Value: Btu/scf Section 04-Emissions Factors&Methodologies \ et*;rAft%:t2NARPat,;j,igitfbVj17:atf,Zqg/A, 42iNgAtrfigickiVinriglitatfi51,3Siit," Description fi s .... ^-,.., MW I _r.o Ib/Ib-mol Displacement Equation Ex=Q'MW Kx/C Weight% Helium 0.0 CO2 1 I N2 methane __,_ ethane _:.. propane __._ isobutane . - n-butane isopeetane n-pentane - ..= cyclopentate 9.. n-Hexane cydohexane3 a - _ Other hexane- __ heptanes m ethylcycloh exa n e ..... 224-TM P ...t- Benzene Toluene - Ethylbenzene , • Rylenes CS+Heavies -_- Total VOC Wt% 5 of 22 K:\PA\2014\14WE0997.CP4 • Separator Venting Emissions Inventory Emission Factors Separator Venting Uncontrolled Controlled (lb/bbl) (lb/bbl) Emission Factor Source Pollutant • (Liquid Throughput) (Liquid Throughput) VOC Benzene Toluene Ethylbenzene Xylene n-Hexane 224 TMP Primary Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) lb/bbl Emission Factor Source (Waste Heat Combusted) (Gas Throughput) PM10 PM2.5 _ a __ SOx NOx _ `*• CO Pilot Light Emissions - Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) lb/MMscf Emission Factor Source (Waste Heat Combusted) (Pilot Gas Throughput) PM10 PM2.5 ` SOx VOC Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (Ibs/month) PM10 _._ 0.0 0.0 0,3 0 PM2.5 633 U. 0.2 8.0 0.0 0 SOx 0.0 0u ..,, / 0.0 =3.0 'n NOx 9.0._ 0A 0.3 0 VOC 1331 .02 _.. 19.0 10 1. 3207 CO ��.-3 8.0 _ Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (Ibs/year) (Ibs/year) (Ibs/year) (Ibs/year) Benzene SOO 0 0 349 0,111 Toluene .. 0 470 311 Ethylbenzene 37 '0 0 37 37 Xylene 131. - . :131 .171 n-Hexane 782 _ 0 700 752 224TMP 0 0 0 U of 22 K:\PA\2014\14WE0997.CP4 Storage Tank Regulatory Analysis Worksheet The regulatory requirements below ore determined based on requested emissions. Colorado se latign 3 Parts A and a-APEN and Permit ReouiremerR. � ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY(Regulation 3,Part A,Section ll.O;la)7 Source Requires an APEN.Gate 2. Produced Water Tanks have nograndfathering provisions Go to next question 3. Are totalfacilfy uncontrolled VOC emissions greater than 5 TPY,NOK greater than 10 TPA or CO emissions greater than OOTPY(Regulation 3,Part 8,Section ll.D.3)7 Source Requires a permit :...:" ,.,..t".n.en.A., NON-ATTAINMENT 1. Are uncontrolled emissionsfram any criteria pollutants from this individual source greater than 1TPY(Regulation 3,Part A,Section ll.D 1/ ,OW °at Source Requires an APEN.Go to at 2, Produced Water Tanks have nograndfathering provisions -- ; 3. Are total facility uncontrolled VOC emissions greater than 2TPY,NOx greater than S WY or CO emissions greater than 10 TPY'Regulation 3,Part 8,Section 11.0,2)7 V ='=Source Requires a permit Colorado Regulation 7,Part 0,Section I.C-F&G 1. Is thhstoagetank located in the 8-hr ozone control area or any none nomartainment ems or attainment/maintenance area(Regulation 7,Part D,Sectionl.A.1]? cc Continue-You have indicated th 2. Is this storage tank located atoll and gas operations that collect,store,or handle hydrocarbon liquids or produced water AND that are located at or upstream of a natural gm processing piant(Regulation 7,Part D,Section 1.4.1)7 ros Continue-You have indicated th 3. Is this storage tank located at a natural gas processing plant(Regulation 7,Part I,Section 1.01? n Storage Tanks not subject to Re 4. Does this storage tank contain condensate? _, 5. Does th's storage tank exhibit"Flash"(e.g.storing non-stabilized liquids)emissions(Regulation 7,part I,Section 1.0.2)7 6. Are uncontrolled actual emissions of this storage t k equal to or greater than 2 tans per year VOC(Regulation 7,Part D,Section l.D.3.alf/l? Yom: Part 0,Section l.C.1—General Requirements for Air Pollution Control Equipment—Prevention of Leakage Part 0,Section I.C.2—Emission Estimation Procedures Part D,Section I.0—Emissions Control Requirements • Part 0,Section 1.E—Monitoring Part a,Section I.F—Recordkeeping and Reporting Part 0,Section I.G.2-Emissions Control Requirements Part 0,Section I.C.l.a and b—General Requirementsfor Alr Pollution Control Equipment—Prevention of Leakage Colorado Regulation 7.Part 0.Section II 1. Is this storegetanklacated at a transmission/storage facility? Corrtinue-You have indicated th 2. Is this storage tanks located at an oil and gas exploration and production operation,well production facility?,natural gas compressor station'or natural gas processing plant°(Regulation 7,Part D,Section II.CI? Go to the next question-You ha 3. Doesth'e storage tank have a fixed roof(Regulation 7,Part D,Section ll.A.2017 ..T)W Go to the nest question 4. Are uncontrolled actual emRsionsofths storagetank equal to or greater than 2tons per year VOC(Regulation 7,Part!),Section/1.01.0)? ijgg+/ Pt Source ssublect to parts of Reg Part D,Section II.B-General Provisions for Air Pollution Control Equipment and Prevention of Emiss/ons Pert D,Section II.C.1-Emissions Control and Monitoring Provisions Part 0,Section II.C.3-Recordkeeping Requirements 5 Does the storage k containonly astabiliree liquids(Regulation 7,Part D Seotian l/.C.2.b17 IRicAllROISource is subject to all provision. [ Part D,Section 11.0.2-Capture and Muttering for Storage Tanks fitted with Air Pollution Control Equipment Is the controlled storage tank located ate well production facility,natural gas compressor station,or natural gas processing plant constructed an or after May 1,2020 or located at a facility that was modified on or after May 1,2020,such -:".'='"l 6. that an additional controlled storage Io constructedto receive an anticipated increase in throughput of hydrocarbon liquids or produced water(Regulation 7,Part D,Section II.C4.a.IiI? Pa/u' '`Storage Tank s not subject to Re Is the controlled storage tank located at a well production facility,natural gas compressor station,or natural gas processing plant constructed an or after January 1,2021 or located at a fadlity that was modified on or after January 1, µ� 7. 2021,such that an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of hydrocarbon liquids or produced water(Regulation 7,Part I,Section II.C.4.a.)li)? ?701alll� 40 CFR,Part Ot.Subpart Kb,Standards of Performance for Volatile Organic Liquid Storage Vessels 1. le the individual storage vessel capacity greater Thee or equal to 75 cubic meters(m')I-472(313Ls](4D CFR 60.110b(a))7 I iud/'vfi+(Storage Tank s not subject NSP6 2. Deas the storage vessel meet the following exemption in 60.111b(d)14)7 A:f?„ a.Does the vessel has a design capacity less than or equal to 1,589.874 ma[`10,000 BBL]used for petroleum'or condensate stored,processed,or treated priorto custodytransferz as defined in 60.11167 3. Wes this storage vessel constructed,reconstructed,or modified)see definitions 40 CFR,60.2)after July 23,1984140 CFR 60.110b(a))T • 3 _ 4. Does the tank meet the definition of"storage vessel'/n 60.11167 5. Does the storage vessel store a"volatile organic liquid(VOLI"sas defined in 00.11/b? 6. Does the storage vessel meet any one of the following additional exemptions: a.Is the storage vessel a pressure vessel designed to operate in excess of 204.9 kpa(-29.7mi]and without emissions totheatmosphere(60.110b(d)(2))7;orb.The design capacity/s greater than or equal to 151 ma(-950 BBL)and stores a liquid with a maximum true vapor pressures less than 3.5 lPa(60.110b(b))7;or ± , • c.The design capacry is greater than or equal to 75 M'(-472 BBL]but less than 151 m'[-950 BBL]and stores a liquid with a maximum true vapor pressure"less than 55.0 kPa(60.110blbl)7 7. Does the storage tank meet either one of thefollowing exemptions from control requirements: :£ a.The design capacity is greater than or equalto 151 m'[-950 BBL]and stores a liquid with a maxmum true vapor pressure greater than or equal to 3.5 bra but less than 5.2 kPa?;or b.The design capacity is greater than or equal to 75 Ma(-472 BBL]but less than 151 ma[-950 BBL]and stores a liquid with a maximum true vapor pressure greater than or equal to 15.0 bra but less than 27.6',Pa? 90 CFR,Part 60,Subpart0000/0000a,Standardsof Performance for Crude all and Natural Gas Production,Tansmissinn and Distribution 1. lothis 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? Continue-You have Indicated th 2. Was this storage vessel constructed,reconstructed,or modified(see definitions 90 CFR,60.2)between August 23,2011 and September 18,2015? - YM?"f;:F':'sate the question 4. 3. Was this storage vessel constructed,reconstructed,or modified(see definition 40 CFR,60.21 after September IA,20157 (fs V"?e`='E Go tothe next quest/on 4. Are potential VOC emissions'from the individual storage vessel greater than or equal to 6 tons per year? "R4A+i:S/'v)'Storage Tanks not subject NSP' 5. Does oho storage vessel meet the definition of"storage vessels per 00.5430/60.5430a7 6. Is the storage vessel subject to and controlled In accordance with requirements for storage vessels in 40 CFR Part 00 Subpart Kb or 40 CFR Part 53 Subpart HH7 - .v.. [Nate:If a storage vessel is previously determined to be subject to MPS 0000/0000a duets emisslonabove 6 tans per year 005 an the applicability determination date,it should remain subject to NSPS 0000/0000a per 60.5365(e))2)/60.5365a(e)(2)even if potential VOL emissions drop below 6 tons per year] 40 cFR,Part 63,Subpart MALT HH,OII and Gas Product/on Facilities 1. Is the storage tank located at an oil and natural gas production facility that meets either of the fallowing criteria: ' 'Continue-You have indicated th a.Afacility that processes,upgrades or stores hydrocarbon liquids'(63.760(")(211;OR b.A facility that processes,upgrades or storm natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or 6 delivered to atinal end user'(63.760(a)(3))located2. Is the tank located at a facility that majors for Intro? lik0:.a)Storage Tank is not subject MAC 3. Does the tank meet the definition of"storage vessel"°in 63.7617 • i�u4;:js* 4. Does the tank meet the definition of"storage vessel with the potential for flash emission"'per 63.761? 5 Is the tank subject to control requirements under 40 CFR Part 60,Subpart Kb or Subpart 0000? vT pyx; Subpart A,General provisions per§63.]64(a)Table 2~` §63.766-Emissions Control Standards 563.773-Monitoring §63.774-Recordkeeping §63.775-Reporting RACT Review PACT review is required IF Regulation 7 does not apply AND ifthe tank is In the non-attainment area.If the tank meets bath criteria,then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act,its implementing regulations,and Air Quality Control Commission regulations.This document is not a rule Deregulation,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, end Air Qualify 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 APCC interpretations and recommendations.Mandatory terminology such as"must"and"required"are intended to describe controlling requirements under the terms of tie Clean Air Act end Air Quality Control Commission regulations,but this document does not establish legally binding requirements stand of itsolf. Hydrocaruon Loadout Emissions Inventory Section 01-Administrative Information - - 'Facility AIRs ID: 2002 r1' 7?`?.2 Viw. • ,.. " PSx. *.- ..000 County Plant Pmt Section 02-Equipment Description Details - - Deta led Em ssi stint i;y1 Dadc737 d ' H 6.7'71D cD66770.'sc,, si$44.6tDtvatD6S-44,64D7AF4D6W40706'1D0 Description: � '3, Emission Control Device Description: I 6 _.s'.I-S 6'€ 6`t ,.4 Is this loadaut controlled? Cr0,000.2.0":00.2 02020* Requested Overall VOC&HAP Control Efficiency/: faii* Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Hydrocarbon Loadout Actual Volume Loaded= ��o-` , "£Barrels(bbl)per year 'RequestedPermitLimitThroughput= p 12,&01 Barrels(bbl)per year Requested Monthly Throughput= 12524 Barrels(bbl)per month Potential to Emit(PTE)Volume Loaded= az. :°' " Barrels(bbl)per year Secondary Emissions-Combustion Device(s) Heat content of waste gas= zr 4 Btu scf Actual Volume of waste gas emitted per year= _.._7 scf/year Requested Volume of waste gas emitted per year= 200190 scf/year Actual heat content of waste gas routed to combustion device= 7 MMBTU per year Requested heat content of waste gas routed to combustion device= 343 MMBTU per year Potential to Emit(PTE)heat content of waste gas routed to combustion device= 36-D MMBTU per year Control Device Pilot Fuel Use Rate: 2'T scfh C:'MMscf/yr Pilot Fuel Gas Heating Value: 0,0 ,., .0'„ .,x 1Btu/scf Z MMBTU/yr Section 04-Emissions Factors&Methodologies Does the company use the state default emissions factors to estimate emissions? Are the emissions factors based one stabilized hydrocarbon liquid sample drawn et the facility being permitted? Loading Loss Equation L=12.46'5'P*M/T Factor Meaning Value Units Source 5 Saturation Factor *0 ` PfR 21AA ;*-2 ,,,a F ,D FDD P True Vapor Pressure .,2 psis att:fil-2 M Molecular Weight of Vapors E:9 Ib/lb-mel 6P-77 Fasie 7.i-1 Liquid Temperature CODS Rankine `Dent„C4 Loading Losses .. lb/1000 gallons lb/bbl Component Mass Fraction Emission Factor Units Source Benzene n009FM 100 Fs lb/bbl FF66F 76666-st 66 Toluene 3.02,,.=74 _ v lb/bbl Ethylbenzene t.€7i .. -,n lb/bbl7766-> s Xylene ..CSSI..h 13 ;._E za lb/bbl n-Hexane 7-667,7-637-67; . __lb/bbl K -h� 224 TMP C._.-t{3>^,F7 Ib/bbl .,,r,s6,76D666s6Dos Hydrocarbon Loadout —-. Uncontrolled Controlled Emission Factor Source Pollutant (lb/bbl) (lb/bbl) (Volume Loaded) (Volume Loaded) =ERR=7.03WPM741'5•ZZ-40,1tre5M21.Wrq MIIMEREIrz [,X,40.014.._„:4000tAftV.,40'00Ziit,,,5',A=A.42) Control Device Pollutant Emission Factor Source (Ib/MMBW) (lb/bbl) • (waste heat combusted) (Volume Loaded) C3t: 3'fiS DAMS 76%83 =MERE t.7,1DirDiD401,,D7SSIIVDDADD5416-3006,4 MIIMEMM D31 DD 146VittareitatittiffiltAigl Pilot Light Emissions Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) (Ib/MMscf( Emission Factor Source (Pilot Gas (Waste Heat Combusted) Throughput) :13111 1,02'1•Yfili!'",§14'4"40W1444:31k0Rt:01 MIEN=0•ZiFfirtatS521P0V00N90WAt045W1:3 9 of 22 K:\PA\2014\14WE0997.CP4 Hydrocarbon L Clad t:a rfr(sc r sen's'o7yr Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month) PM10 ... ._., -0155 9.r,0 CO-- _ PM2.5 ..._ v.0 0.00 G.0 ,. SOx NOx .._ 070 0.01 0." - VOC 9._.. 12.99 1.27 -.a{ CO "-._ ., 0.05 '3.O0 fs Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ihs/year) (Ibs/year) (lbs/year) pbs/years Ilbs/ycarl Benzene .. so Toluene _., 0 2 Ethylbenzene v _ 2 C Xylene a n-Hexane 5 29' __ 224 TMP . 0 p 1 Section 06-Regulatory Summary Analysis Regulation 3,Parts A,B Regulation 7 Part D Section II.C.5. s/dre.: _ .-source is subject to Regisiesion 7 Part D Section 0.25. (See regulatory applicability worksheet for detailed analysis) Section 07-Initial and Periodic Sampling and Testing Requirements • om . 84 .6. Does the company request a control device efficiency greater than 95%for a flare or combustion device? 4 If yes,the permit will contain initial and periodic compliance testing in accordance with P5 Memo 20-02 Section 08-Technical Analysis Notes • • Section 09-5CC Coding and Emissions Factors(For Inventory Use Only) Uncontrolled Emissions AIRS Point# Process ft SCC Code Pollutant Factor Control% Units 006 01 0.8647'1-J2 5.10,0.22 25,1 25-5,b,-23-2-001 3,01,0g 1;2,n. u_S PM10 ... lb/1,000 gallons transferred PM2.5 -800 8 lb/1,000 gallons transferred 50x t',0 lb/1,000 gallons transferred NOx 2.00 lb/1,000 gallons transferred VOC -4.1 lb/1,000 gallons transferred CO .... lb/1,000 gallons transferred Benzene lb/1,000 gallons transferred Toluene - lb/1,000 gallons transferred Ethylhenzene -. lb/1,000 gallons transferred Xylene -... lb/1,000 gallons transferred n-Hexane Ih/1,000 gallons transferred 224 TMP 33 lb/1,000 gallons transferred • 10 of 22 K:\PA\2014\14W E0997.CP4 • • Hydrocarbon Loadout Regulatory Analysis Worksheet Tim regulatory requirements below am determined based on requested emissions and throughput. Colorado Regulation3 Parts A and B-APEN and Permit Requirements I;v_rc_0 0 We wonr...iu... ,. : : ::: 1 rolled actual sionutants horn this individual swrte greaer than 2 TV( .3,Put gxplorationsite le.g.,well pad)(Regulation 3,Part e,section Vas.1),k thn loagallons in tsl of eoil pe annual average baIs thoaeratnloa ]50 bloc per year ofe..sae via splash 557 anIs thweratin loa6,305 bbls per year of condensate via submerged fill procedure?dlitYd VOemkan 5 TW,Nox greaer than l0 TPy or Co emissions greater Mari IC T.(Relonyaa :FNTdletl emissionsfrom arryviteda ppllutane fiom this individual svurte greater Wan lTPY fitegulafion3Pact., ton llD.l.al, Ym'a question. 2. I5 the loadoutlorated at an exploration and production site leg.,wooed)(Regulaton 3,Part 0,Section W.111, • 2V_...ai Go to Me next question k the Idt operation loading less Nan 10.000 gallons(235 SSW)of crude d n°M.l per day o basis, 2ft w co to nestquesgm 4. k the londentoperatim loading less than 5,750 bbk peryearafcondenate via splash fill, 5Wits"Gvto w,tques6on 5. Is We load.,operation loading less than 16,308 h.per year',condensate sda submerged fill procedure, ttrt...Ort.%Go ton.question 5.Are total facility uncontrolled VOC emissions from the greater than 2TPY,004 greater than 5 TPY or CO emissions greater than 10 TPY(Reguladon 3,Part B,4cfionll.o.2)i InktntrA The 1paclout regWres a permit Colorado Regulation)Part Section lLB C 1. Is his condensate Vorage tank hydrocarbon liquids 05a well Pro,fuclinn hdlity,a cal gasc r o dm natural gas Pr¢esemgp .47..lanc 75 xtputlon. 2. Does the facility have oughput',hydrocarbonllquitl oaaou vehicles greater than requal to 5,000 barrels? i S_ Iourae,ssub wect to Regulation,Part D Sectors(LOS. I iltizilaslaa ...pare 0S.too Section II..S.a.lil-Compliance Schedule Section II.C.50.50-Operation without Venting Section II.e5.0051-Icadoat Equipment Operation and Maintenance Section S.a.iiv)-Imdout observations and Operator Training Section s.a.ivl-Records Section n.Cs.a.1.1-Requirements for Air Pollution Control Equipment • Disclaimer • This document assists operators with determining applicability d certain requirements Of the Clean Air Act,its Implementing regulations,and Air Quality Control Commission regulations.This document is not e • rule or neguletim,end the analysis it conteins orgy not apply toe partkdar situation based upon the IndViduel facts end circumstances.This document does not change or substitute fo-any law,rage/Woo, w any other legally binding requirement and is not legally en/Cable co' In the event any conflict between the language d h of this document and the language e Clean AlrAct„its implementing regulations, binding and Air Quality Control Commission regulations,the language dtha statute of regulation will control The use orncrnmendakry language such as"mcwnmend,'“May,""should"and'tan,"is Intended to • d sante APCo interpretations and recommendation.Mandatory terminology such as'must'and'Yequired'are Intended to describe contwding regdtenints under the terms at the Clean Air Act and Air Qualify Control Commission regulations.but this document does not establish legally bindng requirements In and ditset, Hydrocarbon Loadout Emissions Inventory Section 01-Administrative Information 'Facility AIRS ID: 73 .�,m.. , .c�„m-u,-^ -`�_ �' • County Plant Point Section 02-Equipment Description Details Detailed Emissions Unto Description: Produced watert f s Emission Control Device "` " �7" ' Enclosed Combustors,95%collection and 95%control) ,�e x. i„ y,,.; ₹ 5 ,f4+ Description: Is this Loadout controlled? :'Yes iii • Requested Overall VOC&HAP Control Efficiency ge: 9725 Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Hydrocarbon Loadout Actual Volume Loaded= 1,0at Barrels(bbl)per year 'Requested Permit UmitThreoghput= 1,920,300 Barrels(bbl)per year Requested Monthly Throughput= _.,_f53 Barrels(bbl)per month Potential to Emit(PTE)Volume Loaded= 1,920,-330 Barrels(bbl)per year Secondary Emissions—Combustion Device(s) Heat content of waste gas= 237^Btu/scf Actual Volume of waste gas emitted per year= scf/year Requested Volume of waste gas emitted per year= 3 ..•_scf/year Actual heat content of waste gas routed to combustion device= MMBTU per year Requested heat content of waste gas routed ba combustion device= MMBTU per year Potential to Emit(PTE(heat content of waste gas routed to combustion device= ?MMBTU per year Control Device I I Pilot Fuel Use Rate: scfh MMscf/yr Pilot Fuel Gas Heating Value: Btu/scf MMBTU/yr Section 04-Emissions Factors&Methodologies Does the company use the state default emissions factors to estimate emissions? Are the emissions factors based one stabilized hydrocarbon liquid sample drawn et the facility being r permitted? Y s stabilized hydrecarno., - -,.-ie is valid for developing size saes..-en-scans Factors Loading Loss Equation - L=12.46*5*P*M/T Factor Meaning Value Units Source S Saturation Factor egiEjEiglaigik. AP-U2 Ov 11E'ed Table 4?-1 Sdbx P True Vapor Pressure 4.2 psis AP-42Table 7.12.1" M Molecular Weight of Vapors 66 Ib/lb-mol AP-42 Table 7,3-2 • Liquid Temperature 509.9 Rankine Average tem tote Denver,CO • Loading Losses lb/1000 gallons 2%VIC.. ,.....-, lb/bbl Component Mass Fraction Emission Factor Units Source Benzene 0.051234ov lb/bbl Toluene 0 030441[3o a lb/bbl Ethylbenzene c :C: UaB lb/bbl Xylene ,,00Cr= 051: - lb/bbl n-Hexane 0.001/00154 _-.-lb/bbl 224 TMP 9.000653:'0 -.__,i_lb/bbl Emission Factors Hydrocarbon Loadout Uncontrolled Controlled PollutantEmission Factor Source (lb/bbl) (lb/bbl) (Volume Loaded) (Volume Loaded) VOC Benzene Toluene .3 2_ ... Ethylbenzene 3.-:: Xylene n-Hexane 6.01E 224 TMP 2.23E CZ Control Device Pollutant Uncontrolled Uncontrolled Emission Factor source (lb/MMBtu) (lb/bbl) (waste heat combusted) (Volume Loaded) PM10 _.. T tee. PM2.5 50x NOx )Cue CO J.u'Uc-C`3 Pilot Light Emissions Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) (lb/MMscf) Emission Factor Source (Pilot Gas (Waste Heat Combusted) Throughput) PM10 0.0000 f 4 4 , PM2.5 sox o.oi;6 NOx C:7000 VOC CO 12 of 22 K:\PA\2014\14WE0997.CP4 Hydrocarbon I oado ,,,r EmLssons Cr s r:orl+ Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (Ibs/month) PM10 PM2.5 0 SOx NOx VOC ;r CO ... Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Ohs/year} (Ibs/year) (Ibs/year) (Ibs/year) (Ibs/year) Benzene � 13 Toluene Ethylbenzene L 0 _ 1 _ Xylene =1 0 n-Hexane u._ 0 3 .... :. 224TMP 4 0 C J Section 06,Reeulatgry Summary Analn,pis Regulation 3,Parts A,B Regulation 7 Part D Section II.C.5. -_l .1re:. Non,(N um,e6 -.L.00_tce s auu}.c,tc nee,. ..c. '.i.C55. (See regulatory applicability worksheet for detailed analysis) Section 07-Initial and Periodic Sampling and Testing Requirements Does the company request a control device efficiency greater than 95%for a flare or combustion device? ` ' 3M1__- If yes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02 Section 08-Technical Analysis Notes Section 09-5CC Coding and Emissions Factors(For Inventory Use Only) Uncontrolled Emissions AIRS Point# Process# SCC Code - Pollutant Factor Control% Units 010 - 01 =.o,i ...:.x &Ur PM10 99 0 lb/1,000 gallons transferred PM2.5 C 00 lb/1,000 gallons transferred SOx 0 0 lb/1,000 gallons transferred NOx 0.EL- 0 lb/1,000 gallons transferred VOC 9.s 90 lb/1,000 gallons transferred CO 0.00 0 lb/1,000 gallons transferred Benzene 0.00 90 lb/1,000 gallons transferred Toluene 0.00 90 lb/1,000 gallons transferred Ethylbenzene _.All 90 lb/1,000 gallons transferred Xylene 9.9_ 90 16/1,000 gallons transferred n-Hexane 2._9 90 lb/1,000 gallons transferred 224 TMP :313 90 lb/1,000 gallons transferred • 13 of 22 K:\PA\2014\14W E0997.CP4 } Hydrocarbon Loadout Regulatory Analysis Worksheet The regulatory requirements below are determined based on requested emissions and throughput. Colorado Regulation 3 Parts A and 0-APEX and Permit Requirements ATTAINMENT 1.1.Are unconOolleddouticatedal an exanslron any production h,well individual source Partgreater[han2 TPy(Regulation 3,Part A,Section ll.O.l.a77 2. z the loadoutthe lodatan exploration and puduR 000 gallons welmea.'Regulation eollp rda section annual 3. Is the loadout operation loading less Man 10,OO0 gallons 1]30 BBts)of tvutle oil per day onan annualaverage basis] 4. Is Meladout operation loading less Own 3,750 bb's per year of condense.via splash gill S. Is the loadout operation loading less[ion 16,306 blots per year ofcondemateva submerged fill ptaedureT 6.Arm..facility uncontrolled VOC emissions greater Man 5TPY,NOY greater than 10TPYa la emissions greater than lO TPY(Regulation 3,Part e,section OE N, • I too Ile,pill..tn EL...urce..:.:Pp -ArtaP.ptn six NON.AT AINMPNT 1.Are unssduuted emissions Romany cri[eriapelludn[siromtbis individual source greater than ITPYmRegula.1It 3,Part A,Section ll.0.l.ail *sir_ Co[o next question. 2. Is Meloa u[lorated at an xplom 000 so.,well pad''Regular 3,Part0,S o..O.RM o the n 3. tlo is Me...operation loading less than 10,000 gallons(238 Bets)of crude oil per day on anannual average bas.. uestionton 6. Is the loadout operation dadlng less than 6,750 bhls per year of condensate via splash NITquestion 5, Is the loadout operation loading less than 16,308 hots per year of condensate via submerged fill procedure] *ARM to next question 6 Are total facility u II d VOC emissions from the greater Nan Z TPV NOx greater than 5 TPy or CO emissions greater than lO TPY'Regu..3 Porte Section)MIE The d equires a permit Colorado Regulation 7 Part 0 Section FRCS. 1. Is this condensates ank hydrocarbon liquids loadout locakd at a well production facility,n gas compressodstation natural®asp essig plan(] next question. 1.Oasts facility have t of hydrocarbon liquids laa vehicles greater than orequal.8,000 barrelsta Y, Source is subject to Regulation]Part OSectialll.C.5. e t,:.m user.a:.,biert to dout.t,araport Pair:�'.sP esi Srstion II.C5.a.(i(`ComplianccYhedule v Section CS.a.lii)-Operation without Venting Section IL C.S.a(iiil-Loadwt Equipment Operation and Maintenaae Section ll.CS.A(M-Loa..observations and Operator Training Section R.C.5.a.(v)-Records Section lLCS.a.lvil-Requirements fa Air Pollution control Equipment Disclaimer This document assists operators wits determining applicability of certain requirements of the Clean Air Act,Its implementing regulation,end Alr Quality Control Commission regulations,This document Is not s rule orregulation,and the analysis it contains may not apply to a pert)cularsituabon based upon the indvlduel facts and circumstances.This document does not change or substitute(orally low regulation,or any other legally binding requirement end is not legally enforceable.In the event of any confgct between the language of this document end the argue,e the Clean Air Act„its implementing regulations, and Air Quality Control Commission regulations,the language of the statute a•regulation will control.The use ofnon-meal my language such as'yecommed,""may,""should,"and'tan,Is Intended to desessdPCD interpretations and recommendations.Mandatary terminology shat as"must"and Inquired'are Intended to describe controlling requirements under the terns of the Clean Air Act and Air Quality CORM Commission regulations,but this document does not establish legally bindng requirements In end 4: Separator Venting Emissions Inventor~{ Section al-Administrative Information 'Facility AlRs ID: 123 9CO3 011 County Plant Point Section 02-Equipment Description Details Detailed Emissions Unit Description: One vapor recovery tower(VRT) y = Emission Control Device Description: Enclosed eomb stars Requested Overall VOC&HAP Control Efficiency%: 95.0000 Limited Process Parameter Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Separator Actual Throughput= 128/392.0 Barrels(bbl)per year Requested Permit Limit Throughput= 128,502,0 Barrels(bbl)per year Requested Monthly Throughput= 1192_._ Barrels(bbl)per month Potential to Emit(PTE)Throughput= -11:19...;Barrels(bhp per year Secondary Emissions-Combustion Device(s)for Air Pollution Control Separator Gas Heating Value. b �Btu/scf Volume of waste gas emitted per BBL of liquids throughput: 17,1 scf/bbl Control Device Pilot Fuel Use Rate: scfh MMscf/yr Pilot Fuel Gas Heating Value: -Btu/scf Section 04-Emissions Factors&Methodologies Description Pressurized liquids sample with simulated flash in Penman, MW I -d7.?j lb/Ib-mol Displacement Equation Ex=Q.MW'Xx/C Weight% Helium CO2 .._.. N2 methane ethane '5.4 propane isobutane n-butane isopeetane n-pentane cyclopentane • n-Hexane 1.2 cyclohexane Other hexanes heptanes __. methylcyclohexane 224-TMP Benzene f... Toluene Ethylbenzene Xylenes CB+Heavies _,i Total VOC Wt% 15 of 22 K:\PA\2014\14WE0997.CP4 Separator Venting Emissions Inventory Emission Factors Separator Venting Uncontrolled Controlled (lb/bbl) (lb/bbl) Emission Factor Source Pollutant (Liquid Throughput) (Liquid Throughput) VOC Benzene Toluene .. Ethylbenzene Xylene _ n-Hexane _. 224 TMP Primary Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) lb/bbl Emission Factor Source (Waste Heat Combusted) (Gas Throughput) PM25 0,0075 _ et° - SOx r :t; - ..se .. NOx {0 _ CO 310; A p2.;s:tViir:-.1.131-Wf t._f. e r Pilot Light Emissions Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) lb/MMscf Emission Factor Source (Waste Heat Combusted) (Pilot Gas Throughput) PM10 4�f ' PM2.5 ,Sox F NOx VOC Section 05-Emissions Inventory Potential to Emit - Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (Ibs/month) - PM10 _.0 0.0 0.0 1-2 .; PM2.5 3.0 0.0 0.0 0.1 2 A 5Ox ...i. 0.1 0.0 0.0 v_.. 0 NOx 0.1 0.1 0.1 17 VOC ,_-_ 69.1 U.S69.1 537 CO Cl. 0.5 05 .r... 73 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year) Benzene _._ _ _ ,_ 3,_ 1 Toluene ..,..19 .. 349 Ethylbenzene u. .37 _ 37 .. , Xylene 10. 100 S 100 n-Hexane 2616 ,.Uc 131 2916 _.. 224 TMP 0 0 Section 06-Regulatory Summary Analysis Regulation 3,Parts A,B - Regulation 7,Part D,Section II.B,F Regulation 7,Part D,Section 11.8.2.e (See regulatory applicability worksheet for detailed analysis) ( 16 of 22 K:\PA\2014\14W E0997.CP4 • Separator Venting Emissions Inventory Section 07-Initial and Periodic Sampling and Testing Requirements ' r. li: : f u - a,:-�:k`. f',i:s _ - :,.;s t' `ti "_' f 'fir rlr'Mlta. _ .s. :. ,.. .� ee ..: ,.a, ,"rr,.:.: .:c:a .err- pa ippliftellamtifig - 4'"- ar' "i ispn : ' a Y �N ....:... s. . .ea .. a in..: .ra ! . sr.^rr.. � rr r' s i ; _ : : .w z .+,z .., + n .m r q rJ_ Imy :.. i a :1 ... � a: .._. ,f ! as . vb„A"✓a,ii ,,,„,„; "n„P±a>,.R'z , ,,f?A?- ,,a„a,a ;,%1e° a z 1,t. ,. ar'.6.1.4....,.."."'"''&'" -,4, .>%Tv�, .,, • uid'r Using Liquid Throughput to Monitor Compliance Does the company use site specific emission fasters hosed on a pressurized liquid sample(Sampled upstream of the equipment covered under this AIRS ID) and process simulation to estimate emissions? This sample 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 maybe appropriate to use an older site-specific sample. If en,the permit will contain an"Initial Compliance"testing requirement to collect asite-specific liquid sample 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. Does the company request a control device efficiency greater than 95%for a flare or combustion device? If yes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02 Section 08-Technical Analysis Notes Section 09-5CC Coding and Emissions Factors(For Inventory Use Only) AIRS Point# Process# 5CC Code Pollutant Uncontrolled Emissions Factor Control% Units 011 01 ..to-00'i.29 0iI.1,i25 P-z,fzstfmY Ggsiliquld s€paraiia PM10 PM2.5 .. 7 ._. .. 500 0 Ib/1:i'. NOx .5. 0 )b;'?a':- -- VOC b/1v_•- - CO 0 H7.'1== Benzene 95 !H!?_.:. Toluene 9; 11V100.„ .. .. Ethylbenzene 9S i9/1000'.:,a9-,9,i Kylene 0.F 05 Ibf200G is rrals n-Hexane 20„ 05 lb/1400 barrels • 224 TMP a-o OS ih//T 2.7810 17 of 22 K:\PA\2014\14W E0997.CP4 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 'Source is In the aleiniiu ttaa^mane Amin .-.- ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TRY(Regulation 3,Part A,Section ll.0.1.a)? 2. Are total facility uncontrolled VOC emissions greater than 5 TRY,NOz greater than 10 TPY or CO emissions greater than 10 TPY(Regulation 3,Part B,Section 11.0.3)? • � ,. ,ridivezv,_ _,otirca s in the Nun-Attalnmeot Area NON-ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY(Regulation 3,Part A,Section ll.D.1.al? yes .Source Re 2. Are total facility uncontrolled VOC emissions from the greater than 2 TPY,Klux greater than 5 TPY or CO emissions greater than 10 TPY(Regulation 3,Part B,Section 11.0.2)? mu Source Source Re Colorado Regulation 7,Part D Section II 1. Was the well neWly constructed,hydraulically f t d or recompleted on or after August 1,2014? ,%„ 'source is Isc .,:o _- 3 .l-0 Section II.B.2—GeneralProvidons for Air Pollution Control Equipment Used to Comply with Section II Section HS-Control of emissions from well production facilities Alternative Emissions Control(Optional Section' a. Is this separator controlled bye back-up or alternatecombustion device(Le.,not the primary control device)that is not enclosed? tigtrftlq ITT_C..! -_ ...iU1o[.t7 Rev.iiati.0 r'art U. Section II.B.2.e—Alternative emissions control equipment • Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act,its Implementing regulations,and Air Quality Control Commission regulations.This document is not a rule or regulation,and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances.This document does not change or substitute for any law, regulation,or any otherlegally 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 • Separator Venting Emissions inventory Section 01-Administrative Information 'Facility AIRS ID: 123 „gt s<s`' - .,,�'• „ -'"` County Plant Point Section 02-Equipment Description Details Detailed Emissions Unit Description: Fifteen(111"' Emission Control Device Description: Enclosed combustors Requested Overall VOC&HAP Control Efficiency%: 95 Limited Process Parameter 7: , v{ ±th „ , ' Gas meter • Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Separator Actual Throughput= 1E.2S MMscf per year Requested Permit Limit Throughput= 11,25::;MMscf per year Requested Monthly Throughput= _.5 MMscf per month Potential to Emit(PTE)Throughput= 1 MMscf per year Secondary Emissions-Combustion Device(s)for Air Pollution Control Separator Gas Heating Value: 1.351.0 Btu/scf Volume of waste gas emitted per BBL of'{i:9154,y .0 liquids throughput: E a' "/:scf/bbl Control Device Pilot Fuel Use Rate: ` 50 scfh .r.< MMscf/yr Pilot Fuel Gas Heating Value: -1351 Btu/scf • U . Section 04-Emissions Factors&Methodologies Description in reel reprca .-r._ _r ssr„leanalysis _ x fir. ' MW <.9535 Ib/Ib-mol Displacement Equation Ex=Q*MW*%x/C Weight% Helium CO2 _.__9 N2 .334 methane ___:_ • ethane propane 33 isohutane ._.._3_ n-butane isopentane n-pentane _1204 cyclopentane n-Hexane .„ cyclohexane Other hexanes __939 heptanes : methylcyclohexane 224TMP Benzene • Toluene Ethylbenzene Xylenes CO*Heavies -.....,:- Total_ VOCWt% 19 of 22 K:\PA\2014\14W EO997.CP4 Separator Venting Emissions inventory - Emission Factors Separator Venting Uncontrolled Controlled Emission Factor Source Pollutant (lb/MMscf) (lb/MMscf) (Gas Throughput) (Gas Throughput) Benzene 23 - Toluene _55 Ethylbenzene sN: _ Xylene _53. n-Hexane . ._.. 224TMP 3.3.a.-le Primary Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) lb/MMscf Emission Factor Source (Waste Heat Combusted) (Gas Throughput) PM10 0.0073. ,j 2.P.:41:406.1:64.4:: PNI2.5 Dft7 i SOx 000 _ ,�,nt , NOx n _ yc ' �S!Pl' 'a CO 0,310 _ AI'47(tuna 060[nd0uiat F.C.', _. a,.. • Pilot Light Emissions Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) - lb/MMscf Emission Factor Source (Waste Heat Combusted) (Pilot Gas Throughput) PM10 0 vC,;5 2 14 ,4.2,(# .�.4, ' f PM2.5 ..5 2 T -. A SO% NOx 5 -42nN 3 47+-,:,,�, VOC CO O,i1OE ._z _'i:n,,t a Ind0 C'di5°"r71rta.. Section 05-Emissions.Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (Ibs/month) PM10 ,-,_ ..1 _. 0.1 ._ 19 PM2.5 �._ 0,1 • 59 500 _ 0.0 ..., 1 Nov _.. ..:: _._ 0.9 -.-3 146 VOC .. _ 197.1 9.9 .t97.'r 9.0 1674 CO 3.9 3.9 3.9 _..9 655 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ibs/year) (Ibs/year) Ilbs/year) (lbs/year) (Ibs/year) Benzene 1173 11`69 6_ Toluene 1557 73 _35 __ Ethylbenzene _-- '009 10 700 __ Xylene .. 729 36 07:1 .; n-Hexane _ 92r1'3 193 LCi ;... 224 TM P 9 Section 06-Regulatory Summary Analysis Regulation 3,Parts A,B _.,ir,.r00:r=s a e ery at Regulation 7,Part D,Section 11.0,F >_ ,-....,_,,,,,,e,_zc Bogalation 7,Fart 0,Sect:,,;;I..9 2. Regulation 7,Part D,Section 11.B.2.e The col,el device fa,t'==is separator is not sub w to 7egtsiation 7,Part D,3a:ioa ii,B,2.e (See regulatory applicability worksheet for detailed analysis) • 20 of 22 K:\PA\2014\14WE0997.CP4 Sep c for Venting'.missions.l"=lertv)"y 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? 43 3 -33,, 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 maybe appropriate to use an older site-specific sample. If no,the permit will contain an"Initial Testing Requirement"to collect a site-specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. Are facility-wide permitted emissions of VOC greater than or equal to 40 tons per year in the ozone nonattainment -r'` ` , q sb. area OR are emissions greater than or equal to 90 tons per year in iheozone attainment area? ... .s If yes,the permit will contain: -An"Initial Testing Requirement"to collect a site-specific g, 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 emissionsfactors established with this application. -A"Periodic Testing Requirement"to collect a site-specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application on an annual basis. Will the operator have a meter installed and operational upon startup of this point? .''. 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? s'_,, -`=,3':> ' R','"'".int: Ifyes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02 3,3.,333,tiy g :: z .,ff x gi .�fi.."E t' ;ig ✓.moofg.: 3a. g",g " g. " >Sli"NikiWi .e�a tr z't ,..1 0. infivertreitniegargigletininretralkiiiV :. s n >rr.x.:e.: x -z e: .n• y,., OWINVXDOWWWWARRANNIgitig >_., .. .. t r: s.:,,.Y`f. ._., ;.",.:sx> �z 1�:,,�,rx3.,.s 0:0.1:0':.:,• /,x. ,-ar :n> :.ice :'z r: -e y ilk f a.,sx " ,six�x.s- "xtg•x ;� aa=:t >. . <x::a xs:so s: .",,:,'a it s.,n- " �•z,^`.€i..'. : �_. Section 08-Technical Analysis Notes -. > .e sib -+v." .. 4 w Section 09-5CC Coding and Emissions Factors(For Inventory Use Only) _, ' AIRS Point# Process# 5CC Code Pollutant Uncontrolled Emissions Factor Control% Units 012 01 .,._ ,,F₹a'es PM10 1.0.3 G rN ',SCF PM2.5 1G.3 _ Ib/P1MSCF 500 0 tb/M>=•".SCF td ou 90:84.1 0 €b/!NIB'S . VOC 21594 3. S= P.VPANISCP CO :1249 S ibi NIT SCF Benzene 55.5 9.5 S,b 5,5SC= Toluene 05.9 '2/i P34SCF Ethylbenzene 1.1.3 _1 lb/3ilfvlsC5 Xylene •UU.9 95 lb/ P,₹5CF n-Hexane 5337A 55 Ic%sAR'Sci, 224 TMP 0.3 _3 7v/'s€gS_F • • 21 of 22 K:\PA\2014\14WE0997.CP4 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 ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY(Regulation 3,Part A,Section 11.0.1.0)? 2. Are total facility uncontrolled VOC emissions greater than 5 TPY,NOk greater than 10 TPY or CO emissions greater than 10 TPY(Regulation 3 Part B,Section 11.0.3)? YDU hay,ih.qmt.d thot is in th,,,o,-Att.i.nmem.Am. NON-ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY(Regulation 3,Part A,Section II.D1:a)7 2*-:12n201SourceR 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(? WiStre2 Source Re •Colorado Regulation?,Part 0,Sextidn II 1. Was the well newly constructed,hydraulically f t d pleted on or after August 1,2014? IYArO.,(Source is kook, Part zS.cVoo F iff Section II.B.2—General Provisions for Air Pollution Control Equipment Used to Comply with Section II Section I.E.I Control of emissions from well production facilities Alternative Emissions Control(Optional Section) a. Is this separator controlled by back-up It t combustion device(i.e.not the primary control device)that is notanclosed? : The coots [The cu)ssrul . Section II.B.2.e Alternative emissions control equipment Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act,its.implementing regulations,and Air Quality Control Commission regulations.This document is not a rule or regulation,and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances.This document does hot 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 Condensate Storage Tank(s) APEN t+l„M Form APCD-205 COPHE 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: GPZ I AIRS ID Number: 123 / 9CD3 /001 Section 1 -Administrative Information Company Name': Bayswater Exploration &Production, LLC Site Name: Leffler 13,14.23.24-26NHZ,B-26CHZ,P-26NHZ Tank Battery Site Location Site Location: NWNW Sec 26 T7N R66W County: Weld NAICS or SIC Code: 211120 Mailing Address: (Include Zip Code) 730 17th Street, Suite 500 Denver, CO 80202 Contact Person: Brad Rogers Phone Number: 303-893-2503 x 204 ' E-Mail Address2: brogers@bayswater.us 1 Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. LI-31ze ANA COLORADO Permit Number: AIRS ID Number: 123 /9CD3/001 • Section 2 - Requested Action O NEW permit OR newly-reported emission source ❑ Request coverage under traditional construction permit O Request coverage under a General Permit GP01 O GP08 If General Permit coverage is requested,the General Permit registration fee of$312.50 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit(check each box below that applies) ❑ Change in equipment O Change company name3 ❑ Change permit limit ❑ Transfer of ownership4 ❑ Other(describe below) -OR- ❑ APEN submittal for update only(Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ID APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info Ec Notes: Cancel existing GP08 registration, and convert to registration under GP01. 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: 14 x 300 bbl Condensate Storage Tanks Company equipment Identification No. (optional): TK-001 - TK-0 1 4 For existing sources, operation began on: 12/13/2013 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Storage tank(s) located at: Exploration a Production(E&P)site O Midstream or Downstream (non E&P)site Will this equipment be operated in any NAAQS nonattainment area? ❑ Yes ❑ No Are Flash Emissions anticipated from these storage tanks? 0 Yes O No Is the actual annual average hydrocarbon liquid throughput≥ 500 bbl/day? O Yes ❑Q No If"yes", identify the stock tank gas-to-oil ratio: m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (C0GCC) ❑ 805 series rules?If so, submit Form APCD-105. 0 Yes No Are you requesting≥6 ton/yr V0C emissions (per storage tank), or are uncontrolled actual ❑ Yes Q No emissions≥6 ton/yr(per storage tank)? COLORADO 2 1 Par ver•Newt. nay • Permit Number: • AIRS ID Number: 123 /9CD3/001 Section 4- Storage Tank(s) Information Actual Annual Amount Requested Annual Permit Limits (bbllyear) (bbl/year) Condensate Throughput: 2,873.54 1,521,642 From what year is the actual annual amount? 2019 Average API gravity of sales oil: 42.4 degrees RVP of sales oil: 8.7 Tank design: 0 Fixed roof O Internal floating roof O External floating roof Storage #of Liquid Manifold Storage Total Volume of Installation Date of Most Date of First Tank ID Vessels in Storage Tank Storage Tank Recent Storage Vessel in Production (bbl) Storage Tank(month/year) (month/year) TK001-014 14 4,200 03/2020 12/2013 Wells Serviced by this Storage Tank or Tank Battery6(E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 37582 SRC Leffler#13-26NHZ ❑ 05 - 123 - 37583 SRC Leffler#14-26NHZ ❑ 05 - 123 • 37581 SRC Leffler#23-26NHZ ❑ 05 - 123 - 37584 SRC Leffler#24-26NHZ O 05 - 123 - 37580 SRC Leffler#B-26CHZ ❑ S 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-2121 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) 40.552796/-104.753319 O Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack Discharge Height Above Temp. Flow Rate Velocity ID No. Ground Level(Feet) (°F) (ACFM) (ft/sec) EC001-002 25 1200 33.10 0.011 Indicate the direction of the stack outlet: (check one) O Upward ❑Downward O Upward with obstructing raincap ❑Horizontal O Other(describe): Indicate the stack opening and size: (check one) Q Circular Interior stack diameter(inches): 96 ❑Square/rectangle Interior stack width(inches): Interior stack depth(inches): ❑Other(describe): glib o.p+.usmmnmie . J I PnM6Frtvr.an,tint i Permit Number: AIRS ID Number: 123 I 9CD3/001 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. Pollutants Controlled: Vapor Size: Make/Model: ❑ Recovery Unit (VRU): Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Pollutants Controlled: VOCs, HAPs Rating: 1.39 MMBtu/hr Type: 2 x Enclosed Combustors Make/Model: 2 x 96" IES I Combustion Requested Control Efficiency: 95 Device: Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: 500 Waste Gas Heat Content: 2,370 Btu/scf Constant Pilot Light: (] Yes O No Pilot Burner Rating: 0.034 MMBtu/hr Description of the closed loop system: O Closed Loop System Pollutants Controlled: ❑ Other: Description: Control Efficiency Requested: Section 7- Gas/Liquids Separation Technology Information (EftP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 17 psig Describe the separation process between the welt and the storage tanks: A combined stream of liquids and natural gas is extracted from the wells and transferred to to fifteen (15) heated separators, equipped with a burner. The separated condensate is transferred to a vapor recovery tower(VRT), for further separation of natural gas and condensate, prior to transferring to storage tanks. COLORADO Permit Number: • AIRS ID Number; 123 /9CD3/001 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? ❑Q Yes 0 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 Desch Description Collection Efficiency Control Efficiency p (%of total emissions captured (%reduction of captured by control equipment) emissions) VOC Enclosed Combustor 100 95 NOx CO HAPs Enclosed Combustor 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: Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Pollutant Source Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP 42, Emissions Emissfons8 Emissions Emissions Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year) VOC 0.26 lb/bbl SS EF 0.37 0.019 194.74 9.74 NO„ 0.068 Ib/MMBtu AP-42 de minimis 0.81 CO 0.31 Ib/MMBtu AP-42 de minimis 3.69 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. 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. $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 Yes 0 No 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 Emission Factor Actual Annual Emissions Chemical Name Abstract Source Uncontrolled Controlled Service(CM) Uncontrolled Units (AP-42, Emissions Emissions8 Basis Number Mfg.,etc.) (lbs/year) (lbs/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n-Hexane 110543 2,2,4-Trimethylpentane 540841 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. B Annual emission fees will be based on actual controlled emissions reported.If source has not yet started operating,provide projected emissions. COLORADO Permit Number: • AIRS ID Number: 123 /9CD3 i 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. c7y S f J 5' V t_ Signature of Legally Authorized Person (not a vendor or consultant) Date • Brad Rogers Environmental Manager Name (print) Title Check the appropriate box to request a copy of the: ❑Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment,change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 Air Pollution Control Division OR APCD-SS-B1 (303)692-3148 4300 Cherry Creek Drive South Denver, CO 80246-1530 APCD Main Phone Number (303) 692-3150 Make check payable to: Colorado Department of Public Health and Environment 6 Ask-.COLORADO E&P Storage Tank Air Pollutant Emissions Notice(APEN)Addendum Form' Company Name: Baxswater Exploration&Production LLC Source Name: Leffler 13,14,23.24-26NHZ.B-26CHZ,P-26NHZ Tank Batten Emissions Source AIRS ID2: 123 / 9CD3 / 001 Wells Services by this Storage Tank or Tank Battery(E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 38282 LefllerC-26-28HN 05 - 123 - 38283 Leffler E-26-28H\ X❑ 05 - 123 - 38284 Leffler D-26-28HN 05 - 123 - 49488 Leffler J-26-2814N 05 - 123 - 49489 Leffler G-26-28HN 05 - 123 - 49490 Leffler F-26.2811\ 05 - 123 _ 49491 Leffler 1-26-28HNEl 05 - 123 - 49492 Leffler HA-26-2811N O 05 - 123 - 50038 Leffler RA-26-28HN 05 - 123 - 50039 Leffler A-26-281-IN ❑X 05 - 123 - 50040 Leffler K-26-28HN 05 - 123 - 50042 Leffler LA-26-2811N 05 - 123 - 50037 Leffler B-26-28HN 05 - 123 - 37772 SRC Leffler P-26NHZ 0 0 0 0 0 0 0 Footnotes: Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 Form APCD-212 E&P Storage Tank APEN Addendum-Ver.7-29-2014 Produced Water Storage Tank(s) APEN �„PHE T. Form APCD-207 CDPHE Air Pollutant Emission Notice (APEN) and Application for Construction Permit AU sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and wilt 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: 14WEO997 AIRS ID Number: 123 /9CD3 /002 Section 1 -Administrative Information le Company Name': Bayswater Exploration & Production, LLC Site Name: Leffler 13.14.23,24-26NHZ,B-26CHZ,P-26NHZ Tank Battery Site Location: Site Location NWNW Sec 26 T7N R66W • County: Weld NAICS or SIC Code: 211120 Mailing Address: (Include Zip Code) 730 17th Street, Suite 500 Denver, CO 80202 Contact Person: Brad Rogers Phone Number: 303-893-2503 x 204 E-Mail Address2: brogers@bayswater.us 1 Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 431459 Apik COLORADO Permit Number: 14WE0997 - AIRS ID Number: 123 I 9CD3/002 • Section 2 - Requested Action O NEW permit OR newly-reported emission source ❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit 0 GP05 0 GP08 If General Permit coverage is requested,the General Permit registration fee of$312.50 must be submitted along with the APEN filing fee. -OR- MODIFICATION to existing permit(check each box below that applies) ❑ Change in equipment ❑ Change company name; ❑ Change permit limit 0 Transfer of ownership' ❑r 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: Add produced water tanks to existing individual permit. 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: 4 x 300 bbl Produced Water Storage Tanks Company equipment Identification No. (optional): PW-001 - PW-004 For existing sources, operation began on: 12/13/2013 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Storage tank(s) located at: 0 Exploration Et Production(MP)site 0 Midstream or Downstream (non HIP)site Will this equipment be operated in any NAAQS nonattainment area? ❑r Yes O No Are Flash Emissions anticipated from these storage tanks? 0 Yes 0 No Are these storage tanks located at a commercial facility that accepts oil production Yes No wastewater for processing? O ❑ Do these storage tanks contain less than 1%by volume crude oil on an annual average basis? 0 Yes O No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) s Yes No 805 series rules?If so, submit Form APCD-105. ❑ ❑ Are you requesting≥6 ton/yr VOC emissions(per storage tank), or are uncontrolled actual emissions≥6 ton/yr(per storage tank)? ❑ Yes No COLORADO N.%ku • Permit Number: 14WE0997 • AIRS ID Number: 123 .1 9CD3/002 Section 4 -Storage Tank(s) Information Actual Annual Amount Requested Annual Permit Limits (bbllyeor) (bbl/year) Produced Water Throughput: 1,083.86 1,920,000 From what year is the actual annual amount? 2019 Tank design: 0 Fixed roof O Internal floating roof ❑ External floating roof Storage #of Liquid Manifold Storage Total Volume of Installation Date of Most Date of First Tank ID Vessels in Storage Tank Storage Tank Recent Storage Vessel in Production (bbl) Storage Tank(month/year) (month/year) PW001-004 4 1200 12/2013 12/2013 Wells Serviced by this Storage Tank or Tank Battery6(E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 37582 SRC Leffler#13-26NHZ O 05 - 123 - 37583 SRC Leffler#14-26NHZ O 05 - 123 - 37581 SRC Leffler#23-26NHZ O 05 - 123 - 37584 SRC Leffler#24-26NHZ O 05 - 123 - 37580 SRC Leffler#B-26CHZ ❑ 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) 40.552796/-104.753319 0 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 Discharge Height Above Temp. Flow Rate Velocity ID No. Ground Level(Feet) (°F) (ACFM) (ft/sec) EC003 25 1200 1.39 0.0018 Indicate the direction of the stack outlet: (check one) 0 Upward ❑Downward O Upward with obstructing raincap ❑Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter(inches): 48 ❑Square/rectangle Interior stack width (inches): Interior stack depth(inches): ❑Other(describe): y► COIOR ADO 3 1 Plitt N w e Permit Number: 1 4WE0997 • AIRS ID Number: 123 /9CD3/002 Section 6 - Control Device Information O Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor Size: Make/Model: O Recovery Unit (VRU): Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Pollutants Controlled: VOCs, HAPs Rating: 0.11 MMBtu/hr Type: Enclosed Combustor Make/Model: 48"Cimarron Combustion Requested Control Efficiency: 95 Device: Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: 500 Waste Gas Heat Content: 1,469 Btu/scf Constant Pilot Light: 0 Yes ❑ No Pilot Burner Rating: 0.034 MMBtu/hr Description of the closed loop system: O Closed Loop System Pollutants Controlled: ❑ Other: Description: Control Efficiency Requested: Section 7 - Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 58 psig Describe the separation process between the well and the storage tanks: A combined stream of liquids and natural gas is extracted from the wells and transferred to to fifteen (15) heated separators, equipped with a burner. The separated produced water is transfered to storage tanks. COLORADO 4 - wr0.p xen, Permit Number: - 14WE0997 AIRS ID Number: 123 /9c03/002 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? Ei Yes O 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): Collection Efficiency Control Efficiency Pollutant Control Equipment Description (%of total emissions captured (%reduction of captured by control equipment) emissions) VOC Enclosed Combustor 100 95 NOx CO HAPs Enclosed Combustor 100 95 Other: From what year is the following reported actual annual emissions data? 201 9 Use the following table to report the criteria pollutant emissions from source: Emission Factor Actual Annual Emissions Requested Annual Permit Pollutant Source Emission Limit(s)5 Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Basis Units (�42' Emissions Emissions Emissions Emissions Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year) VOC 0.020 lb/bbl SS EF 0.011 0.00054 19.28 0.96 NO. 0.068 lb/MMBtu AP-42 de minims 0.03 CO 0.31 IbIMMBtu AP-42 de minims 0.12 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-criteriaEj Yes El No 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 Emission Factor Actual Annual Emissions Chemical Name Abstract Uncontrolled Source Uncontrolled Controlled Service(CAS) Basis Units (AP-42, Emissions Emissions Number Mfg.,etc.) (lbs/year) Ohs/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n-Hexane 110543 2,2,4-Trimethylpentane 540841 7 Attach produced water laboratory analysis,stack test results,and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emission fees will be based on actual controlled emissions reported.If source has not yet started operating,provide projected emissions. COLORADO 5 '.ttes'mv�wnm.ne Permit Number: 14WE0997 AIRS ID Number: 123 /sun/002 Section 10-Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP05 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. / 13f Z 2. Signature of Legally Authorized Person (not a vendor or consultant) Date Brad Rogers Environmental Manager Name (print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance ❑Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five,(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 Air Pollution Control Division OR APCD-SS-B1 (303)692-3148 4300 Cherry Creek Drive South Denver,CO 80246-1530 APCD Main Phone Number (303)692-3150 Make check payable to: Colorado Department of Public Health and Environment cOtORADO 6 E&P Storage Tank Air Pollutant Emissions Notice(APEN)Addendum Formt Company Name: Bayswater Exploration&Production LLC Source Name: Leffler 13,14,23,24-26NHZ,B-26CHZ,P-26NHZ Tank Battery Emissions Source AIRS ID2: 123 / 9C133 / 002 Wells Services by this Storage Tank or Tank Battery(E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 38282 Leffler C-26-28Hti 05 - 123 - 38283 Leffler E-26-28HN 05 - 123 - 38284 Leffler D-26-28HN 05 - 123 - 49488 Leffler J-26-28HN 05 - 123 - 49489 Leffler G-26-281-IN 05 - 123 - 49490 Leffler F-26-28HN 05 - 123 _ 49491 Leffler 1-26-28HN 05 - 123 _ 49492 Leffler 11A-26-28IIN 05 - 123 - 50038 Leffler BA-26-28HN 05 - 123 - 50039 Leffler A-26-28HN 0 05 - 123 - 50040 Leffler K-26-28HN 05 - 123 - 50042 Leffler LA-26-2811N 05 - 123 - 50037 Leffler B-26-28HN 05 - 123 - 31772 SRC Leffler P-26NHZ O O O - - ❑ O O - - o Footnotes: Attach this addendum to associated APEN form when needed to report additional wells- ` If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 Form APCD-212 E&P Storage Tank APEN Addendum-Ver.7-29-20(4 Hydrocarbon Liquid Loading APEN �+u Form APCD-208 CDPHE Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENS will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks,etc.). In addition,the General APEN (Form APCD-2OO)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 14WE0997 AIRS ID Number: 123 / 9CD3 /006 • Section 1 -Administrative Information 'fit y Company Name1: Bayswater Exploration & Production, LLC Site Name: Leffler 13,14.23,24-26NHZ,B-26CHZ,P-26NHZ Tank Battery Site Location Site Location: NWNW Sec 26 T7N R66W County: Weld NAICS or SIC Code: 211120 Mailing Address: (Include Zip Code) 730 17th Street, Suite 500 Denver, CO 80202 Contact Person: Brad Rogers Phone Number: 303-893-2503 x 204 E-Mail Addressz: brogers@bayswater.us 1 Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. • 431460 tawCOLORADO Permit Number: 14WE0997 AIRS ID Number: 123 /9CD3/006 Section 2 - Requested Action 0 NEW permit OR newly-reported emission source 0 Request coverage under construction permit 0 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- O MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment 0 Change company name3 0 Change permit limit ❑ Transfer of ownership4 ❑ Other(describe below) -OR • APEN submittal for update only(Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- • Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info a Notes: Increase permit limit for condensate loadout in existing individual permit. 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 truck loadout with vapor balance during LACT pipeline downtime. Company equipment Identification No. (optional): TL-001 For existing sources,operation began on: 12/2013 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? El Yes 0 No Is this equipment located at a stationary source that is considered a Major Source of(HAP) emissions? ❑ Yes 0 No Does this source load gasoline into transport vehicles? 0 Yes 2 No Is this source located at an oil and gas exploration and production site? 0 Yes 0 No If yes: Does this source toad less than 10,000 gallons of crude oil per day on an annual 0 Yes 0 No average? Does this source splash fill less than 6,750 bbl of condensate per year? ❑ Yes 0 No Does this source submerge fill less than 16,308 bbl of condensate per year? 0 Yes 0 No COLORDO n.y�,eai d wm . ,. .. - t A� - �I4M#6Lrts.wwnt Permit Number: •14WE0997 AIRS ID Number: 123 /9CD3/006 Section 4- Process Equipment Information Product Loaded: ❑� Condensate 0 Crude Oil 0 Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loadeds: 152,164 bbl/year Actual Volume Loaded: 2,873.54 bbl/year This product is loaded from tanks at this facility into: tank trucks (e.g. "rail tank cars"or"tank trucks") If site specific emission factor is used to calculate emissions, complete the following: Average temperature of Saturation Factor: 0.6 bulk liquid loading: 50.23 °F Molecular weight of True Vapor Pressure: 4.20 Psia®60 "F displaced vapors: 66 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/ft' Load Line Volume: ft3/truckload Vapor Recovery Line Volume: ft3/truckload 5 Requested values wilt become permit limitations or will be evaluated for exempt status,as applicable,and should consider future process growth.Requested values are required on all APENs,including APEN updates. Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.552796/-104.753319 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 Discharge Height Above Temp. Flow Rate Velocity Stack ID No. Ground Level(Feet) (•F) (ACFM) (ftlsec) EC001-002 25 1200 68.14 0.0113 Indicate the direction of the stack outlet: (check one) ❑� Upward 0 Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) El Circular Interior stack diameter(inches): 96 0 Square/rectangle Interior stack width(inches): Interior stack depth(inches): ❑Other(describe): COLORADO Permit Number: 14WE0997 • • AIRS ID Number: 1.23 /9CD3/006 Section 6 - Control Device Information O Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. ❑ Loading occurs using a vapor balance system: Requested Control Efficiency: 95 Used for control of: VOCs,HAPs Rating: 1.39 MMBtu/hr Type: 2 x Enclosed Combustors Make/Model: 2 x 96"IES rn Combustion Device: Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: 500 °F Waste Gas Heat Content: 2370 Btu/scf Constant Pilot Light: 0 Yes O No Pilot Burner Rating: 0.034 MMBtu/hr Pollutants Controlled: D Other: Description: Requested Control Efficiency: Section 7 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O 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 Descri Description Collection Efficiency Control Efficiency p (%of total emissions captured (%reduction of captured by control equipment) emissions) PM SO. NO,, • CO VOC Enclosed Combustor 95 95 HAPs Enclosed Combustor 95 95 Other: ❑ Using State Emission Factors(Required for GP07) VOC Benzene n-Hexane ❑Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL ❑Crude 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? 2019 Use the following table to report the criteria pollutant emissions from source: Emission Factor Actual Annual Emissions Requested Annual Permit Pollutant Emission Limit(s)5 Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Basis Units Mfg etc) Emissions Emissions(' Emissions Emissions (tons/year) (tons/year) (tons/year) (tons/year) PM SO. NOx CO VOC 4.064 lb/1000 gal AP-42 0.0058 0.00057 12.99 1.27 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 4 i to mwr • Permit Number: 14WE0997 - AIRS ID Number: 123 /9CD3/006 Section 8 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteriaEj Yes El No 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 Emission Factor Actual Annual Emissions Abstract Source Uncontrolled Controlled Chemical Name Service CAS Uncontrolled Units( ) Basis (AP-42, Emissions Emissions Number Mfg.,etc.) (tbs/year) (lbs/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n-Hexane 110543 2,2,4-Trimethylpentane 540841 Other: 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions. Section 9 -Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP07. 13 (2o o Signature of Legally Authorized Person (not a vendor or consultant) Date Brad Rogers Environmental Manager Name (print) Title Check the appropriate box to request a copy of the: Q Draft permit prior to issuance O Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, lI.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 Air Pollution Control Division OR APCD-SS-B1 (303)692-3148 4300 Cherry Creek Drive South Denver,CO 80246-1530 APCD Main Phone Number (303)692-3150 Make check payable to: Colorado Department of Public Health and Environment i/+* COLORADO Hydrocarbon Liquid Loading APEN �+u Form APCD-208 COPHE Air Pollutant Emission Notice(APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit,glycol dehydration unit, condensate storage tanks,etc.). In addition, the General APEN (Form APCD-2OO)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 14WE0997 AIRS ID Number: 123 / 9CD3 f 0/O Section 1 -Administrative Information Company Name1: Bayswater Exploration & Production, LLC Site Name: Leffler 13,14,23,24-26NHZ,B-26CHZ,P-26NHZ Tank Battery Site Location Site Location: NWNW Sec 26 T7N R66W County: Weld NAICS or SIC Code: 211120 Mailing Address: • (Include Zip Code) 730 17th Street, Suite 500 Denver, CO 80202 Contact Person: Brad Rogers Phone Number: 303-893-2503 x 204 E-Mail Address2: brogers@bayswater.us 1 Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 431461 COLORADO Permit Number: 14WE0997 - AIRS ID Number: 123 /9CD3/ Section 2 - Requested Action O NEW permit OR newly-reported emission source O 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- 0 MODIFICATION to existing permit(check each box below that applies) O Change fuel or equipment O Change company name3 Q Change permit limit ❑ Transfer of ownership4 ❑ Other(describe below) -OR- ❑ APEN submittal for update only(Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- El Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit (PTE) Additional Info a Notes: Add produced water loadout to existing individual permit. 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 water truck loadout with vapor balance Company equipment Identification No. (optional): TL-002 For existing sources, operation began on: 12/2013 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? 0 Yes O No Is this equipment located at a stationary source that is considered a Major Source of(HAP) ❑ Yes ❑r No emissions? Does this source load gasoline into transport vehicles? ❑ Yes 0 No Is this source located at an oil and gas exploration and production site? 0 Yes ❑ No If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual O Yes ✓❑ No average? Does this source splash fill less than 6,750 bbl of condensate per year? O Yes ❑✓ No Does this source submerge fill less than 16,308 bbl of condensate per year? D Yes No col.oRAoo Permit Number: 14WE0997 • AIRS ID Number: 123 /9CD3 Section 4 - Process Equipment Information Product Loaded: O Condensate O Crude Oil Q Other: Produced Water If this APEN is being filed for vapors displaced from'cargo carrier, complete the following: Requested Volume Loaded5: 1,920,000 bbl/year Actual Volume Loaded: 1,083.86 bbl/year This product is loaded from tanks at this facility into: tank trucks (e.g. "rail tank cars"or"tank trucks") If site specific emission factor is used to calculate emissions, complete the following: Average temperature of Saturation Factor: 0.6 F bulk liquid loading: . 3 52 True Vapor Pressure: 4, 20 Psia®60 °F Molecular weight of 66 lb/lb mot displaced vapors: If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: bbl/year Actual Volume Loaded: bbl/year Product Density: lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume: 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 (Latitude/Longitude or ti1'M) 40.552796/-104.753319 O Check box if the following information is not applicable to the source because emissions wilt not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Discharge Height Above Temp. Flow Rate Velocity Stack ID No. Ground Level(Feet) rp) (ACFM) (ftlsec) EC003 25 1200 1.39 0.0018 Indicate the direction of the stack outlet: (check one) Q Upward O Downward O Upward with obstructing raincap ❑Horizontal O Other(describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter(inches): 48 ❑Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑Other(describe): COLORADO - - awmarftwla.Envfwrment Permit Number: 14WE0997 • AIRS ID Number: 123 /9CD3/ • 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. 0 Loading occurs using a vapor balance system: Requested Control Efficiency: 95 % Used for control of: VOCs,HAPs Rating: 0.11 MMBtu/hr Type: Enclosed Combustor Make/Model: 48"Cimarron rn Combustion Device: Requested COntrol Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: 500 °F Waste Gas Heat Content: 2370 Btu/scf Constant Pilot Light: (] Yes ❑ No Pilot Burner Rating: 0.034 MMBtu/hr Pollutants Controlled: Other: ❑ Description: Requested Control Efficiency: Section 7 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O Yes O 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): Collection Efficiency Control Efficiency Pollutant Control Equipment Description (%of total emissions captured (%reduction of captured by control equipment) emissions) PM SOX NOx CO VOC Enclosed Combustor 95 95 HAPs Enclosed Combustor 95 95 Other: ❑ Using State Emission Factors (Required for GP07) VOC Benzene n-Hexane O Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL O 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: Emission Factor Actual Annual Emissions Requested Annual Permit Pollutant Emission Limit(s)5 Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Unit (AP42, Emissions Emissions6 Emissions Emissions Basis Mfg.,etc.) tons/ ear ( Y ) (tons/year) (tons/year) (tortsJysar) PM 500 NO0 CO VOC 0.081 Ibr1000 gal AP-42 0.000044 0.0000043 3.28 0.32 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 4 tawoa.�u - Permit Number: 14WE0997 • AIRS ID Number: 123 /9C031 , Section 8 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteriaEJ Yes E]No 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 Emission Factor Actual Annual Emissions Chemical Name Abstract Uncontrolled Source Uncontrolled Controlled Service(CAS) Basis Units (AP-42, Emissions Emissions6 Number Mfg.,etc.) (lbs/year) (Ibs/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n-Hexane 110543 2,2,4-Trimethylpentane 540841 Other: 6 Annual emission fees will be based on actual controlled emissions reported.If source has not yet started operating, provide projected emissions. Section 9 -Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP07. Signature of Legally Authorized Person(not a vendor or consultant) DAte Brad Rogers Environmental Manager Name (print) Title Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance ❑Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made (significant emissions increase, increase production, new equipment,change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 Air Pollution Control Division OR APCD-SS-B1 (303)692-3148 4300 Cherry Creek Drive South Denver,CO 80246-1530 APCD Main Phone Number (303)692-3150 Make check payable to: Colorado Department of Public Health and Environment COLORADO ,. • - 3 v ==t,n, t, ..o ,,,, Gas Venting APEN - Form APCD-211 Air Pollutant Emission Notice (APEN)and CDPHE Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website. • This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 14WE0997 AIRS ID Number: 1 23 /9CD3/ Q/2 Section 1 - Administrative Information04„ Company Name': Bayswater Exploration & Production, LLC Site Name: Leffler 13,14.23,24-26NHZ,B-26CHZ,P-26NHZ Tank Battery Site Location Site Location: NWNW Sec 26 T7N R66W Weld County: NAICS or SIC Code: 211120 Mailing Address: 730 17th Street, Suite 500 (Include Zip Code) Denver, CO 80202 Contact Person: Brad Rogers Phone Number: 303-893-2503 x 204 E-Mail Addressz: brogers@bayswater.us 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.My 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. 431463 COLORADO Permit Number: •14WE0997 • AIRS ID Number: 123 /9CD3/ Section 2 - Requested Action O NEW permit OR newly-reported emission source -OR- Q MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment 0 Change company name3 ❑ Add point to existing permit ❑ Change permit limit 0 Transfer of ownership4 p 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: Add low-pressure heated separator associated gas flaring to existing individual permit. 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: Flaring associated'gas from fifteen (15) low-pressure (LP) heated separators Company equipment Identification No. (optional): LP-SEP001 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: 06/2020 Q 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 days/week weeks/year Will this equipment be operated in any NAAQS Yes ❑ No nonattainment area? Is this equipment located at a stationary source that is ❑ Yes Ej No considered a Major Source of(HAP)Emissions? Is this equipment subject to Colorado Regulation No. 7, 0 Yes 0 No Section XVII.G? .. !COLORADO i o gormwrcaa w,ttc warm a ena=wmrne Permit Number: 1 4WE0997 • AIRS ID Number: 123 /9CD3./ Section 4- Process Equipment Information J Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: Serial#: Capacity: gal/min ❑ Compressor Rod Packing Make: Model: #of Pistons: Leak Rate: Scf/hr/pist ❑ Blowdown Events #of Events/year: Volume per event: MMscf/event ❑ Other Description: If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator,you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑✓ Yes ❑ No Vent Gas 35 BTU/SCF Gas Venting Heating Value: Process Parameters: Requested: 18.25 MMSCF/year Actual: 18.25 MMSCF/year -OR- Liquid Throughput Process Parameters: Requested: bbl/year Actual: bbl/year Molecular Weight: 24.95 voC(Weight%) 33 Benzene(weight%) 0.10 Vented Gas Toluene(weight%) 0.13 Properties: Ethylbenzene(Weight%) 0.017 Xylene(Weight%) 0.061 n-Hexane(weight%) 0.77 2,2,4-Trimethylpentane(Weight%) 0.00046 Additional Required Documentation: ❑� Attach a representative gas analysis (including BTEX Et n-Hexane,temperature, and pressure) ❑ Attach a representative pressurized extended liquids analysis (including BTEX Et n-Hexane, temperature, and pressure) 5 Requested values wilt 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. COLORA00 .3 a Cn'«,m-wrt - Permit Number: 14WE0997 • AIRS ID Number: 123 /9CD3/ Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.552796/-104.753319 O Check box if the following information is not applicable to the source because emissions wilt not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Discharge Height Temp, Flow Rate Velocity Above Ground Level Stack ID No. (Pest) r otam) (ft/sec) EC-001 -EC-002 25 1200 33.10 0.011 Indicate the direction of the stack outlet: (check one) Upward ❑Downward ❑ Upward with obstructing raincap ❑Horizontal D Other(describe): Indicate the stack opening and size: (check one) Orcular Interior stack diameter(inches): 96 ❑Square/rectangle Interior stack width (inches): Interior stack depth(inches): ❑Other(describe): Section 6 -Control Device Information O Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Size: Make/Model: ❑ VRU: Requested Control Efficiency: % VRU Downtime or Bypassed: Pollutants Controlled: VOCs, HAPs Rating: 1 39 MMBtu/hr Type: 2 x Enclosed Combustors Make/Model: 2 x 96"IES 0 Combustion Requested Control Efficiency: 95 Device: Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: 500 Waste Gas Heat Content: 1 351 Btu/scf Constant Pilot Light: ❑� Yes ❑ No Pilot burner Rating: 0.034 MMBtu/hr Pollutants Controlled: ❑ Other: Description: Requested Control Efficiency: COLORADO mpnem.a�o�mm�� .. + 4 Permit Number: 1 4VE0997 • AIRS ID Number: 123 /9CD3/ 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? 0 Yes 0 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 Descri Description Collection Efficiency Control Efficiency p (%of total emissions captured (%reduction of captured by control equipment) emissions) PM SOx NO4 CO VOC Enclosed Combustor 100 95 HAPs Enclosed Combustor 100 95 Other: From what year is the following reported actual annual emissions data? 2020 Use the following table to report the criteria pollutant emissions from source: Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Pollutant Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled AP-42 Basis Units Mfg.,etc.) Emissions Emissions& Emissions Emissions (tons/year) (tons/year) (tons/year) (tons/year) PM SOx NOx 0.068 Ib/MMBtu AP-42 1.01 1.01 i CO 0.31 Ib/MMBtu AP-42 4.59 4.59 VOC 0.022 Ib/MMscf Gas Analysis 236.4 11.82 236.4 11.82 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 Yes ❑ No 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 Emission Factor Actual Annual Emissions Chemical Name Abstract Uncontrolled Source Uncontrolled Controlled Service(CAS) Basis Units (AP-42, Emissions Emissions& Number Mfg.,etc.) (lbs/year) (lbs/year) Benzene 71432 0.000065 lb/MMscf Gas Analysis 1,194.88 59.73 Toluene 108883 0.000086 Ib/MMscf Gas Analysis 1,564O1 78.20 Ethylbenzene 100414 Xylene 1330207 0,000040 IbjMMscf Gas Analysis 730.06 36.50 n-Hexane 110543 0.00051 Ib/MMsa Gas Analysis 9.254.28 462.71 2,2,4-Trimethylpentane 540841 Other: 6 Annual emission fees will be based on actual controlled emissions reported.If source has not yet started operating,provide projected emissions. ` Co Lo ADO - ,. Permit Number: 14 y y E0997 AIRS ID Number: • 1 23 /9CD3/ Section 9 -Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. S ib ' s-o . Signature of Legally Authorized Person (not a vendor or consultant) Date Brad Rogers Environmental Manager Name (print) Title Check the appropriate box to request a copy of the: E Draft permit prior to issuance O Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 APCD-SS-B1 OR 4300 Cherry Creek Drive South (303)692-3148 Denver,CO 80246-1530 APCD Main Phone Number Make check payable to: (303)692-3150 Colorado Department of Public Health and Environment COLORADO Received 8/7/2020 Addendum to APEN 431462 Gas VentingAPEN - Form APCD-211 — Air Pollutant Emission Notice (APEN) and 4 CUP" ' Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-2OO)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website. This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 14WE0997 AIRS ID Number: 123 / 9CD3 / 011 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 -Administrative Information Company Name': Bayswater Exploration & Production, LLC Site Name: Leffler 13,14,23,24-26NHZ,B-26CHZ,P-26NHZ Tank Battery Site Location Site Location: NWNW Sec 26 T7N R66W Weld County: NAICS or SIC Code: 211120 Mailing Address: 730 17th Street, Suite 500 (Include Zip Code) Denver, CO 80202 Contact Person: Brad Rogers Phone Number: 303-893-2503 x 204 E-Mail Address2: brogers@bayswater.us 1 Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. giltiCOLORADO Form APCD 211 Gas Venting APEN Revision 12/2019 1 I Heath twos an HeaNt 6 Onvirovtxnt Permit Number: 1 4WE0997 AIRS ID Number: 1 23 I 9CD3/ [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly-reported emission source -OR- ❑� MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit 0 Change permit limit ❑ Transfer of ownership4 ❑r Other(describe below) -OR ▪ APEN submittal for update only(Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- El Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit (PTE) Additional Info&Notes: Add VRT associated gas flaring to existing individual permit. 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: Flaring associated gas from one (1) vapor recovery tower (VRT) Company equipment Identification No. (optional): VRT-001 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: 06/2020 Q 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 days/week weeks/year Will this equipment be operated in any NAAQS El nonattainment area? Yes 0 No Is this equipment located at a stationary source that is o Yes El No considered a Major Source of(HAP) Emissions? Is this equipment subject to Colorado Regulation No. 7, 0 Yes ❑ No Section XVII.G? co COLORADO Form APCD-211 -Gas Venting APEN - Revision 12/2019 2 I `""°CO bEnw...., Permit Number: 1 4WE0997 AIRS ID Number: 1 23 /9CD3/ [Leave blank unless APCD has already assigned a permit.#and AIRS ID] Section 4 - Process Equipment Information 0 Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: Serial#: Capacity: gal/min ❑ Compressor Rod Packing Make: Model: #of Pistons: Leak Rate: Scf/hr/pist ❑ Blowdown Events #of Events/year: Volume per event: MMscf/event ❑ Other Description: If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes ❑✓ No Vent Gas BTU/SCF Gas Venting Heating Value: Process Parameters5: Requested: MMSCF/year Actual: MMSCF/year -OR- Liquid Throughput Process Parameters5: Requested: 107,160 bbl/year Actual: 107,160 bbl/year Molecular Weight: 37.58 VOC (Weight%) 63 Benzene (Weight%) 0.17 Vented Gas Toluene (Weight%) 0.16 Properties: Ethylbenzene(Weight%) 0.017 Xylene (Weight%) 0.046 n-Hexane(Weight%) 1.2 2,2,4-Trimethylpentane (Weight%) 0.000 Additional Required Documentation: ❑ Attach a representative gas analysis (including BTEX ft n-Hexane, temperature, and pressure) ❑ Attach a representative pressurized extended liquids analysis (including BTEX a 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. COLORADO Form APCD-211 - Gas Venting APEN - Revision 12/2019 3 Permit Number: 1 4WE®997 AIRS ID Number: 1 23 /9CD3 (Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.552796/-104.753319 O Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. wk 11A- n11„ piscbef Fle�ghk� Temp Flow Rate `Stack iD Fio s d (`1`) (AGRM) 2 EC-001 - EC-002 25 1200 28.93 0.0096 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Downward O Upward with obstructing raincap ❑ Horizontal O Other(describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter(inches): 96 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other(describe): Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Size: Make/Model: ❑ VRU: Requested Control Efficiency: VRU Downtime or Bypassed: Pollutants Controlled: VOCs, HAPs Rating: 1.39 MMBtu/hr Type: 2 x Enclosed Combustors Make/Model: 2 x 96" IES ❑✓ Combustion Requested Control Efficiency: 95 % Device: Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: 500 Waste Gas Heat Content: 2,151 Btu/scf Constant Pilot Light: 0 Yes ❑ No Pilot burner Rating: 0.034 MMBtu/hr Pollutants Controlled: ❑ Other: Description: Requested Control Efficiency: % 4 Form APCD-211 -Gas Venting APEN - Revision 12/2019 Permit Number: 14WE 0997 AIRS ID Number: 123 /9CD3/ [Leave bank unless APCD has already assigned a permit#and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes 0 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): Collection Efficiency Control Efficiency Pollutant Control Equipment Description (96 of total emissions captured (%reduction of captured by control equipment) emissions) PM SOX NO. CO VOC Enclosed Combustor 100 95 HAPs Enclosed Combustor 100 95 Other: From what year is the following reported actual annual emissions data? 2020 Use the following table to report the criteria pollutant emissions from source: Requested Annual Permit Emission Factor Actual Annual Emissions Emission Limit(s)5 Pollutant Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Basis Units (AP-42, Emissions Emissions6 Emissions Emissions Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year) PM SOx NOx 0.068 lb/MMBtu AP-42 - 0.17 - 0.17 CO 0.31 lb/MMBtu AP-42 - 0.006 -- 0.006 VOC 1.07 lb/bbl Promax 68.89 3.44 68.89 3.44 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 APEN5,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 ❑✓ Yes 0 No 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 Emission Factor Actual Annual Emissions Abstract Source Uncontrolled Controlled Chemical Name Uncontrolled Service(CAS) Units (AP-42, Emissions Emissions6 Number Basis Mfg.,etc.) (lbs/year) y.ear) (tbs/year) Benzene 71432 0.0029 lb/bbl Promax 374.51 18.73 Toluene 108883 0.0027 lb/bbl Promax 348.38 17.42 Ethylbenzene 100414 Xylene 1330207 n-Hexane 110543 0.020 lb/bbl Promax 2,602.40 130.12 2,2,4-Trimethylpentane 540841 Other: 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. fiellAteCOLOI{ADO Form APCD-211 -Gas Venting APEN - Revision 12/2019 5 I '° '1��,�Fnwae�, Permit Number: 14WE0997 AIRS ID Number: 123 /9CD3/ [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 9 -Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. Signature of Legally Authorized Person (not a vendor or consultant) Date Brad Rogers Environmental Manager Name (print) Title Check the appropriate box to request a copy of the: ❑r Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 APCD-SS-B1 OR 4300 Cherry Creek Drive South (303) 692-3148 Denver, CO 80246-1530 APCD Main Phone Number Make check payable to: (303) 692-3150 Colorado Department of Public Health and Environment COLORADO Form APCD-211 - Gas Venting APEN - Revision 12/2019 6 °`°"°"� ""xwv,a en..afft TOTAL EMISSIONS SUMMARY Company: Bayswater Exploration&Production,LLC Facility Name: Leffler 13,14,23,24-26NHZ,B-26CHZ,P-26NHZ Tank Battery Facility Location: Weld County,Colorado UNCONTROLLED POTENTIAL EMISSIONS SUMMARY APEN/Permitted Sources Source NOx CO VOC HAPs lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr Condensate Tanks(TK-001-TK-014)and Enclosed 44.46 194.74 1.44 7.58 Flares(EC-001-EC-002) Produced Water Tanks(PW-001-PW-004)and 4.40 19.28 0.26 1.13 Enclosed Flares(EC-003) --- VRT Gas(VRT-001)and Enclosed Flares(EC-001- --- --- --- --- 15.73 68.89 0.40 1.73 EC-002) LP Separator Gas(LP-SEP001)and Enclosed Flares --- --- -- --- 43.18 189.14 1.42 6.22 (EC-001-EC-002) Hydrocarbon Loadout(TL-001) --- --- --- --- 2.97 12.99 0.04 0.17 Produced Water Loadout(TL-002) --- --- --- --- 0.75 3.28 0.00 0.02 Gas Lift Engine(ENG-003) 13.503 59.14 14.74 64.58 1.10 4.83 0.17 0.74 Gas Lift Engine(ENG-004) 1.521 6.66 7.55 33.05 3.38 14.79 1.36 5.95 TOTAL(APEN/Permit Applicable)= 15.02 65.81 22.29 97.62 115.97 507.94 5.09 23.54 APEN/Permit Exempt Sources Source NOx CO VOC HAPs lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr Heaters(H-001-H-015) 1.379 6.04 1.158 5,07 0.0758 0.332 0.0259 0.1135 Fugitive Emissions(FUG-001) --- --- --- --- 0.16 0.68 0.0028 0.012 Total Potential to Emit= 16.40 71.8 23.45 102.7 116.20 - 509.0 5.12 23.7 • CONTROLLED POTENTIAL EMISSIONS SUMMARY APEN/Permitted Sources Source NOx CO VOC HAPs lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr Condensate Tanks(TK-001-TK-014)and Enclosed 0.186 0.81 0.842 3.69 2.22 9.74 0.072 0.316 Flares(EC-001-EC-002) Produced Water Tanks(PW-001-PW-004)and 0.007 0.031 0.026 0.12 0.22 0.96 0.01 0.06 Enclosed Flares(EC-003) VRT Gas(VRT-001)and Enclosed Flares(EC-001- 0.038 0.17 0.0014 0.006 0.79 3.44 0.020 0.09 EC-002) LP Separator Gas(LP-SEP001)and Enclosed Flares (EC-001-EC-002) 0.18 0.81 0.84 3.67 2.16 9.46 0.07 0.31 Hydrocarbon Loadout(TL-001) 0.01 0.024 0.02 0.09 0.29 1.27 0.00 0.02 Produced Water Loadout(TL-002) 0.00 0.0073 0.00 0.02 0.07 0.32 0.00 0.00 Gas Lift Engine(ENG-003) 0.96 4.22 2.07 9.05 0.96 4.22 0.17 0.74 Gas Lift Engine(ENG-004) 1.52 6.66 2.25 9.86 2.13 9.33 0.93 4.08 TOTAL(APEN/Permit Applicable)= 2.91 12.74 6.05 26.50 8.85 38.75 1.28 5.61 i APEN/Permit Exempt Sources Source NOx CO VOC HAPs lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr Heaters(H-001-H-015) 1.38 6.04 1.16 5.07 0.076 0.33 0.026 0.11 Fugitive Emissions(FUG-001) --- --- --- --- 0.16 0.68 0.0028 0.012 Total Potential to Emit= 4.29 18.78 7.21 31.58 9.08 39.76 1.31 5.74 I NOTE:Tank emissions will be controlled by an enclosed flare with a control efficiency of 95%.Loadout emissions will be routed back to the tank battery through a vapor balance system with a capture efficiency of 95%and then onto the enclosed flare with a control efficiency of 95%. 20203087/DEN20O 111567 2020 Copyright 2020 Kleinfelder Page 1 of 5 April.com www.kleinfelder.com Estimated VRT Off Gas Composition Company. Bayswater Exploration&Production,LLC Facility Name: Calvary Farms South Tank Battery Location: Weld County,Colorado Unit lD: Fuel Type Natural Gas Heat Value(wet): ., Btu/sof Venting Volumes Total Daily Volume' I Mscfd Total Daily Liquid Volume' J bbl/d 1.)Total daily volume assumes the VRU that takes the vapors from the VRT will be down 7%of the year.Vapor ad Liquid volume is estimated using Promax Component Net Component Component Requested Component Male Mole MoleWeight Flow Flow Emission Percent Weight Weight Fraction Rate .. Rate Rate (Ib/Ib-mol) (Ib/ib-mol) Illa/Y0 (tPY) )tPY) Methane 20.42 16.04 3.28 0.087 , 1577541 7.89 9.47 Ethane 31.69 30.07 ' 9.53 0.254 45886.68 22.94 27.53 Propane 28.82 44.10 12.708 0,34 61200.94 30.60 36.721 _I-Butane 3,30 58.12 1.92 0.051 9251.47 4.63 5.55 n-Butane 6.95 58.12 4.04 0.11 19451.40 9.73 11.67 I-Pentane 1.73 72.15 1.25 0.033 6018.17 3.01 3.611 n-Pentane 2.29 72.15 1:65 0.04 7963.73 3,98 4.78 Hexanes 1.14 86.18 0.98 0.026 4726.79 2.36 2.84 Heptanes 0.50 100.20 ' 0.50 0.013 2398.08 1.20 1.44 Octanes 0.13 114.23 0.15 0.004 725.01 0.36 0.44 Nonanes 0.03 128.26 0.04 0.0011 200.37 0.10 0.12 -Demons 0.00 142.29 0.000003 0.00000008 0.01 0.000007 0.000009 2,2,4 Trimethylpentane 0.00 114.23 0.0000 0.0000000 0.00 0.000 0.000 Benzene 0.08 78.12 0.06 0.0017 312.09 0.16 0.19 Toluene 0.07 92.13 0.06 0.0016 290.32 0.15 0.17 Ethylbenzene 0.01 106.16 0.006 0.00017 31.04 0.016 • 0.019 Xylenes 0.02 106.16 0.017 0.00046 83.33 0.04 0.05 n-Hexane 0.52 86.18 0.45 0.0120 2168.67 1.08 1.3 Helium 0.00 4.00 0,00 0.00 0.00 0,00 000 Nitrogen 0.50 28.01 0.140 0.00372 672.51 0.336 0.404 Carbon Dioxide 1.81 44.01 0.80 0.0212 3838.17 1.92 2.30 Oxygen 0.00 32.00 0.00 0.00 0.00 0.00 0.00 Hydrogen Sulfide 0.00 34.08 0.00 0.00 0.00 0.00 0.00 VOC Total 45.59 23.84 0.63 s 114821.41 57.4107 68.9 HAP Subtotal 0.69 0.599 0.016 2885.44 1.44 1.73 TOTAL 100.0 37.58 1.00 180994.19 90.5 108.6 Note:Gas composition from site-specific model,VRU Gas stream.During VRT downtime,the VRU gas is controlled by a flare with a 95%control efficiency. Uncontrolled Emissions Component Emission Factor Actual Emissions Requested Emissions Ibibbi lb/hr lb/yr tpy lb/hr Iblyr tpy VOC 1.07 13.107 114,821 57.41 15.73 137,785.70 68.89 Benzene 0.0029 0.036 312.09 0.156 0.043 374.51 0.187 Toluene 0.0027 0.033 290.32 0.145 0.040 348.38 0.174 Ethylhenzene 0.00029 0.0035 31.04 0.016 0.0043 _ 37.25 0.019 Xylenes 0.00078 0.0095 83.33 0.042 0.011 100.00 0.050 n-Hexane 0.020 0.248 2,168.67 1.08 0.30 2,602.40 1.30 2,2,4 Trimethylpentane 0.000000 0.000000 0.00 0.00000 0.000000 0.00 0.00000 Total HAPs 0.027 0.329 2885.4 1.44 0.395 3463 1.73 Controlled Emissions C id rr''16ns Emission Factor Actual Emissions Requested Emissions Ibibbi lb/hr lb/yr : tpy lb/hr Ib/yr tpy VOC 0.054 0.655 5,741 2.87 0.79 6,889 3.44 Benzene 0.00015 ' 0.00178 15.60 0.008 0.00214 18.73 0.009 Toluene 0.00014 0.00166 14.52 0.007 0.0020 17.42 0.009 Ethylbenzene 0.000014 0.00018 1.55 0.001 0.00021 1.86 0.001 Xylenes 0.000039 0.00048 4.17 0.002 0.00057 5.00 0.002 n-Hexane 0.0010 0.0124 108.43 0.054 0.0149 130.12 0.07 2,2,4 Trimethylpentane 0.000000 0.0000000 •0.000 0.000 0.0000000 0.00 0.000 Total HAPs 0.0013 0.0165 144.3 0.07 0.0190 173 0.09 Calculations are based on a representative natural gas analysis. Relative Male Weight(lb/lb-mole)_ [Mole Percent'Molecular weight(lb/hi-mole)]/100 Weight Fraction= Net Male Weight/Total Mole Weight 20203087/DEN20O111567 April 2020 Copyright 2020 Kleinfelder Page 2 of 5 , www.klelnfelder.com Flaring Emissions Company: Bayswater Exploration&Production,LLC Facility Name: Leffler 13,14,23,24-26NHZ,B-26CHZ,P-26NHZ Tank Battery Location: Weld County,Colorado Source Description Enclosed Flare for Condensate Storage Tanks,Truck Loadout,VRT,&Heated Separator Source Information Emission Calculations-Pilot Burner Unit ID i..,:,-(r k: .,,, Emission:Factor Estimated Emissions Emission Factor Pollutant Source Description /,,,„ (Ib/MMsef) (tpt0° Source Hours of Operation hr/yr NOx 100.0 0.015 AP-42 Ch.1.4 Table 1.4-1 Fuel Consumption' scf/hr CO 84.00 0.012 AP-42 Ch.1.4 Table 1.4-1 Estimated Fuel Heat Value' .. BtWscf VOC 5.50 0.00080 AP-42 Ch.1.4 Table 1.4-2 Fuel Use 0.22 MMscf/yr PM 10 7.60 0.0011 AP-42 Ch.1.4 Table 1.4-2 HAPs 1.88 0.00027 AP-42 Ch.1.4 Table 1.4-3 • Estimated Tank Emissions Information Condensate Tank Waste Stream Emissions Unit ID - : .. I. Pollutant Emission Factor Estimated Emissions Emission Factor Estimated Condensate Production' bbl/yr (IWMMBtu) (tpy) Source Estimated Production 2,084 bbl/day NOx 0.068 0.404 AP-42,Ch.135 Table 13.5.1 Estimated Gas to Oil Rat o° scf/bbl CO 0.31 1.84 r AP-42 Ch 13 5,Table 13.5.1 Esimated Emissions Rate 572.35 scf/hr Estimated Flash Gas Heat Value' Btu/scf Condensate Loadout Waste Stream Emissions Estimated Hydrocarbon Loadout Production r bbl/yr Emission Factor Estimated Emissions Emission Factor Estimated Production 208 hhl/da Pollutant Y (ltilMMetu) (1pY) Source Esimated Emissions Rater 13.50 scf/hr NOx 0.068 0.010 AP-42.Ch.13.5,Table 13.5.1 Estimated Gas Heat Value Blu/scf - CO 0.31 0.04 AP-42,Ch.13.5,Table 13.5.1 VRT Gas to Flare' scf/hr VRT Gas Heat Value' , Blu/scf VRT Waste Stream Emissions VRT Gas Emissions Heat Input 0.27 MMBtu/hr Emission.Factor Estimated Emissions Emission.Factor Pollutant Heated Separator Gas to Flare' sef/hr (1b/NIMBtu) (tpy) Source:.::. Heated Separator Gas Heat Value' Btu/scf NOx 0.068 0.080 AP-42,Ch.13.5.Table 13 5.1 Heated Separator Gas Emissions Heat Inpu 1.35 _ MMBtu/hr CO 0.31 0.0010 AP-42.Ch.13.5.Table 13 5.1 Yank Emissions Heat Input- 1.39 1v1MBtulhr Heated Separator Stream Emissions 1)Estimated based on manufacturer data for similar combustors Emission'Factor Estimated Emissions Emission Factor' 2)Fuel H Valu Is eat e calculated from a representative met analysts. pollyfant.' (IbtMMBtu) (tpy)" Source 3)Estimated production Is the site total requested production evenly divided by the number of NOx 0.068 0.40 AP-42,Ch.13 5,Table 13 5.1 flares for storage tanks and condensate truck loading in service. CO 0.31 1.83 AP-42,Ch.13.5,Table 13.5.1 4)The GOR Is calculated from a representative ProMax model. 5)The flash gas heat value Is calculated from the flash gas and W&B gas composition from a Total Potential Combustor Eit1lsslons representative ProMax model. Estimated Emissions Estimated Emissions 5)In accordance With AP-42,Chapter/.4 guidance,the emissions factors are converted to the Pollutant (lb/hr) (tiny) specified fuel heating value by multipling the emission factor by the ratio of the specified heat NOx 0.21 0.91 value to the delait heat value of 1,020 Btu/scf. CO 0.85 3.73 7)Condendsate truck loading flow calculated based on assumption 95%of captured vapors from VOC 0.00018 0.00080 vapor balance system. PM 10 0.00025 0.0011 HAPs 0.000062 0.00027 - Sample Calculations: Pilot Emissions Fuel Consumption(MMscf/yr)= Pilot Fuel Consumption(sof/hr)•8.760(hra/vrl•MMscf/10'scf Emissions(tons/yd.. AP-42 Emission Factor(Ib/MMscf)•Fuel Consumption(MMscf/yr)•1 ton/20001bs•Estimated Fuel Heat Value(Btu/sop/Default Fuel Heat Value(Btu/s<0 Tank Emissions Tank Emissions Rate(sef/hr)= Estimated Production(bbl/day)•GOR(scf/bbl)•1 day/24 his .Flash Gas Heal Input(MMBtWhr)= Tank Emissions Rate(scf/hr)•Estimated Flash Gas Heat Value(BWlsof)•1 MMBtu/10°Btu Emissions(tons/yr)= AP-42 Emission Factor(Ibs/MMBtu)•Flash Gas Heat Input(MMBtWhr)•1 ton/2000 lbs • 20203087/DEN200111567 - -- April 2020 Copyright 2020 Kleinfeider Page 3 of 5 www.kleinFelder.com • Flaring Emissions Company: Bayswater Exploration&Production,LLC Facility Name: Leffler 13,14,23,24-26NHZ,B-26CIIZ,P-26NHZ Tank Battery Location: Weld County,Colorado Source Description Enclosed Flare for Storage Tanks,Truck Loadout,VRT,&Heated Separator Source Information Emission Calculations-Pilot Burner Unit ID ameIt.C U7?.i Emission Factor Estimated Emissions Emission Factor Pollutant • Source DescriptionCombo-Aim Pik ii (IWMMse() (tr a Source Hours of Operation 1.,Vi hr/yr NO, 100.0 0.015 AP-42 Ch.1.4 Table 1.4-1 Fuel Consumption' /PP scf/hr CO 84.00 0.012 AP-42 Ch.1.4 Table 1.4-1 Estimated Fuel Heat Value' 1.314 Btu/scf VOC 5.50 0.00080 AP-42 Ch.1.4 Table 1.4-2 Fuel Use 0.22 Mt/sof/yr PM 10 7.60 0.0011 AP-42 Ch.1.4 Table 1.4-2 HAPs 1.88 0.00027 AP-42 Ch.1.4 Table 1.4-3 Estimated Tank Emissions Information Condensate Tank Waste Stream Emissions Unit ID ' -: Emission Factor Estimated Emissions. Emission Factor Pollutant Estimated Condensate Production' 7x:-: bolyr (IWMMBtu) (toy) Source Estimated Production 2,084 bbl/day NO, 0.008 0.404 AP-42,Ch.13.5,Table 13.5.1 Estimated Gas to Oil Ratio° - scf/bbl CO 0.31 1.84 AP-42,Ch.13.5,Table 13.5.1 Esimated Emissions Rate _ 572.35 sot/hr , Estimated Flash Gas Heat Value' <.s/4 Btu/scf Condensate Loadout Waste Stream Emissions Estimated Hydrocarbon Loadout Production bbi/yr Pollutant Emission Factor Estimated Emissions Emission Factor Estimated Production 208 b8/day (lb/MMEItia) (tpy). Source Esimated Emissions Rate' 13 50 sof/hr NO, 0.068 0.010 AP-42,Ch.13.5,Table 13.5.1 Estimated Gas Heat Value Btu/scf CO 0.31 0.04 AP-42,Ch.13.5,Table 13.5.1 VRT Gas to Flare' - sc8hr VRT Gas Heat Value' - - Btu/scf VRT Waste Stream Emissions VRT Gas Emissions Heat Input 027 MMBtu/hr Emission:Factor Estimated Emissions : Emission Factor __ Pollutant Heated Separator Gas to Flare' scf/hr (lb/MS/Btu) _ (toy) Source Heated Separator Gas Heat Value' Btu/scf NO, 0.068 0.080 AP-42.Cl.13 5,Table 13.5.1 Heated Separator Gas Emissions Heat Inpu 1.351 MMBtu/hr CO 0.31 0.0010' AP-42,Cl,13.5,Table 13.5.1 rank Emissions Heat Input 1.39 )0MBtu/hr Heated Separator Stream Emissions 1)Estimated based on manufacturer data for similar combustors. Emission Factor` Estimated Emissions Emission Factor 2)Fuel Heat Value is calculated from a representative fuel analysis. Pollutant (lb/MMBtu). (158) Source 3)Estimated production is the site total requested production evenly divided by the number of NO, 0-068 0.40 AP-42.Cl,.13.5,Table 13.5.1 flares for storage tanks and condensate truck loading in service. CO 0.31 1.83 AP-42,Cl.13.5,Table 13.5.1 4)The GOR Is calculated from a representative ProMax model. 5)The flash gas heat value is calculated from the gash gas and W&B gas composition from a Total Potential Combustor Emissions representative ProMax model Estimated Emissions Estimated Emissions 6 in accordance with AP-42,Chapter 1.4 (dance,the emissions factors are converted to the Pollutant 1 P 9u (Ib/hr).. (tP1/) specified fuel heating value by multipling the emission factor by the ratio of the specified heat NO, 0.21 0.91 value to the defait heat value of 1,020 Btu/scf. CO 0.85 3.73 7)Ceodendsate truck loading flow calculated based on assumption 95%of captured vapors from VOC 0.00018 0.00080 vapor balance system. PM 10 0,00025 0.0011 HAPs 0.000083 0.00027 Sample Calculations: . Pilot Emissions Fuel Consumption(MMscf/yr)= Pilot Fuel Consumption lsef/hr)'8,760 ihrs/yr)'MMscf/t0a eel Emissions(tons/yr)= AP-42 Emission Factor(Ib/MMeot)•Fuel Consumption(MMscf/yr)'1 ton/2000 lbs'Estimated Fuel Heat Value(Bturscf)/Default Fuel Heat Value(Btu/sof) Tank Emissions Tank Emissions Rate(scf/hr)= Estimated Production(bbl/day)'GOR(scf/bbl)'1 day/24 hrs Flash Gas Heat Input(MM0tu/hr)= Tank Emissions Rate(scf/hr)'Estimated Flash Gas Heat Value(Blu/scg'1 MMBtu/10'Btu Emissions(tons/yr)= AP-42 Emission Factor(Ibs/MMBtu)•Flash Gas Heat Input(MMBtu/hr)•1 ton/2000 lbs 20203087/DEN20O111567 April2020 Copyright 2020 Kleinfelder Page 4 of 5 www.kleinfelder.com VRT Flash Gas Composition Company: Bayswater Exploration&Production,LLC Facility Name: Leffler 13,14,23,24-26NHZ,B-26CHZ,P-26NHZ Tank Battery Location: Weld County,Colorado Fuel Type: VRT Waste Gas Heat Value(wet)': ✓.." Btu/sof C1-C2 Wt.Fraction: 0.341 VOC Wt.Fraction: 0.63 Non-HC Wt.Fraction: 0.0249 Total: 1.00 . ''COMPONENT .MOLE _.. COMPONENT -.. NET , WEIGHTS,-: ., -HO RC COMPONENT 'PERCENT. MOLE MOLE FRACTION ' :.NETMOLE WEIGHT WEIGHT WEIGHT ''..'.WEIGHT. FRACTION (lbllb-mole) . (lb/lb-mole) _ : ' r. (i6t14'mdte) Methane 20.42 16.04 3.276 0.0872 3.276 0.0894 Ethane 31.69 30.07 9.53 0.254 9.53 0.260 Propane 28.82 44.10 12.71 0.34 12.71 0.35 i-Butane 3.30 58.12 1.92 0.051 1.92 0.052 n-Butane 6.95 58.12 4.04 0.11 4.04 0.11 i-Pentane 1.73 72.15 1.25 0.033 1.25 0.034 n-Pentane 2.29 72.15 1.654 0.044 1.654 0.045 Hexanes 1.14 86.16 0.98 0.020 0.98 0.027 Heptaneu* 0.50 100.20 0.50 0.013 0.50 0.014 Octanes 0.13 114.23 0.15 0.0040 0.15 0.0041 Nonanes 0.032 128.26 0.04 0,0011 0.04 0.0011 Dacanes 2.19E-06 142.29 3.109E-06 8.27E-08 3.109E-06 8.48E-08 2,2,4Trimethylpentane 0.0000 114.23 0.0000 0.00000 0.0000 0.00000 Benzene 0.08 78.12 0.06 0.0017 0.065 0.0018 Toluene 0.07 92.13 0.06 0.0016 0.060 0.0016 Ethylbenzene 0,006 106.16 0.006 0.00017 0.006 0.00018 Xylenes 0.016 106.16 0.017 0.00046 0.017 0.00047 n-Hexane 0.52 86.18 0.45 0.012 0.45 0.012 Helium 0,00 4.00 0.00 0.00 — -- Nitrogen 0.4985 28.01 0.1396 0.003716 -- -- Carbon Dioxide 1.81 44.01 0.80 0,0212 -- -- Oxygen 0.00 32.00 0.00 0.00 -- -- Hydrogen Sulfide 0,00 34.08 0.00 0.00 -- -- TOTAL 100.0 37.56 1.00 36,64 1.00 1)The heating value is the weighted average of the flash gas heating value and W&B vent gas heating value from the output of the ProMax 5.0 model. 2)The mole percent is weighted average of the Flash Gas and W&B emissions generated from the output the ProMax 5.0 model. Relative Mole Weight db/lb-mole)= [Mole Percent'Molecular weight(Ib/bl-mole)]/100 • Weight Fraction= Net Mole Weight/Total Mole Weight 20203087/DEN20O111567 Pa 5of 5 April 2020 Copyright 2020 Kleinfelder 9e wvrri.kleinfelder.com R esearc l&Engineering,LLC e g a® } [BR&EJ ProMax® 5.Q S t s < z s L2oI7vn9ht©2aoaoLQ6Re Group Ltd,`Ali Rights Reserved Simulation Report Project: ProMax_GD Hanks.pmx Licensed to Kleinfelder, Inc.and Affiliates Client Name: Bayswater Exploration&Production,LLC Location: Weld County Job: Leffler HZ ProMax Filename: C:\Userstmbangert\AppData\Local\Microsoft\Windows\INetCache\Content.Gutlook\PSNVO9KD1ProMax_GD Hanks.pmx ProMax Version: 5.0.19263,0 Simulation Initiated: 7/8/2020 2:11:53 PM Bryan Research&Engineering,LLC Chemical Engineering Consultants P.O.Box 4747 Bryan,Texas 77805 Office:(979)776.5220 FAX;(979)776-4818 aiit sal s(n?k}t}iu„uom ritt„J1e vtt+,trl .crrrrr1 Report Navigator can be activated via the ProMax Navigator Toolbar. An asterisk(*),throughout the report,denotes a user specified value. A question mark(?)after a value,throughout the report,denotes an extrapolated or approximate value. Al , VRU.Gas Uncontrolled Rash Gas Pressurized Liquid-- >. rrt,mr,..„„:4440,.„,,,,,„„,„, `� Q-1 t�ha „" r 3 10 x 500 bbl Oil Tanks { 1 VSSL +d r0-Tank k-- µms` Properties Oil • Std Liquid Volumetric Flow(Total) 4169" bbl/d Process Streams Oil Pressurized Liquid VRU Gas 1 Composition Status: Sated SOiV21 Solved $rl;ed Phase Tu„:.z From Block: 10 x 500 bbl Oil Tanks — VSSL-100 VSSL-100 To Block: -- VSSL-160 -- .10 x 500 bbl Oil Tanks Mole Fraction I -%. Carbon Dioxide 0.0169302 0.0748998* 1.81083 0.0374637 Nitrogen 0.000112412 0.0119000* 0.498476 0.00140673 Methane 0.0349749 0.590598* 20.4173 0.163025 Ethane 1.14742 2.27659* 31.6853 1.64442 Propane 4.75966 5.70418' 28.8173 5.20574 Isobutane 1.41997 1.49410* 3,30496 1.45504 n-Butane 6.02397 6.06528* 6..94875 6.04623 Isopentane 2.70660 2.67289* 1.73194 2.69318 n-Pentane 4.37842 4.29819* 2.11288 4.34531 Cyclopentane 0.525668 0.513398* 0.178964 0.520611 n-Hexane 3.50202 3.39619* 0.522523 3.45816 Cyclohexane 1.49801 1.45110* 0.172189 1.47868 2-Methylpentane 4.57327 4.44519* 0.966695 4.52020 n-Heptane 6.97054 6.73728* 0.363359 6.87474 Methylcyclohexane 2.59950 2.51249* 0.133557 2.56380 2,2,4-Tdmethylpentane 0 0' 0 0 Benzene 0.627589 0.608298* 0.0829511 0.619628 Toluene 1.64165 1.58610* 0.0654294 1.61889 Ethylbenzene 0.455084 0.439299* 0.00607096 0.448641 o-Xylene 1.57134 1.51670* 0.0162983 1.54905 n-Octane 7.62477 7.36116* 0.131784 7.51708 n-Nonane 5.74118 5.54068* 0.0324386 5.65947 Decanes+ 42.1813 40.7015* 2.18502E-06 41.5792 VRT Decanes+ 0 0' 0 0 Molar Flow lbmol/h Ibmol/h Ibmol/h Ibmot/h Carbon Dioxide 0.0510866 0.234226* 0.119543 0.114683 Nitrogen 0.000339202 0.0372136* 0.0329073 0.00430624 Methane 0.105536 1.84692* 1.34787 0.499050 Ethane 3.46234 7.12561* 2.09173 5.03388 Propane 14.3622 17.8381* 1.90240 15.9357 Isobutane 4.28476 4.67233* 0.218180 4.45415 n-Butane 18.1773 18.9673* 0.458728 18.5086 Isopentane 8.16715 8.35866* 0.114335 8.24433 n-Pentane 13.2118 13.4413" 0.139483 13.3018 Cyclopentane 1.58620 1.60550* 0.0118145 1.59368 n-Hexane 10.5673 10.6206" 0.0344948 10.5861 Cyclohexane 4.52024 4.53786" 0.0113672 4.52650 2-Methylpentane 13.7996 13.9010" 0.0638172 13.8372 n-Heptane 21.0335 21.0688* 0.0239874 21.0448 Methylcyclohexane 7.64396 7.85706* 0.00881685 7.64825 2,2,4-Trimethylpentane 0 0" 0 0 Benzene 1.89374 1.90227* 0.00547609 1.89679 Toluene 4.95367 4.96003* 0.00431938 4.95572 Ethylbenzene 1.37321 1.37377*0.000400779 1.37337 o-Xylene 4.74151 4.74301* 0.00107595 4.74193 n-Octane 23.0077 23.0199* 0.00869984 23.0112 n-Nonane 17.3239 17.3268* 0.00214146 17.3247 Decanes+ 127.282 127.282* 1.44246E-07 127.282 VRT Decanes+ 0 0* 0 0 Mass Fraction - % % % % Carbon Dioxide 0.00466285 0.0211925" 2.12119 0.0104296 Nitrogen 1.97071E-05 0.00214322" 0.371677 0.000249279 Methane 0.00351132 0.0609142* 8.71818 0.0165438 Ethane 0.215917 0.440496* 25,3590 0.312783 Propane 1.31345 1.61713* 33,8224 1.45207 Isobutane 0.516495 0.558311* 5.11287 0.534968 n-Butane 2.19113 2.26646* 10.7499 2.22298 Isopentane 1.22207 1.23984* 3.32596 1.22915 n-Pentane 1.97693 1.99375* 4.05750 1.98317 Cyclopentane 0.230715 0.231490* 0.334074 0.230964 n-Hexane 1.88862 1.88161* 1.19852 1.88512 Cyclohexane 0.768973 0.785154* 0.385713 0.787201 2-Methylpentane 2.46634 2.46280' 2.21732 2.46406 n-Heptane 4.37105 4.34027* 0.969097 4.35754 Methylcyclohexane 1.59729 1.58603* 0.349036 1.59237 2,2,4Trimethylpentane 0 0* 0 0 Benzene 0.306786 0.305484* 0.172462 0.306166 Toluene 0.946598 0.939563' 0.160461 0,943556 Ethylbenzene 0.302355 0.299845* 0.0171551 0.301294 o-Xylene 1.04399 1.03523' 0.0460554 1.04030 n-Octane 5.45061 5.40602* 0.400676 5.43167 n-Nonane 4.60807 4.56871* 0.110737 4.59156 Decanes+ 68.5544 67.9576* 1.51037E-05 68.3059 VRT Decanes+ 0 0* 0 0 Mass Flew Ib/h. Ib/h lb/h - Ib/h Carbon Dioxide 2.24829 10.3082* 5.26104 5.04715 Nitrogen 0.00950220 1.04248* 0.921846 0.120633 Methane 1.69306 29.6291' 21.6231 8.00599 Ethane 104.109 214.260* 62.8963 151.364 Propane 633.310 - - 786.583* 83.8874 702.695 Isobutane 249.040 271.566* 12.6811 258.885 n-Butane 1056.50 1102.42* 26.6623 1075.76 Isopentane 589.250 603.067* 8.24916 594.818 n-Pentane 953.218 969.772* 10.0635 959.709 Cyclopentane 111.245 112.598' 0.828582 111.770 n-Hexane 910.641 915.231" 2.97260 912.258 Cyclohexane 380.421 381.904* 0.956658 380.948 2-Methylpentane 1189.20 1197.92' 5.49947 1192.42 n-Heptane 2107.60 2111.14' 2.40359 2108.73 Methylcyclohexane 770.168 771.454* 0.865692 770.588 2,2,4-Tdmethylpentane 0 0' 0 0 Benzene 147.924 148.590' 0.427747 148.162 Toluene 456.424 457.010' 0.397981 456.612 Ethylbenzene 145.787 145.847' 0.0425487 145.804 o-Xylene 503.382 503.541* 0.114228 503.427 n-Octane 2628.13 2629.53' 0.993770 2628.53 n-Nonane 2221.88 2222.25* 0.274654 2221.98 Decanes+ 33055.0 33055.0* 3.74606E-05 33055.0 VRT Decanes+ 0 0* 0 0 Process Streams Oil Pressured Liquid VRU Gas 1 Properties Status: So€r d so=,�u Sc � Phase eta! From Block: 10 x 500 bbl Oil Tanks — VSSL-100 VSSL-100 To Block: - VSSL•100 -- 10 x 500 bbl Oil Tanks Property Units _ Temperature 'F 50.23* 117* 92* 92 Pressure psig 0' 59.4* 17* 17 Mole Fraction Vapor % 0 0 100 0 Mole Fraction Light Liquid % 100 100 0 100 Mole Fraction Heavy Liquid % 0 0 0 0 Molecular I/Veight Ib/Ibmol 159.793 155.541 37.5703 158.085 Mass Density Ib/ft^3 49.2804 47.2415 0.188880 48.0495 Molar Flow Ibmol/h 301.749 312.720 6.60158 306.118 Mass Flow lb/h 48217.2 48640.7 248.023 48392.7 Vapor Volumetrc Flow ft^3/h 978.425 1029.62 1313.13 1007.14 Liquid Volumetric Flow gpm 121.985 128.368 163.715 125.566 Std Vapor Volumetric Flow MMSCFD 3.26966 3.38854 0.0715328 3.31701 Old Liquid Volumetric Flow sgpm 121.596* 123.387 1.05840 122.329 Compressibility 0.00718184 0.0380502 0.978379 0.0161827 Specific Gravity 0.789610 0.756941 1.29720 0.769887 API Gravity 47.7023 48.2444 47.9303 Enthalpy Btu/h -4.13357E+07 -4.02965E+07 -288813 -4.05862E+07 Mass Enthalpy Btu/lb -857.281 -828.452 -1164.46 -838.686 Mass Cp Btu/(Ib'°F) 0.469117 0.508808 0.422066 0.493712 Ideal Gas CpCv Ratio 1.03649 1.03346 1.14513 1.03430 Dynamic Viscosity cP 1.70009 0.662806 0.00925712 1.09607 Kinematic Viscosity c5t 2.15366 1.14017 3.05964 1.42406 Thermal Conductivity Btu/(h`ft'°F) 0.0726646 0.0680397 0.0126384 0.0698476 Surface Tension Ibf/ft 0.00180467? 0.00163480? 0.00178079? Net Ideal Gas Heating Value Btu/ft^3 8034.49 7823.94 1974.31 7950.09 Net Liquid Heatng Value Btu/lb 18560.7 18568.7 19437.3 18564.2 • Gross Ideal Gas Heating Value Btu/ft^3 8589.03 8365.39 2151.20 8499.40 Gross Liquid Heating Value Btu/lb 19852.9 19864.9 21191.3 19858.1 Flowsheet Environment Report G&D Hanks Client Name: Bayswater Exploration&Production,LLC IJob: ILeffler HZ Location: Weld County Flowsheet: Leffler HZ :a Environment Settings Number of Poynting Intervals 0 Phase Tolerance 1 % Gibbs Excess Model Evaluation Temperature 77 °F Emulsion Enabled FALSE Freeze Out Temperature Threshold Difference 10 °F Emulsion Enabled FALSE Components Component Henry's Law Comp. Phase Initiator'Component Henry's Law Comp: Phase Initiator Carbon Dioxide FALSE FALSE Nitrogen FALSE FALSE Methane FALSE FALSE Ethane FALSE FALSE Propane FALSE FALSE Isobutane FALSE FALSE n-Butane FALSE FALSE Isopentane FALSE FALSE n-Pentane FALSE FALSE Cyclopentane FALSE FALSE n-Hexane FALSE FALSE Cyclohexane FALSE FALSE 2-Methylpentane FALSE FALSE n-Heptane FALSE FALSE Methylcyclohexane FALSE FALSE 2,2,4-Trimethylpentane FALSE FALSE Benzene FALSE FALSE Toluene FALSE FALSE Ethylbenzene FALSE FALSE o-Xylene FALSE FALSE n-Octane FALSE FALSE n-Nonane FALSE FALSE Decanes+ FALSE FALSE IVRT Decanes+ FALSE FALSE Physical Property Method Sets Liquid Molar Volume COSTALD Vapor Package Peng-Robinson Overall Package Peng-Robinson Light Liquid Package Peng-Robinson Stability Calculation Peng-Robinson Heavy Liquid Package Peng-Robinson Notes: Environments Report Client Name: Bayswater Exploration&Production,LLC ]Job: (Leffler HZ Location: Weld County Flowsheet: Project-Wide Constants Atmospheric Pressure 12.12 psia Ideal Gas Reference Volume 451.488 ftA3/Ibmol Ideal Gas Reference Pressure 12.12 psia Liquid Reference Temperature 50.23 °F Ideal Gas Reference Temperature 50.23 °F G&D Hanks Environment Settings Number of Poynting Intervals 0 Phase Tolerance 1 % Gibbs Excess Model Evaluation Temperature 77 °F Emulsion Enabled FALSE Freeze Out Temperature Threshold Difference 10 °F Emulsion Enabled FALSE Components Component Henry's Law Comp. Phase Initiator'Component Henry's Law Comp. Phase Initiator Carbon Dioxide FALSE FALSE Nitrogen FALSE FALSE Methane FALSE FALSE Ethane FALSE FALSE Propane FALSE FALSE Isobutane FALSE FALSE n-Butane FALSE FALSE Isopentane FALSE FALSE n-Pentane FALSE FALSE Cyclopentane FALSE FALSE n-Hexane FALSE FALSE Cyclohexane FALSE FALSE 2-Methylpentane FALSE FALSE n-Heptane FALSE FALSE Methylcyclohexane FALSE FALSE 2,2,4-Trimethylpentane FALSE FALSE Benzene FALSE FALSE Toluene FALSE FALSE Ethylbenzene FALSE FALSE o-Xylene FALSE FALSE n-Octane FALSE FALSE n-Nonane FALSE FALSE Decanes+ FALSE FALSE VRT Decanes+ FALSE FALSE Physical Property Method Sets Liquid Molar Volume COSTALD Vapor Package Peng-Robinson Overall Package Peng-Robinson Light Liquid Package Peng-Robinson Stability Calculation Peng-Robinson Heavy Liquid Package Peng-Robinson Notes: Single Oil Report Decanes + Client Name: Bayswater Exploration&Production, LLC 'Job: 'Lef@er HZ Location: Weld County Flowsheet: Properties Volume Average Boiling Point 617.252 °F Low Temperature Viscosity 5.15184 cP Molecular Weight 259.7* Ib/Ibmol Temperature of High T Viscosity 210 °F Specific Gravity 0.851* High Temperature Viscosity 1.49663 cP API Gravity 34.7750 Watson K 12.0448 Critical Temperature 922.392 °F ASTM D86 10-90%Slope 0 °F/% Critical Pressure 200.524 psig ASTM D93 Flash Point 307.704 °F Critical Volume 15.6861 ft^3/Ibmol Pour Point 38.5969 °F Acentric Factor 0.933308 Paraffinic Fraction 67.4959 % Carbon to Hydrogen Ratio 6.40234 Naphthenic Fraction 24.4641 % Refractive Index 1.47163 Aromatic Fraction 8.04001 % Temperature of Low T Viscosity 100 °F Ideal Gas Heat Capacity 92.0272 Btu/(Ibmol*°F) Notes: ,=r User Specification Summary For Reported Objects Client Name: Bayswater Exploration&Production,LLC 'Job: 1 Leffler HZ Location: Weld County Flowsheet: Flowsheet: Leffler HZ .: PStream:Oil Project!Flowsheets!Leffler HZ!PStreams!Oil!Phases!Total!PropertieslTemperature 50.23 °F ProjectlFlowsheets!Leffler HZIP Streams!Oil!Phases!Total!Properties!Pressure 0 psig Project!Flowsheets!Leffler HZ!PStreams!Oil!Phases!Total!Properties!Std Liquid Volumetric Flow 121 5958333 sgpm PStream:Pressurized Liquid Project!Flowsheets!LefflerHZlPStreams!PressurizedLiquid!Phases!Total!Properties!Temperature 117 °F Project!Flowsheets!Leffler HZ!PStreams!Pressurized Liquid!Phases!Total!Properties!Pressure 59.4 psig Project!Flowsheets!Leffler HZ!PStreams!Pressurized LiquidlPhases!Total!Composition!Mole Fraction Carbon Dioxide 7.49E-02 % Nitrogen 1.19E-02 % Methane 0.590598228 % Ethane 2.278593164 % Propane 5.704182887 % Isobutane 1.494095518 % n-Butane 6.065281804 % Isopentane 2.672891981 % n-Pentane 4.298187105 Cyclopentane 0.51339846 % n-Hexane 3.396189811 % Cyclohexane 1.451095647 % 2-Methylpentane 4.445186664 % n-Heptane 6.737279788 % Methylcyclohexane 2.512492463 % Benzene 0.608298175 % Toluene 1.586095242 % Ethylbenzene 0.439298682 % o-Xylene 1.51669545 % n-Octane 7.361177916 % n-Nonane 5.540683378 % Decanes+ 40.7014779 % PStream VRU Gas Project!Flowsheets!Leffler HZ!PStreams!VRU Gas!Phases!Total!Properties!Temperature 92 °F Project!Flowsheets!Leffler HZ!PStreams!VRU Gas!Phases!Total!Properties!Pressure 17 psig Oils i_.. • Decanes+ . Project!Oils!Decanes+!Properties!Molecular Weight • 259.7 Ib/Ibmol Project!Oils!Decanes+!Properties!Specific Gravity 0.851 -VRT Decanes+ Project!Oils!VRT Decanes+!PropertieslMolecular Weight 261.8 Ib/Ibmol Project!Oils!VRT Decanes+!Properties!Specific Gravity 0.852 5530 Marshall Street Arvada,Colorado 80002 Phone:303-420-5949 A ++ Fax:303-420-5920 op lar— CU TESTING EXTENDED NATURAL GAS LIQUID ANALYSIS SAMPLE DATA PROJECT NO OG-2019-0057 SAMPLE ID Pressurized Liquid COMPANY NAME Bayswater ANALYSIS DATE 3/18/2019 SITE G&D Hanks Tank Battery SAMPLE DATE 3/15/2019 UNIT ID TA-27-28HN CYLINDER NO 37514 SAMPLED BY AJM LAB ANALYST CLB FIELD DATA SAMPLE PROBE PRESSURE(psig) 59.4 SAMPLE PROBE TEMP(°F) 117 UNIT GAUGE PRESSURE(psig) 58 UNIT GAUGE TEMP(°F) 120 AMBIENT PRESSURE(psi) 12.5 AMBIENT TEMP(°F) 25 COMMENTS: LABORATORY DATA COMPONENT MOLE% WT% LV% CARBON DIOXIDE 0.0749 0.0212 0.0205 NITROGEN(AIR) 0.0119 0.0022 0.0020 METHANE. 0.5906 0.0610 0.1602 ETHANE 2.2786 0.4408 0.9753 PROPANE 5.7042 1.6183 2.5151 ISOBUTANE 1.4941 0.5587 0.7825 N-BUTANE 6.0653 2.2681 3.0604 ISOPENTANE 2.6729 1.2407 1.5645 N-PENTANE 4.2982 1.9952 2.4936 CYCLOPENTANE 0.5134 0.2317 0.2433 N-HEXANE 3.3962 1.8830 2.2352 CYCLOHEXANE 1.4511 0.7857 0.7900 OTHER HEXANES 4.4452 2.4421 2.7692 OTHER HEPTANES 6.7373 4.3193 4.8199 METHYLCYCLOHEXANE 2.5125 1.5872 1.6156 2,2,4 TRIMETHYLPENTANE 0.0000 0.0000 0.0000 BENZENE 0.6083 0.3057 0.2722 TOLUENE 1.5861 0.9403 0.8496 ETHYLBENZENE 0.4393 0.3001 0.2712 XYLENES 1.5167 1.0360 0.9339 OTHER OCTANES 7.3612 5.3691 5.7618 NONANES 5.5407 4.5692 4.9099 DECANES PLUS 40.7016 68.0245 62.9542 TOTAL 100.00000 100.00000 100.00000 SAMPLE FRACTIONS TOTAL C6+ C7+ C10+ SPG LIQUID 0.788 0.818 0.826 0.851 API GRAVITY 48.1 41.5 39.7 34.8 MOLECULAR WEIGHT 155.4 186.5 201.7 259.7 ABSOLUTE DENSITY(lbs/gal) 6.6 6.8 6.9 7.1 HEATING VALUE LIQUID IDL GAS(GBTU/gal) 85965.7 128151.1 129164.5 131072.3 GBTU/GAL LIQUID 105495.8 128245.0 128877.7 130039.0 NBTU/GAL LIQUID 127056.1 131275.7 131328.7 135151.1 VAPOR/LIQUID (SCF/gal) 18.1 16.3 15.5 13.7 VAPOR PRESSURE (psia) 65.7 1.0 0.4 0.0 ANALYTICAL PROCEDURES TAKEN FROM GPA-2186,ASTM D6730-01(2011),ASTM D7169,GPA-2103M. Page 1 of 6 1:16 PM,3/19/2019 --' 5530 Marshall Street Arvada,Colorado 80002 Phone:303-420-5949 03-420-5920 AlIiance Fax:303-420-5920 SOURC ... . TESTING EXTENDED NATURAL GAS LIQUID ANALYSIS DHA COMPONENT ANALYSIS SAMPLE DATA PROJECT NO OG-2019-0057 SAMPLE ID Pressurized Liquid COMPANY NAME Bayswater ANALYSIS DATE 3/18/2019 SITE G&D Hanks Tank Battery SAMPLE DATE 3/15/2019 UNIT ID TA-27-28HN CYLINDER NO 37514 SAMPLED BY AJM LAB ANALYST CLB FIELD DATA SAMPLE PROBE PRESSURE(psig) 59.4 SAMPLE PROBE TEMP(°F) 117 UNIT GAUGE PRESSURE(psig) 58 UNIT GAUGE TEMP(°F) 120 AMBIENT PRESSURE(psi) 12.5 AMBIENT TEMP(°F) 25 COMMENTS: LABORATORY DATA COMPONENT MOLE% WT% LV% Air 0.0119 0.0022 0.0020 Carbon Dioxide 0.0749 0.0212 0.0205 Methane 0.5906 0.0610 0.1602 Ethane 2.2786 0.4408 0.9753 Propane 5.7042 1.6183 2.5151 Isobutane . . 1.4941 0.5587 0.7825 n-Butane . 6.0653 2.2681 3.0604 Cyclopentane . 0.5134 0.2317 0.2433 Isopentane 2.6729 1.2407 1.5645 n-Pentane . 4.2982 1.9952 2.4936 Unknown C5s 0.0000 0.0000 0.0000 Neopentane . 0.0000 0.0000 0.0000 Benzene 0.6083 0.3057 0.2722 Methylcyclopentane 1.7387 0.9415 0.9842 Cyclohexane 1.4511 0.7857 0.7900 2,2-Dimethylbutane 0.0215 0.0119 0.0144 Neohexane . 0.0000 0.0000 0.0000 2-Methylpentane 1.5913 0.8823 1.0562 2,3-Dimethylbutane . 0.1586 0.0879 0.1040 3-Methylpentane . 0.9351 0.5185 0.6104 Unknown C6s 0.0000 0.0000 0.0000 n-Hexane . 3.3962 1.8830 2.2352 Toluene 1.5861 0.9403 0.8496 1,1-Dimethylcyclopentane 0.2030 0.1282 0.1331 1,t-3-Dimethylcyclopentane 0.3560 0.2249 0.2352 1,c-3-Dimethylcyclopentane 0.3743 0.2364 0.2483 1,t-2-Dimethylcyclopentane . 0.6424 0.4058 0.4229 Methylcyclohexane 2.5125 1.5872 1.6156 1,c-2-Dimethylcyclopentane . . 0.0832 0.0526 0.0533 Ethylcyclopentane 0.2060 0.1302 0.1330 Cycloheptane 0.0000 0.0000 0.0000 2,2-Dimethylpentane . 0.0225 0.0145 0.0168 2,4-Dimethylpentane 0.1677 0.1081 0.1257 2,2,3-Trimethylbutane . 0.0072 0.0046 0.0053 3,3-Dimethylpentane 0.0256 0.0165 0.0187 2-Methylhexane 0.7071 0.4558 0.5255 2,3-Dimethylpentane 0.3345 0.2157 0.2429 3-Methylhexane 0.8795 0.5670 0.6457 3-Ethylpentane . 0.0667 0.0430 0.0482 n-Heptane 2.5876 1.6682 1.9106 Triptane . 0.0000 0.0000 0.0000 Unknown C7s 0.0740 0.0477 0.0547 Page 2 of 6 1:16 PM,3/19/2019 Styrene 0.0000 0.0000 0.0000 Ethylbenzene 0.4393 0.3001 0.2712 o-Xylene 0.5447 0.3721 0.3314 m-Xylene 0.7752 0.5295 0.4802 p-Xylene 0.1968 0.1344 0.1224 1,1,3-Trimethylcyclopentane 0.0000 0.0000 0.0000 1,t-2,c-4-Trimethylcyclopentane 0.2007 0.1449 0.1518 1,t-2,c-3-Trimethylcyclopentane 0.1901 0.1372 0.1426 1,c-3-Dimethylcyclohexane 0.0270 0.0195 0.0200 1,t-4-Dimetylcyclohexane 0.2115 0.1527 0.1568 1,1-Dimethylcyclohexane 0.0888 0.0641 0.0643 1-Methyl-c-3-ethylcyclopentane 0.0809 0.0584 0.0592 1-Methyl-t-2-ethylcyclopentane 0.2158 0.1558 0.1587 1,1,2-Trimethylcyclopentane 0.1257 0.0907 0.0920 1,c-2,t-4-Trimethylcyclopentane 0.0000 0.0000 0.0000 1,c-2,t-3-Trimethylcyclopentane 0.6344 0.4580 0.4657 1-Methyl-t-3-ethylcyclopentane 0.0722 0.0522 0.0536, 1-Methyl-l-ethylcyclopentane 0.0000 0.0000 0.0000 1,t-3-Dimethylcyclohexane 0.3710 0.2679 0.2674 1,c-4-Dimethylcyclohexane 0.0000 0.0000 0.0000 1,c-2,c-3-Trimethylcyclopentane 0.0000 0.0000 0.0000 Isopropylcyclopentane 0.0403 0.0291 0.0293 1-Ethyl-c-2-methylcyclopentane 0.0000 0.0000 0.0000 1,c-2-Dimethylcyclohexane.... 0.0230 0.0166 0.0164 n-Propylcyclopentane 0.8428 0.6084 0.6140 Ethylcyclohexane 0.0328 0.0237 0.0236 Cyclooctane 0.0000 0.0000 0.0000 n-Octane 1.9697 1.4476 1.6150 Unknown C8s 0.0000 0.0000 0.0000 Dilsobutyl 0.0000 0.0000 0.0000 Isooctane 0.0000 0.0000 0.0000 2,2,4-Trimethylpentane 0.0000 0.0000 0.0000 2,2-Dimethyihexane 0.2154 0.1583 0.1782 2,4-Dimethylhexane 0.1504 0.1106 0.1236 2,5-Dimethythexane 0.0551 0.0405 0.0457 2,2,3-Trimethylpentane 0.0000 0.0000 0.0000 3,3-Dimethylhexane 0.0289 0.0212 0.0234 2,3,4-Trimethylpentane 0.0613 0.0451 0.0491 2,3-Dimethylhexane 0.0953 0.0701 0.0771 2-Methylheptane . 0.8561 0.6292 0.7058 4-Methylheptane 0.2708 0.1990 0.2211 3-Methylheptane 0.4294 0.3156 0.3501 3,4-Dimethyihexane 0.0718 0.0527 0.0574 3-Ethylhexane 0.0000 0.0000 0.0000 C9 5.5407 4.5692 4.9099 C10 5.1237 4.6903 5.0330 C11 3.8852 3.9072 4.1361 C12 3.3087 3.6261 3.7934 C13 3.1822 3.7746 3.6029 C14 2.8369 3.6211 3.4109 C15 2.3268 3.1799 2.9741 C16 1.7997 2.6220 2.4320 C17 1.7120 2.6487 2.4684 C18 1.6915 2.7697 2.5720 C19 1.3868 2.3959 2.1990 C20 1.2348 2.2448 2.0483 C21 0.9617 1.8351 1.6649 C22 0.9866 1.9717 1.7785 C23 0.7962 1.6630 1.4932 C24 0.7456 1.6246 1.4521 C25 0.6891 1.5636 1.3913 C26 0.5955 1.4050 1.2445 C27 0.6025 1.4760 1.3016 C28 0.4900 1.2445 1.0925 C29 0.4692 1.2341 1.0798 C30 0.4663 1.2684 1.1061 C31 0.3040 0.8546 0.7420 C32 0.3192 0.9261 0.8014 C33 0.2476 0.7407 0.6389 C34 0.2678 0.8253 0.7095 C35 0.2454 0.7783 0.6669 C36+ . 4.0264 13.1334 11.1208 TOTAL 100.0000 100.0000 100.0000 Page 3 of 6 1:16 PM,3/19/2019 5530 Marshall Street Arvada,Colorado 80002 Phone:303-420-5949 IaIiCe hone:303-42 5920 SOURCE TESTING EXTENDED NATURAL GAS LIQUIDS ANALYSIS BY CARBON NUMBER SAMPLE DATA PROJECT NO OG-2019-0057 SAMPLE ID Pressurized Liquid COMPANY NAME Bayswater ANALYSIS DATE 3/18/2019 SITE G&D Hanks Tank Battery SAMPLE DATE 3/15/2019 UNIT ID TA-27-28HN CYLINDER NO 37514 SAMPLED BY AJM LAB ANALYST CLB FIELD DATA SAMPLE PROBE PRESSURE(psig) 59.4 SAMPLE PROBE TEMP(°F) 117 UNIT GAUGE PRESSURE(psig) 58 UNIT GAUGE TEMP(°F) 120 AMBIENT PRESSURE(psi) 12.5 AMBIENT TEMP(°F) 25 COMMENTS: LABORATORY DATA COMPONENT MOLE% WT% LV% Air 0.0119 0.0022 0.0020 Carbon Dioxide 0.0749 0.0212 0.0205 C1 0.5906 0.0610 0.1602 C2 2.2786 0.4408 0.9753 C3 5.7042 1.6183 2.5151 C4 7.5593 2.8268 3.8429 C5 7.4845 3.4676 4.3014 C6 9.9008 5.4165 6.0666 C7 10.8359 6.8468 7.2851 C8 9.3172 6.7051 6.9669 C9 5.5407 4.5692 4.9099 C10 5.1237 . 4.6903 5.0330 C11 3.8852 3.9072 4.1361 C12 3.3087 3.6261 3.7934 C13 3.1822 3.7746 3.6029 C14 2.8369 3.6211 3.4109 C15 . 2.3268 3.1799 2.9741 C16 1.7997 2.6220 2.4320 C17 1.7120 2.6487 2.4684 C18 1.6915 2.7697 2.5720 C19 1.3868 2.3959 2.1990 C20 1.2348 2.2448 2.0483 C21 0.9617 1.8351 1.6649 C22 . . 0.9866 1.9717 1.7785 C23 0.7962 1.6630 1.4932 C24 0.7456 1.6246 1.4521 C25 0.6891 1.5636 1.3913 C26 0.5955 1.4050 1.2445 C27 0.6025 1.4760 1.3016 C28 0.4900 1.2445 1.0925 C29 0.4692 1.2341 1.0798 C30 0.4663 1.2684 1.1061 C31............ . . 0.3040 0.8546 0.7420 C32 0.3192 0.9261 0.8014 C33 0.2476 0.7407 0.6389 C34 0.2678 0.8253 0.7095 C35 0.2454 0.7783 0.6669 C36+ 4.0264 13.1334 11.1208 TOTAL 100.0000 100.0000 100.0000 Page 4 of 6 1:16 PM,3/19/2019 5530 Marshall Street Arvada,Colorado 80002 Apia web Phone:303-4200-5949 920 SOURCE TESTING PHYSICAL PROPERTY TESTING SAMPLE DATA PROJECT NO OG-2019-0057 SAMPLE ID Sales Oil COMPANY NAME Bayswater ANALYSIS DATE 3/18/2019 SITE G&D Hanks Tank Battery SAMPLE DATE 3/15/2019 UNIT ID Storage Tank CYLINDER NO Jar SAMPLED BY AJM LAB ANALYST CLB FIELD DATA SAMPLE PRESSURE(psig) NA SAMPLE TEMP(°F) 62 AMBIENT PRESSURE(psi) 12.5 AMBIENT TEMP(°F) 25 COMMENTS: LABORATORY DATA API GRAVITY 42.4 ASTM D5002 RVP EQUIVALENT(psi) 8.7 ASTM D6377* NOTES: *RVPe=VPCR4(100°F)x A A=0.915 for ambient samples or 0.834 for pressurized samples Page 5 of 6 1:16 PM,3/19/2019 5530 Marshall Street Arvada,Colorado 80002 Alha Phone:303-420-5949 Fax:303-420-5920 SOURCE TESTING BUBBLE POINT QUALITY ASSURANCE SAMPLE DATA PROJECT NO OG-2019-0057 SAMPLE ID Pressurized Liquid COMPANY NAME Bayswater ANALYSIS DATE 3/18/2019 SITE G&D Hanks Tank Battery SAMPLE DATE 3/15/2019 UNIT ID TA-27-28HN CYLINDER NO 37514 SAMPLED BY AJM LAB ANALYST CLB FIELD DATA SAMPLE PROBE PRESSURE(psig) 59.4 SAMPLE PROBE TEMP(°F) 117 UNIT GAUGE PRESSURE(psig) 58 UNIT GAUGE TEMP(°F) 120 AMBIENT PRESSURE(psi) 12.5 AMBIENT TEMP(°F) 25 COMMENTS: RECORDED PRESSURE(psia) 71.9 VMG CALCULATED PRESSURE(psia) 60.0 DIFFERENCE 16.6% PHASE DIAGRAM 800 704' 604 Goo 400. .. .. .. . . ... a 300 204 Recorded Sample Canftonsl - J 100 1 . 0 100 200 300 400 500 600 700 000 300 1000 1171 Page 6 of 6 1:16 PM,3/19/2019 Hello