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Home My WebLink About20152881.tiff A1 c PE COLORADO CoDepartment of Public • Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 0 St PO Box 758 Greeley, CO 80632 RECEIVED August 24, 2015 AUG 2 7 2015 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On August 26, 2015, the Air Pollution Control Division will begin a 30-day public notice period for Whiting Oil and Gas Corporation - Razor Federal 30K-3107. 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: Clara Gonzales Regards, i ._tom' Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure A•ial`c 2015-2881 S-31-16- �C):YL,PL. Pw gixi 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe 8 John W. Hickenlooper, Governor r Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer "\*'1£76,`,` � � Air Poliution Control Division � Notice of a Proposed Project or Activity Warranting Public �M Comment Website Title: Whiting Oil and Gas Corporation - Razor Federal 30K-3107 - Weld County Notice Period Begins: August 26, 2015 Notice is hereby given that an apptication for a proposed project or activity has been submitted to the Colorado Air Poltution Control Division for the following source of air pollution: Applicant: Whiting Oil and Gas Corporation Facility: Razor Federal 30K-3107 Oil and Gas Exploration and Production Facility NE '/4 of SW '/a of Section 30, Township 10N, Range 58W Weld County The proposed project or activity is as foltows: Applicant is requesting permit coverage for crude oil loadout in addition to one (1) two-phase separator that is controlled by an enclosed flare during gas gathering system downtime at an exploration and production facility. The Division has determined that this permitting action is subject to pubtic comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshotd values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non-attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a pretiminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 15WE0389 have been filed with the Wetd 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 abitity 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. Any such comment must be submitted in writing to the foltowing addressee: Harrison Slaughter Colorado Department of Public Heatth and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcdC�state.co.us ��t�R�a� 1 I ri.., .�>;`. ..�...t A STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT „q, tAIR POLLUTION CONTROL DIVISION , ' = o TELEPHONE:(303)692-3150 «t *1876* CONSTRUCTION PERMIT PERMIT NO: 1 5WE0389 Issuance 1 DATE ISSUED: ISSUED TO: Whiting Oil & Gas Corporation THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas exploration and production facility, known as Razor Federal 30K-3107, located in the NE 1/4 of SW 1/4 of Section 30, Township 10N, Range 58W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID SEP-01, One (1) two-phase separator controlled by an enclosed flare FLR-01 001 during gas gathering system downtime. Enclosed flare has a minimum combustion efficiency of 95%. LOAD-01 002 Truck loadout of crude oil. Emissions from the loadout are not controlled. 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 THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit 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. (Reference: Regulation No. 3, Part B, III.G.2). 2. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) AIRS ID: 123/9DA4 Page 1 of 9 Wellhead Version 2012-1 II olo± , De E ent f Public Health and Environment Air Pollution Control Division 3. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 4. The operator shall retain the permit final authorization letter issued by the Division, after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 5. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Equipment ID Point NO. VOC CO Emission Type SEP-01, FLR-01 001 4.8 52.3 25.8 Point LOAD-01 002 --- 9.3 --- Point See "Notes to Permit Holder #4" for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 6. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) Facility AIRS Pollutants Equipment Point Control Device Controlled ID SEP-01, 001 Steffes SHP-6 Enclosed Flare VOC, HAPs FLR-01 PROCESS LIMITATIONS AND RECORDS 7. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the throughput shall be maintained by the applicant and made AIRS ID: 123/9DA4 Page 2 of 9 olo De ent f Public Health and Environment Air Pollution Control Division available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point SEP-01, 001 Gas flared from separator.during gas 104.2 MMscf/yr FLR-01 gathering system downtime. LOAD-01 002 Crude Oil Loading 219,000 BBL/yr The owner or operator shall monitor monthly process rates based on the calendar month. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 8. Point 001: The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas flared from the separator(s) using a flow meter. The flow meter shall continuously measure flow rate and record total volumetric flow flared from each separator. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits specified in Condition 7 and to calculate emissions as described in this permit. 9. Point 002: Crude oil loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) STATE AND FEDERAL REGULATORY REQUIREMENTS 10. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 11. These sources are subject to the odor requirements of Regulation No. 2. (State only enforceable) 12. Point 001: The flare(s) covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). These requirements include, but are not limited to: • XVII.B.2.b If a combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed, have no visible emissions during normal operations, 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. • XVII.B.2.d Auto-igniters: All combustion devices used to control emissions of hydrocarbons must be equipped with and operate an auto-igniter as follows: • XVII.B.2.d.(i) All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto-igniter upon installation of the combustion device. AIRS ID: 123/9DA4 Page 3 of 9 i 1 olo A , De - . ent ,f Public Health and Environment Air Pollution Control Division • XVII.B.2.d.(ii) All combustion devices installed before May 1, 2014, must be equipped with an operational auto-igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 13. Point 001: The separator covered by this permit is subject to Regulation 7, Section XVII.G. (State Only). 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 date of first production 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. 14. Point 002: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations onsite at the time of inspections to monitor compliance with Condition 14 (a) and (b) above. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 15. Point 002: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. OPERATING & MAINTENANCE REQUIREMENTS 16. Point 001: Upon startup of these points, the applicant shall follow the 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. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 17. Point 001: The operator shall complete an initial site specific extended gas analysis of the natural gas produced at this site in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self- certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 18. Point 001: The owner or operator shall demonstrate compliance with opacity standards, using EPA Method 22 to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration AIRS ID: 123/9DA4 Page 4 of 9 olo De ent f Public Health and Environment Air Pollution Control Division greater than or equal to one (1) minute in any fifteen (15) minute period during normal operation. (Reference: Regulation No. 7 Section XVII.AII) ADDITIONAL REQUIREMENTS 19. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually 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 sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 20. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS 21. 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 No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 22. 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 No. 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 AIRS ID: 123/9DA4 Page 5 of 9 � i olo De ent f Public Health and Environment Air Pollution Control Division obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 23. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant 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 applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 24. 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. 25. 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 applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. � 26. 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. 27. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Harrison Slaughter Permit Engineer Permit Histo Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation AIRS ID: 123/9DA4 Page 6 of 9 �, olo.. De, ent f Public Health and Environment Air Pollution Control Division Notes to Permit Holder: 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 (Reference: Regulation No. 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 permittee 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 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 permittee 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.qov/pacific/cdphe/aqcc-reqs 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. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS# BIN (Ib/ r) reportable? Rate(Ib/ r) Benzene 71432 A 5,990 Yes 300 Toluene 108883 C 4,711 Yes 236 Ethylbenzene 100414 C 613 Yes 31 001 Xylenes 1130207 C 992 Yes 50 2'2'4 540841 C 534 Yes 27 Trimeth I entane n-Hexane 110543 C 37,164 Yes 1,859 Benzene 71432 A 26 No N/A Toluene 108883 C 82 No N/A 002 Ethylbenzene 100414 C 16 No N/A Xylenes 1130207 C 73 No N/A n-Hexane 110543 C 141 No N/A 5) The emission levels contained in this permit are based on the following emission factors: Point 001: Weight Emission Emission CAS# Pollutant Fraction Factors Factors Source of Gas (%) Uncontrolled Controlled AIRS ID: 123/9DA4 Page 7 of 9 I i olo De ent f Public Health and Environment Air Pollution Control Division Weight Emission Emission CAS# Pollutant Fraction Factors Factors Source of Gas(%) Uncontrolled Controlled NOx ___ 0.068 0.068 AP-42 Ib/MMBtu Ib/MMBtu 0.37 0.37 CO --- Ib/MMBtu Ib/MMBtu AP-42 VOC 32.10 20,063.2 1,003.16 Gas Analysis Ib/MMscf Ib/MMscf 71432 Benzene 0.093 57.508 2.8�5 Gas Analysis Ib/MMscf Ib/MMscf 108883 Toluene 0.072 45.224 2.261 Gas Analysis Ib/MMscf Ib/MMscf 100414 Ethylbenzene 0.0094 Ib/MMscf Ib/MMscf Gas Analysis 1330207 Xylenes 0.015 Ib/MMscf Ib/MMscf Gas Analysis 540841 2'2'4 0.0082 5.124 0256 Gas Analysis Trimeth I entane Ib/MMscf Ib/MMscf 110543 n-hexane 0.57 356.772 17.839 Gas Analysis Ib/MMscf Ib/MMscf Note: The uncontrolled VOC and HAP emissions for this point were calculated using the December 09, 2014 analysis of a sales gas sample collected from the Razor 27K CTB well. The controlled VOC and HAP emissions factors for point 001 are based on the flare control efficiency of 95%. A higher heating value(HH�of 1,335 BTU/scf was used for combustion calculations. Point 002: Emission Factors-Uncontrolled CAS Pollutant Ib/BBL loaded Source VOC 0.0846 AP-42 The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: S= 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) =2.80 psia M (vapor molecular weight) = 50 Ib/Ib-mol T(temperature of liquid loaded) =520°R The uncontrolled non-criteria reportable air pollutant(NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the pressurized oil sample from the Razor 27K Pad, collected January 28, 2014, by the VOC emission factor. 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: AIRS ID: 123/9DA4 Page 8 of 9 olo. De ent` f Public Heaith and Environment Air Pollution Control Division Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, n-Hexane, Total HAPs PSD Synthetic Minor Source of: VOC, n-Hexane, Total HAPs MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Not Applicable 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.�poaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX 9) A self certification form and guidance on how to self-certify compliance as required by this permit may be obtained online at: http://www.colorado.qov/pacific/cdphe/air-permit-self-certification AIRS ID: 123/9DA4 Page 9 of 9 Division Information Engineer: Harrison Slaughter Control Engineer: Chris Laplante Review Date: 06/08/2015 Application Date: 02/12/2015 Facility Identifiers Permit No. 15WE0389 Potentially located in ozone nonattainment area AIRs County# 123 Weld Facility# 9DA4 Facility Type: exploration and production facility ❑Located in the 8-hour non-attainment area? �True Minor � SyntheticMinorfor: � VOC � NOx � CO Administrative Information Company Name: Whiting Oil and Gas Corporation Source Name: Razor Federal 30K-3107 Source Location: NE1/4 of SW1/4 Section 30, Township 10N, Range 58W SIC: 1311 Address 1: Whiting Oil and Gas Corporation Mailing Address 2: 1700 Broadway, Suite 2300 Address ty,State Zip: Denver, CO, 80290 Name: Chenine Wozniak Person To Phone: 303-802-8369 Contact Fax: 303-861-4023 Email: chenine.wozniak@whitin�.com Requested Action Self Certification Required? Yes Issuance Number: 1 Source Description: Oil and gas exploration and production facility known as the Razor Federal 30K-3107, located in the NE1/4 of SW1/4 Section 30,Township 10N, Range 58W,Weld County,Colorado. Point Name T e Control Action SEP-01, Newly 001 FLR-01 Separator Venting Flare reported source Newly 002 LOAD-01 Loadout None reported source One(1)two-phase separator controlled by one enclosed flare during gas gathering system downtime.Flare 001 has a minimum control efficiency of 95%. Equipment Description This source vents natural gas from: a well head separator Emissions from this source are: routed to a flare **Emissions are routed to a flare only during gas gathering system downtime. 'Natural gas venting from a well head separator.Emissions from this source are routed to a flare. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q*MW*Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas*MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/Ib-mol)at 60F and 1 atm Throughput(Q) 104.166667 MMscf/yr 41666.6668 scf/hr MW 23.725 lb/lb-mol 1.000000003 MMscf/d mole% MW Ibx/Ibmol mass fraction lb/hr lb/yr tpy Helium 0.02 4.0026 0.001 0.000 0.09 220.02 0.11 CO2 2.64 44.01 1.162 0.049 127.73 319333.77 159.67 N2 1.15 28.013 0.322 0.014 35.42 88541.53 44.27 methane 71.06 16.041 11.399 0.480 1253.24 3133096.00 1566.55 ethane 10.77 30.063 3.237 0.136 355.90 889743.84 444.87 propane 8.48 44.092 3.739 0.158 411.07 1027674.20 513.84 isobutane 0.82 58.118 0.477 0.020 52.47 131174.42 65.59 n-butane 2.98 58.118 1.730 0.073 190.19 475483.32 237.74 isopentane 0.52 72.114 0.377 0.016 41.46 103640.09 51.82 n-pentane 0.68 72.114 0.492 0.021 54.05 135134.47 67.57 cyclopentane 0.06 70.13 0.046 0.002 5.00 12509.45 6.25 n-Hexane 0.16 86.18 0.135 0.006 14.87 37163.70 18.58 cyclohexane 0.04 84.16 0.037 0.002 4.08 10200.79 5.10 Other hexanes 0.28 86.18 0.242 0.010 26.59 66487.26 33.24 heptanes 0.14 100.21 0.145 0.006 15.92 39798.66 19.90 methylcyclohexane 0.03 98.19 0.033 0.001 3.65 9121.65 4.56 224-TMP 0.00 114.23 0.002 0.000 0.21 533.73 0.27 Benzene 0.03 78.12 0.022 0.001 2.40 5990.40 3.00 Toluene 0.02 92.15 0.017 0.001 1.88 4710.83 2.36 Ethylbenzene 0.00 106.17 0.002 0.000 0.25 612.79 0.31 Xylenes 0.00 106.17 0.004 0.000 0.40 992.13 0.50 C8+Heavies 0.09 122.3520223 0.104 0.004399 11.47 28684.66 14.34 VOC mass fraci 0.321 Total VOC(Uncontrolled) 1044.96 VOC mol% 14.35 Gas MW 23.725 Notes Mole%,MW,and mass fractions from the Razor 27K CTB sales gas analysis collected 12/09/14. It should be noted that the gas analysis is representative and not site specific. Emissions are based on 2,500 hours of operation per year. The average molecular weight(MW)of C8+was determined through the use of the goal seek function. Since the mass fraction of C8+is known from the extended natural gas analysis provided,goal seek was used to set the C8+mass fraction to a value of 0.004399(cell E50)by changing the MW weight of C8+ (cell D50). This resulted in a C8+MW of 122.4 lb/lb-mol. 15WE0389.CP1.xlsm One(1)two-phase separator controlled by one enclosed flare during gas gathering system downtime.Flare 001 has a minimum control efficiency of 95%. Flaring Information Equipment Description Flare to combust low-pressure separator gas during gas gathering system downtime. Manufacturer Steffes Model SHP-6 Serial Number 102915 Gas Heating Value 1335 Btu/scf Throughput 139062.5004 MMBtu/yr VRU Information Equipment Description NOT APPLICABLE Make N/A Model N/A Requested Control N/A Annual Bypass Tim N/A Backup None Overall Control 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.07 Ilb NOX/MMBtu 0.37 Ilb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 20063.1606 lb/MMscf 1003.1580 lb/MMscf 1044.96 tpy 52.25 tpy Gas Analysis Nox 0.07 lb/MMBTU 0.07 lb/MMBTU 4.73 tpy 4.73 tpy AP-42 CO 0.37 Ib/MMBTU 0.37 lb/MMBTU 25.73 tpy 25.73 tpy AP-42 Benzene 57.5079 lb/MMscf 2.875 lb/MMscf 5990 lb/yr 300 lb/yr Gas Analysis n-Hexane 356.7716 lb/MMscf 17.8386 lb/MMscf 37164 lb/yr 1858.2 lb/yr Gas Analysis Toluene 45.2240 lb/MMscf 2.2612 lb/MMscf 4711 lb/yr 236 lb/yr Gas Analysis Xylenes 9.5245 lb/MMscf 0.4762 lb/MMscf 992 lb/yr 50 lb/yr Gas Analysis Ethylbenzene 5.8828 lb/MMscf 0.2941 lb/MMscf 613 lb/yr 31 lb/yr Gas Analysis 2,2,4-TMP 5.1238 lb/MMscf 0.2562 lb/MMscf 534 lb/yr 27 lb/yr Gas Analysis Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' AQCC Regulation 2 Section I.A applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air." AQCC Regulation 7 Was the well newly constructed,hydraulically fractured,or recompleted on or after August 1,2014? Per application,the well began producing after the August 1,2014 applicability date. This is further confirmed by information available on the COGCC website. The COGCC website displays that the well began producing in November 2014. yes This separator is subject to Reg 7,Section XVII.G.and control requirements of Reg 7,Section XVII.B.2 Notes: 1.The notice of start-up(NOS)conditions were removed from the permit because a NOS was submitted for both the loadout and the separator with the original application. This satisfied the permit condition requirement and it was therefore determined that the condition did not need to remain in the permit. 2.The APEN that was originally submitted had emission factors displayed with units of lb/lb-mol. It was discussed with the operator that the emissions factors should instead have units of lb/MMscf.They agreed to this change. As a result,the emission factors were updated on the APEN. Additionally,it was determined the 2,2,4- Trimethylpentane was also a reportable HAP. As a result,the operator was requested to submit the non-criteria reportable pollutant APEN addendum form. This form was submitted along with the updated emission factor calculation spreadsheet. 3. An initial site specific extended gas analysis was required in the permit because the sample provided in the permit application and used for analysis was not site- specific. 4.The flow meter referenced in the permit and used to monitor throughput to the flares has already been installed at the facility. 15WE0389.CP1.xlsm One(1)two-phase separator controlled by one enclosed flare during gas gathering system downtime.Flare 001 has a minimum control efficiency of 95%. 5.The operator was provided with a draft permit for review. They reviewed the permit and provided comments. Please reference the comments and subsequent response in the attached email and comment summary sheet. It should be noted that the condition numbers referenced in the email and comments are different than the condition numbers in the final draft because certain conditions were removed during the review phase. 15WE0389.CP1.xlsm 002 Crude Oil Loadout to Tanker Trucks The table of inputs below enables you to calculate the loading loss emissions factor"L". Calculations If you choose to use a state default emissions factor,you may enter is directly into cell B14 L= 12.46*S*P*M/T(AP-42: Chapter 5.2, Equation 1) in units lb/1,000 gallons which will overwrite L= loading losses in lb per 1000 gallons loaded Factor Meaning Value Units Source AP-42 (Table 5.2-1 Submerged Loading: S Saturation Factor 0.6 Dedicated normal service) P True Vapor Pressure 2.8 psia AP-42(Table 7.1-2: Crude Oil RVP 5) M Molecular Weight of Var\ 50 lb/lb-mole AP-42 (Table 7.1-2: Crude Oil RVP 5) T Liquid Temperature 520 deg. R Field Data L 2.01 lb/10^3 gal 8.45E-02 lb/bbl Annual requested Throughput 219000 BBL/yr 9198000 gal/yr Annual requested VOC emissions 18513 lb/yr 9.26 tpy Control: None Efficiency: 0.00% NCRPs Component Mass Fraction If the operator provides HAP speciation from a stable"sales oil" Benzene 0.0014 analysis,enter the mass fraction from this data. Alternatively,if n-hexane 0.0076 the operator modeled a pressurized oil to develop a site specific emissions factor,enter the modeled mass fraction for the Toluene 0.0044 Xylenes 0.0039 E-Benzene 0.0009 2,2,4-TMP 0.0000 Pressurized oil sample from the Razor 27K Pad-this is a representative analysis, not site specific. Source: This sample was collected on January 28, 2014. Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.0845 lb/bbl 9.26 tpy 9.26 tpy AP-42 Benzene 0.0001 lb/bbl 25.36 lb/yr 25.36 lb/yr AP-42 n-Hexane 0.0006 lb/bbl 140.15 lb/yr 140.15 lb/yr AP-42 Toluene 0.0004 Ib/bbl 82.01 lb/yr 82.01 lb/yr AP-42 Xylenes 0.0003 lb/bbl 72.57 lb/yr 72.57 lb/yr AP-42 E-Benzene 0.0001 lb/bbl 15.92 lb/yr 15.92 lb/yr AP-42 2,2,4-TMP 0.0000 Ib/bbl 0.00 lb/yr 0.00 lb/yr AP-42 Regulatory Review 'Requlation 1 -Particulate, Smoke, Carbon Monoxide, and Sulfur Dioxide ' Visible emissions shall not exceed twenty percent(20°/o) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.1. &4.) 'Requlation 2-Odor Section I.A- No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. �Reaulation 3-APEN and Permittinq Requirements Is this site considered an exploration and production location (e.g.well pad)? Yes If yes, review the following two exemptions for applicability: Does the operetor unload less than 10,000 gallons(238 BBLs)per day of crude oil on an annual average basis? NO If yes,this emissions point is categorically exempt from permit requirements per Regulation 3,Part B,Section II.D.1.1 Does this operator unload less than 6,750 bbls per year of condensate via splash fill or 16,308 bbls per year of condensate via submerged fill procedure? No If yes,this emissions point is categorically exempt from permit requirements per Regulation 3, Part B,Section II.D.1.1 Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: each individual emission point in an attainment area with uncontrolled actual emissions of two tons per year or more of any individual criteria pollutant(pollutants are not summed)for which the area is attainment. (Applicant is required to file an APEN since emissions exceed 2 tons per year VOC) Part B—Construction Permit Exemptions Applicant is not required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 5.0 TPY threshold (Reg. 3, Part B, Section II.D.3.a) Part B, III.D.2- RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainmenUmaintenance areas. This source is not located in the 8-hour ozone nonattainment area or the 1-hour ozone area. Since source is in attainment, RACT is not required. However, operator is using 0.6 saturation factor, which does satisfy RACT requirements. 'Regulation 6-New Source Performance Standards No applicable subpart. This facility is not a bulk gasoline terminal. 'Regulation 7-Volatile Orqanic Compounds No sections apply. Per Regulation 7, Section VI.C, a terminal is defined as a petroleum liquid storage and distribution facility that has a daily average throughput of more than 76,000 liters of gasoline(20,000 gallons), which is loaded directly into transport vehicles. I This facility is neither a terminal, nor a bulk plant per definitions in Reg 7, Section VI.C. lRequlation 8-Hazardous Air Pollutants MACT EEEE: Not subject because a synthetic minor source of HAPs NOTES: ' ' ' ' ' ' ' ' '' 1.The notice of start-up(N0S) conditions were removed from the permit because a N0S was submitted for =: both the loadout and the separator with the original application. This satisfied the permit condition requirement and it was therefore determined that the condition did not need to remain in the permit. 2.The operator was provided with a draft permit for review. They reviewed the permit and provided ` comments. 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