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Home My WebLink About20181777.tiffCOLORADO Department 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 O St PO Box 758 Greeley, CO 80632 May 30, 2018 Dear Sir or Madam: RECEIVED JUN 042018 WELD COUNTY COMMISSIONERS On May 31, 2018, the Air Pollution Control Division will begin a 30 -day public notice period for Whiting Oil and Gas Corporation - Razor 12F Production 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: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure Revt O(o-I3-18 ac: pLC Ana fTO, 14L(1-1), FIN (ER 1TieK) y 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Whiting Oil and Gas Corporation - Razor 12F Production Battery - Weld County Notice Period Begins: May 31, 2018 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: Whiting Oil and Gas Corporation Facility: Razor 12F Production Battery Well Production Facility SENW SEC 12 T10N R58W Weld County The proposed project or activity is as follows: Modification to existing tank and separator emissions; addition of VRT equipment. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 16WE0912 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.govtpacific/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. Any such comment must be submitted in writing to the following addressee: Timothy Sharp Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us 1 COLORADO Colorado Air Permitting Project Version No. 1.00 PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Package #: Received Date: Review Start Date: Section 01- Facility Information Timothy Sharp 366367 7/20/2017 11/7/2017 Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Location: Type of Facility: What industry segment? Is this facility located in a NAAQS non -attainment area? No If yes, for what pollutant? Ecarbon Monoxide (CO) articulate Matter (PM) Wtilting Oil and Gas Corporation 123 9ECD Razor 12F Production Battery SENW Section 12 T10N RS8W Exploration & Production Well Pad Oil & Natural Gas Production & Processing Section 02 - Emissions Units In Permit Application zone (NOx & VOC) AIRs Point # Emissions Source Type Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks 004 Produced Water Storage Tank Yes 16WE0912 CP2 No Permit Modification 006 Crude Oil Storage Tank Yes 16WE0914 CP2 No Perrtlit Modification 007 Separator Venting Yes 16WE0915 CP2 No Permit Modification 008 Vapor Recovery Tower (VRT) Yes 17 WE0770 CP1 Yes Section 03 - Description of Project Section 04 - Public Comment Requirments Is Public Comment Required? Yes If yes, why?" Requesting Synthetic Minor Permit Section 05 - Ambient Air Impact Analysis Requirements Was a quantitative modeling analysis required?2 No If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, explain what programs and which pollutants here: Title V Operating Permits (OP) : VOC, HAPs (total, n -hexane, benzene, toluene Non -Attainment New Source Review (NANSR): VOC Is this stationary source a major source? If yes, explain what programs and which pollutants here: No Yes Condensate Storage Tank(s) Emissions Inventory Issuance Date: December 30, 2015 Section 01- Adminstrative Information Facility AIRs ID: 123 /E County Plant Poin 16WE0912 CP1 Section 02- Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC& HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Produced Water Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Produced Water Throughput= Secondary Emissions- Combustion Device(s) High heat value of waste gas = 1"2 Btu/scf 333 Low heat value of waste gas = j� �;; Btu/scf • Volume of waste gas emitted per BBL of liquid produced= 'I 1,i scf/ bbl Actual heat content of waste gas routed to combustion device = Request HHV heat content of waste gas routed to combustion device = Potential to Emit (PTE) HHV heat content of waste gas routed to combustion device = Request LHV heat content of waste gas routed to combustion device = Potential to Emit (PTE) LHV heat content of waste gas routed to combustion device= Barrels (bbl) per year Barrels (bbl) per year Barrels (bbl) per year Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Pollutant PM10 PM2.5 NOx VOC Produced Water Storage Tanks Uncontrolled E.F. (lbs/bbl Produced Water Throughput) 0.0275' Actual Produced Water Throughput While Emissions Controls Operating = HHV used for NOx calculation LHV usedfor CO calculation Control Device 2,368 MMBTU per year 3,690 MMBTU per year 3,690 MMBTU per year 3,364 MMBTU per year 3,364 MMBTU per year Controlled E.F. Uncontrolled (Ibs/bbl Uncontrolled E.F. E.F. (Ibs/bbl Produced (lbs/MMBtu Produced Water waste heat Water Throughput) combusted) Throughput) CO Benzene Toluene 0.0000 0.0000 0.000100 \\\ �� 0,31.::; ,• 0.000414 0,00023 0 000012 „- 0,00014 0.000008 0.0000008 0.0000014 0.000015 0.0000019 Ethylbenzene X lene n -Hexane 224 TMP Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled . (tons/year) (tons/year) .Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 • NOx VOC CO 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 0.1 0.125 0.1 0.1 34.6 34.6 1.73 22.2 1.1 0.5 0.5 0.521 0.4 0.4 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 2.9E-01 2.9E-01 1.4E-02 1.9E-01 9.3E-03 2.0E-01 2.0E-01 1.0E-02 1.3E-01 6.5E-03 2.0E-02 ' 2.0E-02 ' 1.0E-03 1.3E-02 6.5E-04 3.4E-02 3.4E-02 1.7E-03 2.2E-02 1.1E-03 -'3.8E-01 3.8E-01 1.9E-02 2.4E-01 • 1.2E-02 4.8E-02 4.8E-02 2.4E-03 3.1E-02 1.5E-03 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XVII.B, C.1, C.3 Storage tank is subject to Regulation 7, Section XVII, 8, C.1 & C.3, a Regulation 7, Section XVII.C.2 Storage tank is subject to Regulation 7, Section XVII.C.2, as provide Regulation 6, Part A, NSPS Subpart 0000 Storage Tank is not subject to NSPS 0000 (See regulatory applicability worksheet for detailed analysis) Emissions Factor Source Citation Controlled PTE Uncontrolled PTE (I6/yr) (Ib/yr) 579 29.0 403 20.1 40 2.0 68 3.4 756 37.8 96 4.8 2 of 15 K:\PA\2016\16 W E0912.CP2.xlsm Condensate Storage Tank(s) Emissions Inventory Issuance Date: December 30, 2015 Section 07 - Initial and Periodic Sampling and Testing Requirements 123-9ECD-004 Does the company use a site specific emisions factor to estimate emissions? 16WE0912 CP1 Amy; If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn "--- --- at the facility being permitted and 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. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor. See PS Memo 14-03, Questions 5.9 and 5.12 for additional guidance on testing. Does the company request a control device efficiency greater than 95%for a flare or combustion device? If yes, the permit will contain and intial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08- Technical Analysis Notes Applicant used the resultsof a flash 'theya These, revolts were combined to arrive at the AIRS Point # 004 Section 09- Inventory SCC Coding and Emissions Factors Process # SCC Code 01 4-04-003-15 Fixed Roof Tank, Produced Water, working+breathing+flashing losses br Uncontrolled Emissions Pollutant Factor Control % Units NOx 0.0024 0 lb/1,000 gallons liquid throughput VOC 0.6548 95 lb/1,000 gallons liquid throughput CO 0.0099 0 lb/1,000 gallons liquid throughput Benzene 0.0055 95 lb/1,000 gallons liquid throughput Toluene 0.0038 95 lb/1,000 gallons liquid throughput Ethylbenzene 0.0004 95 lb/1,000 gallons liquid throughput Xylene 0.0006 95 lb/1,000 gallons liquid throughput n -Hexane 0.0071 95 lb/1,000 gallons liquid throughput 224 TMP 0.0009 95 lb/1,000 gallons liquid throughput 3 of 15 K:\PA\2016\16WE0912.CP2.xlsm Produced Water Storage Tank Regulatory Analysis Worksheet Please note that NSPS Kb might be might be applicable for certain tanks at water management and injection facilities. If the tanks you are reviewing are at one of these facilities, please review NSPS Kb. 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 II.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? 'Source requires a permit NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section II.D.2)? Y, 'Not enough information Colorado Regulation 7, Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this produced water storage tank' located at an oil and gas exploration and production operation , well production facility2, natural gas compressor station or natural gas processing plant? 3. Is this produced water storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions°of this storage tank equal to or greater than 6 tons per year VOC? 'Storage tank Is subject to Regulation 7, Section XVII, B, C.1 & C.3, as provided below Section XVII.B — General Provisions for Air Pollution Control. Equipment and Prevention of Emissions Section XVII.C.1 - Emissions Control and Monitoring Provisions Section XVII.C.3 - Recordkeeping Requirements 5. Does the produced water storage tank contain only "stabilized" liquids? If no, the following additional provisions apply. 'Storage tank is subject to Regulation 7, Section XVILC.2, as provided below Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart 0000, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Was this produced water storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after August 23, 2011? 2. Does this produced water storage vessel meet the definition of "storage vessel"' per 60.5430? 3. Is this produced water 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? 4. Are potential VOC emissions2 from the individual storage vessel greater than or equal to 6 tons per year? 'Storage Tank is not so Subpart A, General Provisions per §60.5425 Table 3 - §60.5395 - Emissions Control Standards for VOC §60.5413 - Testing and Procedures §60.5395(g) - Notification, Reporting and Recordkeeping Requirements §60.5416(c) - Cover and Closed Vent System Monitoring Requirements _ _ §60.5417 - Control Device Monitoring Requirements [Note: If a storage vessel is previously determined to be subject to NSPS OOOO due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS OOOO per 60.5365(e)(2) even if potential VOL emissions drop below 6 tons per year] O RACT Review RACT review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer ye Source Req Go to next i Source Req Go to next t Go to the n Go to the n Source Is st. Go to the n Go to the n Go to the n Storage Tar This document assists operators'wifh determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," 'may," "should," and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. Crude Oil Storage Tank(s) Emissions Inventory Section 01- Adminstrative Information Facility AIRs ID: County Plant Poin 16W E0914 CPO Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency 'X: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Throughput= Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = Barrels (bbl) per year Actual Crude Oil Throughput While Emissions Controls Operating = Barrels (bbl) per year Barrels (bbl) per year ' Secondary Emissions - Combustion Device(s) HHV Heat content of waste gas = 2520 Btu/scf LHV heat content of waste gas = 3?5' Btu/ cf Volume of waste gas emitted per BBL of liquids produced = scf/bbl Actual heat content of waste gas routed to combustion device = Request HI -IV heat content of waste gas routed tocombustion device = Potential to Emit (PTE) HHV heat content of waste gas routed to combustion device = Request LHV heat content of waste gas routed to combustion device = Potential to Emit (PTE) LHV heat content of waste gas routed to combustion device= Section 04 - Emissions Factors & Methodologies Will this storage tank emit flash emissions? Crude Oil Storage Tank Section 05 - Emissions Inventory Control Device 1,780 MMBTU per year 3,226 MMBTU per year 3,226 MMBTU per year 2,970 MMBTU per year 2,970 MMBTU per year Uncontrolled E.F. Uncontrolled Uncontrolled E.F. Controlled E.F. (Ibs/MMBtu E.F. (Ibs/bbl (Ibs/bbl Crude Oil (Ibs/bbl Crude waste heat Crude Oil Throughput) Oil Throughput) combusted) Throughput) 0.0002 0.0010 0.0000 0.0000 0.00000 0.0000 0.0003 0.00000 Emissions Factor Source Citation Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 NOx VOC CO 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 0.1 0.11 0.1 0.1 64.8 64.8 3.24 35.8 1.8 0.5 0.5 0.46 0.3 0.3 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tans/year) (tans/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 2.4E-01 2.4E-01 1.2E-02 1.3E-01 6.6E-03 2.2E -0i 2.2E-01 1.1E-02 1,2E -0i 6.0E-03 3.7E-02 ' 3.7E-02 1.8E-03 2.0E-02 1.0E-03 8.6E-02 8.6E-02 4.3E-03, 4.8E-02 2.4E-03 2.3E+00 2.3E+00 .12E-01 1.3E+00 6.4E-02 4.2E-02 4.2E-02 2.1E-03 2.3E-02 1.2E-03 Section 06- RegulatorySumma Analysis Regulation 3, Parts A,B Regulation 7, SectionXVll. B, C.1, C.3 Regulation 7, Section XVII.C,2 Regulation 6, Part A, HOPS Subpart Kb Regulation 6, Part A, NIPS Subpart 0000 Regulation 8, Part E, MACT Subpart HO (See regulatory applicability worksheet for detailed analysis) Source requires a permit Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3, as provided Storage tank is subject to Regulation 7, Section XVII-C.2, as provided below Storage Tank is not subject to NSPS Kb Storage Tank is not subject to HOPS 0000 Storage Tank is not subject to MACT fill Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 20 tons VOC per year? 0 Controlled PTE Uncontrolled PTE (lb/yr) (Ib/yr) 482 24 434 22 74 4 172 9 4629 231 84 4 6af 15 K:\PA\2016\16 W E0912.CP2,xlsm Crude Oil Storage Tank(s) Emissions Inventory 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 envisions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample of crude oil drawn at the facility being permitted? 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 and intial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 -Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 006 Process # 01 SCC Code Definitions for Drop Down Lists Storage Tank Emissions Factor Options State Default E.F. (includes flash) Other (Documented in Technical Analysis Notes) Site Specific E.F. (includes flash) Site Specific EPA TANKS E.F. Working and Breathing Only Qualifiers No Yes Not applicable - stabilized tank Control Devices Enclosed Flare Open Flare Vapor Recovery Unit (VRU) Control Device Combustion Emissions Factor Options AP -42 Chapter 13.5 Industrial Flares (NOx/CO) TNRCC Flare Emissions Guidance (NOx/C0) AP -42 Table 1.4-2 (PM10/PM.2.5) SCC Codes - Storage Tank Emissions 4-04-003-12 Fixed Roof Tank, Crude Oil, working+breathing+flashing losses 4-04-003-02 Fixed Roof Tank: Working & Breathing Losses 4-04-003-22 External Floating Roof Tank, Crude Oil, working+breathing+flashing 4-04-003-06 External Floating Roof Tank: Working and Breathing Losses 4-04-003-32 Internal Floating Roof Tank, Crude Oil, working+breathing+flashing 4-04-003-07 Internal Floating Roof Tank: Working and Breathing Losses SCC Codes - Flaring Combustion Emissions 3-10-001-60 Flares Uncontrolled Emissions Pollutant Factor Control % Units NOx 0.01 0 lb/1,000 gallons crude oil throughput VOC 3.4 95 lb/1,000 gallons crude oil throughput CO 0.02 0 lb/1,000 gallons crude oil throughput Benzene 0.01 95 lb/1,000 gallons crude oil throughput Toluene 0.01 95 lb/1,000 gallons crude oil throughput Ethylbenzene 0.00 95 lb/1,000 gallons crude oil throughput Xylene 0.04 95 l6/1,000 gallons crude oil throughput n -Hexane 0.12 95 lb/1,000 gallons crude oil throughput 224 TMP 0.00 95 lb/1,000 gallons crude oil throughput 7 of 15 K:\PA\2016\ 16WE0912.CP2.xlsm Crude Oil. Storage Tank Regulatory Analysis Worksheet 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 II.D.1.a)? 2. Is the construction date prior to 4/14/2014 and not modified after 4/14/14 (See PS Memo 14-03 for additional guidance on grandfather applicability)? 2a. If answer to #2 is yes, is the crude oil throughput less than 40,000 gallons per year? 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.3)? (Source requires a permit NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the construction date prior to 4/14/2014 and not modified after 4/14/14 (See PS Memo 14-03 for additional guidance on grandfather applicability)? 2a. If answer to #2 is yes, is the crude oil throughput less than 40,000 gallons per year? 3. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section 11.0.2)7 'Not enough information Colorado Regulation 7, Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this crude oil storage tank' located at an oil and gas exploration and production operation , well production facility', natural gas compressor stations or natural gas processing plant? 3. Is this'crude oil storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions' of this storage tank equal to or greater than 6 tons per year VOC? 'Storage tank is subject to Regulation 7, Section XVII, B, C.I. & Cl, as provided below Section XVII.B— General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1 - Emissions Control and Monitoring Provisions Section XVII.C.3 - Recordkeeping Requirements 5. Does the crude oil storage tank contain only "stabilized" liquids? If no, the following additional provisions apply. 'Storage tank Is subject to Regulation 7, Section XVII.C.2, as provided below Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the individual storage vessel capacity greater than or equal to 75 cubic meters (m3) [-472 BBLs]? 2. Does the storage vessel meet the following exemption in 60.111b(d)(4)? a. Does the vessel has a design capacity less than or equal to 1,589.874 m3 [^10,000 BBL] used for petroleum' or condensate stored, processed, or treated prior to custody transfer' as defined in 60.111b? 3. Was this condensate storage tank constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23, 1984? 4. Does the tank meet the definition of "storage vessel's in 60.111b? 5. Does the storage vessel store a "volatile organic liquid (VOL)"s as defined in 60.111b? 6. Does the storage vessel meet any one of the following additional exemptions: A. Is the storage vessel a pressure vessel designed to operate in excess of 204.9 kPa [^29.7 psi] and without emissions to the atmosphere (60.110b(d)(2))?; or b. The design capacity is greater than or equal to 151 m3 (-950 BBL] and stores a liquid with a maximum true vapor pressure' less than 3.5 kPa (60.110b(b))?; or c. The design capacity is greater than or equal to 75 M5 [-472 BBL] but less than 151 m3 [-950 BBL] and stores a liquid with a maximum true vapor pressure' less than 15.0 kPa(60.11ob(b))? Source Req Go to next anal Go to the n Storage Tank is not subject to NSPS Kb SubpartA, General Provisions §60.112b - Emissions Control Standards for VOC §60.113b - Testing and Procedures §60.115b - Reporting and Recordkeeping Requirements §60.116b - Monitoring of Operations 40 CFR, Part 60, Subpart 0000, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Was this crude oil storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after August 23, 2011? 2. Does this crude oil storage vessel meet the,definition of "storage vessel" per 60.5430? 3. Is this crude oil 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? 4. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? Source Req Go to next Go to the n Go to the n Source is si. Storage Tar Storage Tank is not subject to NSPS OOOO Subpart A, General Provisions per §60.5425 Table 3 §60.5395 - Emissions Control Standards for VOC §60.5413 - Testing and Procedures §60.5395(g) - Notification, Reporting and Recordkeeping Requirements 660.5416(c) - Cover and Closed Vent System Monitoring Requirements §60.5417 - Control Device Monitoring Requirements [Note: If a storage vessel is previously determined to be subject to NSPS OOOO due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS OOOO per 60.5365(e)(2) even if potential VOC emissions drop below 6 tons per year] 40 CFR, Part 63, Subpart MACT HH, Oil and Gas Production Facilities 1. Is the tank located at a facility that Is majors for HAPs? 2. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR b. A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end user3 (63.760(a)(3))? 3. Does the tank meet the definition of "storage vessel"4 in 63.761? 4. Does the tank meet the definition of "storage vessel with the potential for flash emissions"' per 63.761? 5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or Subpart OOOO? (Storage Tank is not subject to MACT HH Subpart A, General provisions per §63.764 (a) Table 2 §63.766 - Emissions Control Standards §63.773 - Monitoring §63.774 - Recordkeeping §63.775 -Reporting RACT Review RACT review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," may," "should," and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. Storage Tar Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division 123-9ECD-007 16WE0915 CP2 Point Description: Venting and flaring from four gas/liquid separators during periods of gathering system downtime. 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/lb-moI) at 60F and 1 atm Throughput (Q) MW 32.9 MMscf/yr 26.884 Ib/Ib-moI 3755.7 scf/hr 0.090 MMscf/d 2.79 MMscf/mo mole % MW Ibx/Ibmol mass fraction E lb/hr lb/yr tpy Helium 0 4.0026 0.000 0.000 Helium 0.0 0 0.00 CO2 3.44 44.01 1.514 0.056 CO2 15.0 131283 65.64 N2 1.119 28.013 0.313 0.012 . N2 3.1 27182 13.59 methane 60.762 16.041 9.747 0.363 methane 96.5 845205 422.60 ethane 13.125 30.063 3.946 0.147 ethane 39.1 342161 171.08 propane 12.389 44.092 5.4626 0.203 propane 54.1 473690 236.85 isobutane 1.354 58.118 0.7869 0.029 isobutane 7.8 68238 34.12 n -butane 4.726 58.118 2.7467 0.102 n -butane 27.2 238179 119.09 isopentane 0.898 72.114 0.6476 0.024 isopentane 6.4 56156 28.08 n -pentane 1.165 72.114 0.8401 0.031 n -pentane 8.3 72852 36.43 cyclopentane 0.284 70.13 0.1992 0.007 cyclopentane 2.0 17271 .8.64 n -Hexane 0,234 86.18 0.2017 0.007501 n -Hexane 2.00 17487 8.74 cyclohexane 0.0980 84.16 0.0825 0.003 cyclohexane 0.8 7152 3.58 Other hexanes 0.093 86.18 0.0801 0.003 Other hexanes 0.8 6950 3.48 heptanes 0.183 100.21 0.1834 0.007 heptanes 1.8 15902 7.95 methylcyclohexane 0.027 98.19 0.0265 0.001 methylcyclohexane 0.3 2299 1.15 224-TMP 0.018 114.23 0.0206 0.000765 224-TMP 0.2 1783 0.89 Benzene 0.026 78.12 0.0203 0.000756 Benzene 0.2 1761 0.88 Toluene 0.012 92.15 0.0111 0.000411 Toluene 0.1 959 0.48 Ethylbenzene 0.003 106.17 0.0032 0.000118 Ethylbenzene 0.0 276 0.14 Xylenes 0.014 106.17 0.0149 0.000553 Xylenes 0.1 1289 0.64 C8+ Heavies 0.03 121.24 0.0364 0.001 C8+ Heavies 0.4 3154 1.58 VOC mass fraction: 26.884 Notes Mole %, MW, and mass fractions from site -specific gas analysis sampled 6/14/16. Emissions are based on 8760 hours of operation per year. MW of C8+ was assumed by applicant and I accepted it. 0.4227 Total VOC Emissions (Uncontrolled) annual limit assuming 95% control monthly limit assuming 95% control (lb/mo.) 492.7 24.63 4184.6 Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division 123-9ECD-007 16WE0915 CP2 Point Description: Venting and flaring from four gas/liquid separators during periods of gathering system downtime. 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/lb-mol) at 60F and 1 atm Throughput (O) MW 32.9 MMscf/yr 26.884 Ib/Ib-mol 3755.7 scf/hr 0.090 MMscf/d 2.79 MMscf/mo mole % MW Ibx/Ibmol mass fraction E lb/hr lb/yr tpy Helium 0 4.0026 0.000 0.000 Helium 0.0 0 0.00 CO2 3.44 44.01 1.514 0.056 CO2 15.0 131283 65.64 N2 1.119 28.013 0.313 0.012 N2 3.1 27182 13.59 methane 60.762 16.041 9.747 0.363 methane 96.5 845205 422.60 ethane 13.125 30.063 3.946 0.147 ethane 39.1 342161 171.08 propane 12.389 44.092 5.4626 0.203 propane 54.1 473690 236.85 isobutane 1.354 58.118 0.7869 0.029 isobutane 7.8 68238 34.12 n -butane 4.726 58.118 2.7467 0.102 n -butane 27.2 238179 119.09 isopentane 0.898 72.114 0.6476 0.024 isopentane 6.4 56156 28.08 n -pentane 1.165 72.114 0.8401 0.031 n -pentane 8.3 72852 36.43 cyclopentane 0.284 70.13 0.1992 0.007 cyclopentane 2.0 17271 8.64 n -Hexane 0.234 86.18 0.2017 0.007501 n -Hexane 2.00 17487 8.74 cyclohexane 0.0980 84.16 0.0825 0.003 cyclohexane 0.8 7152 3.58 Other hexanes 0.093 86.18 0.0801 0.003 Other hexanes 0.8 6950 3.48 heptanes 0.183 100.21 0.1834 0.007 heptanes 1.8 15902 7.95 methylcyclohexane 0.027 98.19 0.0265 0.001 methylcyclohexane 0.3 2299 1.15 224-TMP 0.018 114.23 0.0206 0.000765 224-TMP 0.2 1783 0.89 Benzene 0.026 78.12 0.0203 0.000756 Benzene 0.2 1761 0.88 Toluene 0.012 92.15 0.0111 0.000411 Toluene 0.1 959 0.48 Ethylbenzene 0.003 106.17 0.0032 0.000118 Ethylbenzene 0.0 276 0.14 Xylenes 0.014 106.17 0.0149 0.000553 Xylenes 0.1 1289 0.64 C8+ Heavies 0.03 121.24 0.0364 0.001 C8+ Heavies 0.4 3154 1.58 mass fraction: 26.884 Notes Mole %, MW, and mass fractions from site -specific gas analysis sampled 6/14/16. Emissions are based on 8760 hours of operation per year. MW of C8+ was assumed by applicant and I accepted it. 0.4227 Total VOC Emissions (Uncontrolled) annual limit assuming 95% control monthly limit assuming 95% control (lb/mo.) 492.7 24.63 41846 Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division Flaring Information Equipment Description Flare combusts separator gas during gathering system downtime. Manufacturer Model Serial Number Pilot Gas Hi h Heating Value Pilot Gas Low Heatin. Value (for CO) Heating Value Low Heating Value Se Se Pilot Gas Flow Rate Pilot Gas Thro Pilot Gas Throu•h. Se arator Gas Throu Separator Gas Throu arator Gas arator Gas Hi h h ut (@ HHV) ut (@ LHV) hput (@ HHV) hput (@ LHV) Flare Industries SFVP 824 2516 2315 1486 1355 1.54 Btu/scf Btu/scf Btu/scf Btu/scf MMscf/yr MMBtu/yr MMBtu/yr MMBtu/yr MMBtu/yr 3874.64 3565.1 48889.4 44579.5 Combustion emission factor source: AP -42: Chapter 13.5 0.068 lb NOX/MMBtu tpy NOX 0.31 7.46 lb CO/MMBtu tpy CO 1.79 Emissions Summary 1.79 tpy NOX Uncontrolled/PTE 7.46 tpy CO 492.7 tpy VOC Controlled 24.63 tpy VOC 123-9ECD-007 NOx emissions based on HHV. CO emissions based on LHV. Uncontrolled Total (Ib/yr) Reportable? Controlled Total (Ib/yr) Benzene 1761 Yes 88 Toluene 959 Yes 48 Ethylbenzene 276 Yes 14 Xylenes 1289 Yes 64 n -hexane 17487 Yes 874 224-TMP 1783 Yes 89 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 3 Part A: An APEN is required for this source because uncontrolled VOC emissions exceed two tons per year in an attainment area. Part B: A permit is required for this source because uncontrolled VOC emissions from this facility exceed five tons per year in an attainment area. This source is not subject to Section III.D.2 (Minor Source RACT) because it is not located in a nonattainment area. Is public comment required? Public Comment not Required AQCC Regulation 7 Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014? yes This separator is subject to Reg 7, Section XVII.G. and control requirements of Reg 7, XVI1.B.2 Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division 123-9EC6007 SCC Coding: Emission Factors for Permit Uncontrolled 31000205 NOX 109.1 lb/MMscf natura CO 453.6 lb/MMscf natura VOC 29951 lb/MMscf natura Benzene 53.535 lb/MMscf natura Toluene 29.146 lb/MMscf natura Ethylbenzene 8.3951 lb/MMscf natura Xylenes 39.1771 lb/MMscf natura n -Hexane 531.53 lb/MMscf natura 224-TMP 54.1945 lb/MMscf natura Controlled NOX 109.1 lb/MMscf natural CO 453.6 lb/MMscf natura VOC 1498 lb/MMscf natura Benzene 2.6768 b/MMsct natura I oluene 1.4573 b/MMsct natura Ethylbenzene 0.4198 b/MMsct natura Xylenes 1.9589 b/MMsct natura nliexane 26.5763 b/MMsct natura b/MMsct natura 224- I MP 2.7097 gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented 16WE0915 Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division 123-9ECD-008 17WE0770 CP1 Point Description: Venting and flaring from two gas/liquid separators (VRTs) during periods of gathering system downtime. 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/lb-mol) at 60F and 1 atm 912,500 bbl/yr Throughput (Q) MW 3.7 MMscf/yr 43.610 Ib/Ib-mol 422.1 scf/hr 0.010 MMscf/d 0.31 MMscf/mo mole % MW Ibxllbmol mass fraction E lb/hr Ib/yr tpy Helium 0 4.0026 0.000 0.000 Helium 0.0 0 0.00 CO2 2.381 44.01 1.048 0.024 CO2 1.2 10213 5.11 N2 0.245 28.013 0.069 0.002 N2 0.1 669 0.33 methane 17.5671 16.041 2.818 0.065 methane 3.1 27464 13.73 ethane 19.552 30.063 5.878 0.135 ethane 6.5 57287 28.64 propane 29.5018 44.092 13.0079 0.298 propane 14.5 126777 63.39 isobutane 3.5672 58.118 2.0732 0.048 isobutane 2.3 20205 10.10 n -butane 14.1434 58.118 8.2199 0.188 n -butane 9.1 80112 40.06 isopentane 2.8317 72.114 2.0421 0.047 isopentane 2.3 19902 9.95 13.31 n -pentane 3.7874 72.114 2.7312 0.063 n -pentane 3.0 26619 cyclopentane 0.4535 70.13 0.3180 0.007 cyclopentane 0.4 3100 1.55 n -Hexane 1.469 86.18 1.2656 0.029022 n -Hexane 1.41 12335 6.17 cyclohexane 0.3572 84.16 0.3006 0.007 cyclohexane 0.3 2930 1.46 Other hexanes 0 86.18 0.0000 0.000 Other hexanes 0.0 0 0.00 heptanes 0.6859 100.21 0.6873 0.016 heptanes 0.8 6699 3.35 methylcyclohexane 0.2812 98.19 0.2761 0.006 methylcyclohexane 0.3 2691 1.35 224-TMP 0.0206 114.23 0.0235 0.000540 224-TMP 0.0 229 0.11 Benzene 0.1895 78.12 0.1480 0.003395 Benzene 0.2 1443 0.72 Toluene 0.1474 92.15 0.1358 0.003115 Toluene 0.2 1324 0.66 Ethylbenzene 0.022 106.17 0.0234 0.000536 Ethylbenzene 0.0 228 0.11 Xylenes 0.0514 106.17 0.0546 0.001251 Xylenes 0.1 532 0.27 C8+ Heavies 0.3845 121.24 0.4662 0.011 C8+ Heavies 0.5 4543 2.27 VOC mass fraction: 41.586 Notes Mole %, MW, and mass fractions from site -specific gas analysis sampled 6/14/16. Emissions are based on 8760 hours of operation per year. VRU and pipeline downtime account for 10% of total gas volume to be sent to combustion device. Throughput represents this 10% value. 0.7286 Total VOC Emissions (Uncontrolled) annual limit assuming 95% control monthly limit assuming 95% control (lb/mo.) 7.74 1315.0 Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division Flaring Information Equipment Description Flare combusts separator gas during gathering system downtime. Manufacturer Model Serial Number Pilot Gas Pilot Gas See Se Pilot Gas Flow Rate Pilot Gas Throu•h. Pilot Gas Throu.h.ut Separator Gas Thro Separator Gas Thro Hi Low Heatin h Heating Value Value (for CO) arator Gas Hi.h Heating Value Low Heating Value arator Gas ut (@ HHV) (@ LHV) hput (@ HHV) hput (@ LHV) Flare Industries SFVP 824 2516 2315 1486 1355 1.54 Btu/scf Btu/scf Btu/scf Btu/scf MMscf/yr MMBtu/yr MMBtu/yr MMBtu/yr MMBtu/yr 3874.64 3565.1 5494.74505 5010.349625 Combustion emission factor source: AP -42: Chapter 13.5 0.068 lb NOX/MMBtu tpy NOX 0.31 1.33 lb CO/MMBtu tpy CO 0.32 Emissions Summary 0.32 tpy NOX Uncontrolled/PTE 1.33 tpy CO 154.8 tpy VOC Controlled 7.74 tpy VOC 123-9ECD-007 NOx emissions based on HHV.. CO emissions based on LHV. Uncontrolled Total (Ib/yr) Reportable? Controlled Total (lb/yr) Benzene 1443 Yes 72 Toluene 1324 Yes 66 Ethylbenzene 228 No 11 Xylenes 532 Yes 27 n -hexane 12335 Yes 617 224-TMP 229 No 11 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 3 Part A: An APEN is required for this source because uncontrolled VOC emissions exceed two tons per year in an attainment area. Part B: A permit is required for this source because uncontrolled VOC emissions from this facility exceed five tons per year in an attainment area. This source is not subject to Section III.D.2 (Minor Source RACT) because it is not located in a nonattainment area. Is public comment required? Public Comment Required AQCC Regulation 7 Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014? yes This separator is subject to Reg 7, Section XVII.G. and control requirements of Reg 7, XVII.B.2 Produced Natural Gas Venting/Flaring Preliminary Analysis SCC Coding: Emission Factors for Permit Uncontrolled 31000205 NOX 172.3 lb/MMscf natura CO 718.9 lb/MMscf natura VOC 83747 lb/MMscf natura Benzene 390.188 lb/MMscf natura Toluene 358.010 Ib/MMscf natura Ethylbenzene 61.5640 lb/MMscf natura Xylenes 143.8360 lb/MMscf natura n -Hexane 3335.90 lb/MMscf natura 224-TMP 62.0226 lb/MMscf natura Controlled I gas vented I gas vented I gas vented I gas vented I gas vented I gas vented I gas vented I gas vented I gas vented NOX 172.3 lb/MMscf natural CO 718.9 lb/MMscf natura VOC 4187 lb/MMscf natura Benzene 19.5094 b/MMsct natura toluene 17.9005 b/MMsctnatura Ethylbenzene 3.0782 b/MMsct natura Xyytenes 7.1918 b/MMsct natura n Hexane 166.7949 b/MMsct natura 224- I MI' 3.1011 b/MMsct natura gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented gas vented Colorado Department of Public Health and Environment Air Pollution Control Division 123-9ECD-007 16WE0915 Permit number: COLORADO Air Pollution Control Division Department of Public Health Et Environment CONSTRUCTION PERMIT 16WE0912 Date issued: DRAFT Issued to: Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 2 Whiting Oil and Gas Corporation Razor 12F Production Battery 123/9ECD SENW Section 12 T10N R58W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description PW-01 through PW-08 004 Eight (8) 400 -bbl fixed -roof atmospheric storage tanks for storage of produced water. Enclosed Flare This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1 This construction permit represents final permit approval and authority to operate this emissions source. Therefore, it is not necessary to self -certify. (Regulation Number 3, Part B, Section III.G.5.) EMISSION LIMITATIONS AND RECORDS 2. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO PW-01 through PW-08 004 --- --- 1.7 --- Point 'COLORADO Air Pollution Control Division Dew., .t of Pubto.Heath&Elvironnient Page 1 of 7 Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 3. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled PW-01 through PW-08 004 Enclosed Flare VOC and HAP PROCESS LIMITATIONS AND RECORDS 4. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit PW-01 through PW-08 004 Produced Water throughput 2,518,500 barrels 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. STATE AND FEDERAL REGULATORY REQUIREMENTS 5. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 6. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 7. This source is subject to Regulation Number 7, Section XII. The operator shall comply with all applicable requirements of Section XII and, specifically, shall: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for condensate 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 COLORADO Air Pollution Control Division r Pbu€= ke;i:h C, (� _rtrorrrtet' Page 2 of 7 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, Section XII.C.) (State only enforceable) 8. The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.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 XVII, it shall be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16; 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 following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • 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. 9. The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall 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 May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section XVII.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. 10. The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Section XVII.C.2. OPERATING Et MAINTENANCE REQUIREMENTS 11. 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 the OEtM plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Periodic Testing Requirements 12. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 13. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or COLORADO Air Pollution Control Division Department of Pudfit Health & Environment Page 3 of 7 For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. GENERAL TERMS AND CONDITIONS 14. 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. 15. 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. 16. 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. 17. 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. 18. 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. 19. 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. 20. 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 COLORADO Air Pollution Control Division I „K tati"x:-:t o€ Public Eh?eal°h G E^vvvrmert Page 4 of 7 enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 December 5, 2016 Issued to Whiting Oil and Gas Corporation. Issuance 2 This Issuance Issued to Whiting Oil and Gas Corporation. Modification to process and emissions limits. COLORADO Air Pollution Control Division 1 rota si7 erlt z t P bt<L° i{eE'h.6 E^Y'nonment Page 5 of 7 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.cotorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 004 Benzene 71432 567 29 Toluene 108883 395 20 n -Hexane 110543 746 38 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 004: CAS # . Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source N0x --- 0.000010 AP -42 Ch.13-5 CO --- 0.000041 AP -42 Ch.13-5 V0C 0.0275 0.001 Flash liberation analysis (flash) and EPA Tanks 4.09D (working & breathing) 71432 Benzene 0.00023 0.00001 108883 Toluene 0.00016 0.000008 110543 n -Hexane 0.0003 0.000015 Note: The controlled emissions factors for this point are based on an overall 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 ICOLORADO Air Pollution Control Division t �,i r�tittt tca ? & Environment Page 6 of 7 associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, HAPs (total, benzene, toluene, n -hexane) PSD Synthetic Minor Source of: VOC MACT HH Area Source Requirements: Not Applicable 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix 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 COLORADO I Air Pollution Control Division p,,,t l ter 1�c�f�li� t #c[ 't o Page 7 of 7 Permit number: Date issued: DRAFT Issued to: Facility Name: Plant AIRS ID: Physical Location: County: General Description: COLORADO Air Pollution Control Division Department of Public Health & Environment CONSTRUCTION PERMIT 16WE0914 Issuance: 2 Whiting Oil and Gas Corporation Razor 12F Production Battery 123/9ECD SENW Section 12 T10N R58W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description TK-01 through TK-16 006 Sixteen (16) 400 -bbl fixed -roof atmospheric storage vessels used to store crude oil. Enclosed Combustor This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. This construction permit represents final permit approval and authority to operate this emissions source. Therefore, it is not necessary to self -certify. (Regulation Number 3, Part B, Section III.G.5.) EMISSION LIMITATIONS AND RECORDS 2. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO,t VOC CO TK-01 through TK-16 006 --- --- 43.6 --- Point COLORADO Air Pollution Control. Division tepottrte:t of ;Vatic Health .& E^vironnert Page 1 of 7 Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 3. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled TK-01 through TK-16 006 Enclosed Combustor VOC and HAP PROCESS LIMITATIONS AND RECORDS 4. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit TK-01 through TK-16 006 Crude Oil throughput 730,000 barrels 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. STATE AND FEDERAL REGULATORY REQUIREMENTS 5. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 6. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 7. This source is subject to Regulation Number 7, Section XII. The operator shall comply with all applicable requirements of Section XII and, specifically, shall: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for condensate 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 COLORADO I .Air Pollution Control Division tepart ner t of I%uErti= .e n 6 E6,:ir6rv=rzr;t Page 2 of 7 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, Section XII.C.) (State only enforceable) 8. The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.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 XVII, it shall be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16; 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 following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • 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. 9. The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall 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 May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section XVII.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. 10. The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Section XVII.C.2. OPERATING Et MAINTENANCE REQUIREMENTS 11. 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 the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Periodic Testing Requirements 12. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 13. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or COLORADO Air Pollution Control Division Yepot ,-s n} Pt.ibiEnvVonrnee,t Page 3 of 7 For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. GENERAL TERMS AND CONDITIONS 14. 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. 15. 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. 16. 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. 17. 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. 18. 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. 19. 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. 20. 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 1COLORADO Air Pollution Control Division Liar€; t res nv E':iC' r:r;ueet Page 4 of 7 enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 December 5, 2016 Issued to Whiting Oil and Gas Corporation. Issuance 2 This Issuance Issued to Whiting Oil and Gas Corporation. Modification to process and emissions limits. ICOLORADO Mr Pollution Control Division ...,Wartment „f Public Hcwtn u EIvirol neat Page 5 of 7 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-reps 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 006 Benzene 71432 3629 182 Toluene 108883 2710 136 Ethylbenzene 100414 390 20 Xylenes 1330207 1279 64 n -Hexane 110543 32699 1635 2,2,4- Trimethylpentane 540841 3213 161 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 006: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source N0x --- 0.068 AP -42 CO --- 0.31 AP -42 V0C 2.388 0.119 Aspen HYSIS (flash), Tanks 4.09d (working/breathing) based on a site - specific pressurized liquid sample 71432 Benzene 0.0050 0.0002 108883 Toluene 0.0037 0.0002 100414 Ethylbenzene 0.0005 0.00003 1330207 Xylene 0.0018 0.0001 110543 n -Hexane 0.0448 0.0022 540841 2,2,4- Trimethylpentane 0.0044 0.00022 COLORADO Air Pollution Control Division `24Arrnelt of 3?c( C.r-vrcrre Page 6 of 7 Note: The controlled emissions factors for this point are based on an overall 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 permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, HAPs (total, benzene, toluene, n -hexane) PSD Synthetic Minor Source of: VOC MACT HH Area Source Requirements: Not Applicable 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63:6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX COLORADO Air Pollution Control Division I Ds,sri,v2rtJl Publ: lie4th E-r.nor.rt5ent Page 7 of 7 Permit number: Date issued: Issued to: COLORADO Air Pollution Control Division Department of Public Health & Environment CONSTRUCTION PERMIT 16WE0915 Issuance: 2 Whiting Oil and Gas Corporation Facility Name: Razor 12F Production Battery Plant AIRS ID: 123/9ECD Physical Location: SENW Section 12 T10N R58W County: Weld County General Description: Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description SEP-01 through SEP-04 007 Venting and flaring of gas from four (4) 2 - phase separators during downtime of the gas gathering system. Open Flare This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to this specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. This construction permit represents final permit approval and authority to operate this emissions source. Therefore, it is not necessary to self -certify. (Regulation Number 3, Part B, Section III.G.5.) EMISSION LIMITATIONS AND RECORDS 2. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) .A.4. ) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO,i VOC CO COLORADO I Air Pollution Control Division I Depry-ie^i <,.t R t41,z i ieu.°n u e vnarine t Page 1 of 7 SEP-01 through SEP-04 007 --- --- 24.6 7.5 Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 3. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled SEP-01 through SEP-04 007 Emissions from the separators are routed to an Open Flare during gas gathering system downtime VOC and HAP PROCESS LIMITATIONS AND RECORDS 4. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit SEP-01 through SEP-04 007 Natural Gas Venting 32.9 MMscf 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. 5. Upon installation of the flow meter, the owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from the separators) using the flow meter. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 6. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 7. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 1COLORADO 1 Air Pollution Control Division • ( i`.ep<v a'tt..t Ur Pub€ic, er ttonme:t Page 2 of 7 8. The open flare covered by this permit has been approved as an alternative emissions control device under Regulation Number 7, Section XVII.B.2.e. The open flare must have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16, and be designed so that an observer can, by means of visual observation from the outside of the open flare, or by other convenient means approved by the Division, determine whether it is operating properly. This open flare must be equipped with an operational auto -igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • 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. 9. 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. OPERATING Et MAINTENANCE REQUIREMENTS 10. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O8M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Periodic Testing Requirements 11. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 12. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NO„ per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or COLORADO Air Pollution Control Division Dep:rtswrt Jf. ptt€ t Health v ErNiorrnert Page 3 of 7 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. 13. 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 Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS 14. 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. 15. 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. 16. 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. 17. 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. 18. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. ;COLORADO Air Pollution Control Division Pubifie i-#eri;n & Emir=e,rrnent Page 4 of 7 19. 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. 20. 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: Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 December 5, 2016 Issued to Whiting Oil and Gas Corporation. Issuance 2 This Issuance Issued to Whiting Oil and Gas Corporation. Modification to process and emissions limits. COLORADO Air Pollution Control Division D epert,,ent zrf Path;: k #eewn & l * vonr?ce+ t Page 5 of 7 Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 007 Benzene 71432 1758 88 Toluene 108883 918 46 Ethylbenzene 100414 285 14 Xylenes 1130207 1259 63 n -Hexane 110543 17483 874 2,2,4- Trimethylpentane 540841 1761 88 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 0.125 ton per year (ton/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 007: CAS # Pollutant Uncontrolled Emission Factors (lb/MMscf) Controlled Emission Factors (lb/MMscf) Source - N0x 106.9 106.9 AP -42 Ch. 13.5 CO 444.4 444.4 AP -42 Ch. 13.5 V0C 29952 1498 Mass Balance 71432 Benzene 53.528 2.6764 Mass Balance 108883 Toluene 27.929 1.39645 Mass Balance 100414 Ethylbenzene 8.675 0.43375 Mass Balance 1330207 Xylene 38.334 1.9167 Mass Balance 110543 n -Hexane 532.208 26.6104 Mass Balance 540841 2,2,4-Trimethylpentane 53.592 2.6796 Mass Balance Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. ;COLORADO I Air Pollution Control Division Deeeas:rttnerx cr PutA,z 3 3er- tn.6 En*,ir�nr�ur:C Page 6 of 7 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 Requirement . Status Operating Permit Synthetic Minor Source of: VOC, HAPs (total, benzene, toluene, n -hexane) PSD Synthetic Minor Source of: VOC 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, Appendixes Appendix A - Appendix Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX COLORADO Air Pollution Control Division M1t of Yub€i i iec no'sr.`r•rme>:t Page 7 of 7 Permit number: Date issued: Issued to: COLORADO Air Pollution Control Division Department of Public Health & Environment CONSTRUCTION PERMIT 1 7WE0770 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Whiting Oil and Gas Corporation Razor 12F Production Battery 123/9ECD SENW Section 12 T10N R58W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description SEP-11 through SEP-12 008 Venting and flaring of gas from two (2) Vapor Recovery Towers during VRU and gas gathering downtime Open Flare This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to this specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit 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/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) 2. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) COLORADO Air Pollution Control Division , De.put.,':'-"nt of Public E'ECii"th U Environment. Page 1 of 7 3. 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 4. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO SEP-11 through SEP-12 008 --- --- 8.3 --- Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 5. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled SEP-11 through SEP-12 008 Emissions from the VRTs are routed to an Open Flare during VRU and gas gathering system downtime VOC and HAP PROCESS LIMITATIONS AND RECORDS. 6. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit SEP-11 through SEP-12 008 Condensate Throughput 912,500 bbl/yr 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 COLORADO Air Pollution Control Division TF aW, & EnvIronment Page 2 of 7 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. 7. The owner or operator must use monthly VRU downtime records, monthly condensate/crude oil throughput records, calculation methods detailed in the O&M Plan, and the emission factors established in the Notes to Permit Holder to demonstrate compliance with the process and emissions limits specified in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 8. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 9. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 10. The open flare covered by this permit has been approved as an alternative emissions control device under Regulation Number 7, Section XVII.B.2.e. The open flare must have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16, and be designed so that an observer can, by means of visual observation from the outside of the open flare, or by other convenient means approved by the Division, determine whether it is operating properly. This open flare must be equipped with an operational auto -igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • 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. 11. 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. OPERATING & MAINTENANCE REQUIREMENTS 12. 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 the OaM 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 13. The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.16) Periodic Testing Requirements 14. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. COLORADO Air Pollution Control Division I Deparomrt or Fubl o 1 ie h & l srnOY;rneM Page 3 of 7 ADDITIONAL REQUIREMENTS 15. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NO. per year, a change in - annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 16. 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 Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS 17. 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. 18. 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. COLORADO Air Pollution Control Division E;ytr�mJ'rsr Page 4 of 7 19. 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. 20. 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. 21. 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. 22. 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. 23. 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: Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation. COLORADO Mr Pollution Control Division Page 5 of 7 Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 007 Benzene 71432 1443 72 Toluene 108883 1324 66 Ethylbenzene 100414 228 11 Xylenes 1130207 532 27 n -Hexane 110543 12335 617 2,2,4- Trimethylpentane 540841 229 11 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 0.125 ton per year (ton/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 007: CAS # Pollutant Uncontrolled Emission Factors (lb/MMscf) Controlled Emission Factors (lb/MMscf) Source N0x --- 106.9 AP -42 Ch. 13.5 CO --- 444.4 AP -42 Ch. 13.5 V0C 89078 4453.9 Mass Balance 71432 Benzene 390.065 19.50325 Mass Balance 108883 Toluene 358.083 17.90415 Mass Balance 100414 Ethylbenzene 61.524 3.0762 Mass Balance 1330207 Xylene 143.802 7.1901 Mass Balance 110543 n -Hexane 3335.797 166.7899 Mass Balance 540841 2,2,4-Trimethylpentane 61.927 3.0964 Mass Balance Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. COLORADO Air Pollution Control Division h s E vhnrnent Page 6 of 7 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 Requirement Status Operating Permit Synthetic Minor Source of: VOC, HAPs (total, benzene, toluene, n -hexane) PSD Synthetic Minor Source of: VOC 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, 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 COLORADO 3rPesiivtian Control Division ititi V e a�.C,E-a�rUr,mes Page 7 of 7 Produced Water Storage Tank(s) APEN - Form APCD-207 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result IOW longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store produced water associated with oil and gas industry pera emission source does not fall into this category, there may be a more specific APEN available for our crude oil storage tanks, condensate storage tanks, hydrocarbon liquid loading, etc.). In addition, he General APZN .. (Form APCD-2OO) is available if the specialty APEN options will not satisfy your reporting needs. A isisfVE't available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/pacific/cdphe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 3O 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: 16WE0912 AIRS ID Number: 123 / 9ECtp/ 004 [Leave blank unless APCD has already assigned a permit and AIRS ID) Section 1 - Administrative Information Company Name': Whiting Oil and Gas Corporation Site Name: Razor 12F Production Battery Site Location: SENW Sec 12, T10N, R58W Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Denver, CO 80290 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Jacob Parker Phone Number: 303-357-4078 E -Mail Address': CDPHECorrespondence@whiting.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-207 Produced Water Storage Tank(s) APEN Revision 02/2017 366362 Y COLORADO iI Vu.wrm�n.:t fusr. Permit Number: 16WE0912 ,L P AIRS ID Number: 123 / 9ECi/ 004 rhEri„ ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source O Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP05 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $250 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 E Change permit limit ❑ Transfer of ownership3 ❑ 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 Additional Info a Notes: Change in control equipment and permitted emissions 3 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: (8) 400 bbl produced water tanks For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: May 25, 2016 Normal Hours of Source Operation: 24 hours/day 7 days/week 52 Storage tahk(s) located at: O Exploration Et Production (EEtP) site weeks/year ❑ Midstream or Downstream (non EEtP) site Will this equipment be operated in any NAAQS nonattainment area? ■ Yes O No Are Flash Emissions anticipated from these storage tanks? GI Yes ■ No Are these storage tanks located at a commercial facility that accepts oil production wastewater for processing? Yes No • © Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? ■ Yes 0 No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No U ri Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No U D Form APCD-207 Produced Water Storage Tank(s),APEN - Revision 02/2017 AyCOLORADO Permit Number: 16WE0912 AIRS ID Number: 123 / 9ECg/ 004 Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/year)'' Requested Annual Permit Limit4 (bbl/year) Produced Water Throughput: 1,619,369 2,518,500 From what year is the actual annual amount? Tank design: Fixed roof 2016 ['Internal floating roof ❑ External floating roof Storage Tank ID # of ,Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) " Date of First Production (month/year) PIN -01 UxoWhPN-08 8 3,200 02/2015 05/2016 Wells Serviced by this Storage Tank or Tank Battery5 (E&P Sites Only) API Number Name of Well Newly Reported Well 05 -123 - 387h Razor 12F -0101A ■ 05 - 123- 387h Razor 12F -0102B ■ 05 - 123- 387k Razor 12F -0103A ■ 05 - 123- 387h Razor 12F -0104B ■ 05 - 123- 387w Razor 12F -0105A ■ 4 Requested values wilt become permit limitations. Requested limit(s) should consider future growth. 5 The EEtP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.854641/-103.817697 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) COMB -01 35 >2000 Indicate the direction of the stack outlet: (check one) 0 Upward 0 Horizontal ❑ Downward 0 Other (describe): Indicate the stack opening and size: (check one) 0 Circular 0 Square/rectangle 0 Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): 96' Interior stack width (inches): Interior stack depth (inches): Form APCD-207 • Produced Water Storage Tank(s) APEN - Revision 02/2017 3 1 AYCOLORADO =m,= Permit Number: 16WE0912 AIRS ID Number: 123 / 9ECti/ 004 Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Make/Model: Requested Control Efficiency: % VRU Downtime or Bypassed (emissions vented): % ❑ Combustion Device: Pollutants Controlled: VOC and HAPs Rating: Type: Enclosed Combustor MMBtu/hr Make/Model: Crimson Energy CE 1000 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 % Minimum Temperature: N/A Waste Gas Heat Content: 1221 Btu/scf Constant Pilot Light: E Yes ❑ No Pilot Burner Rating: 0.44 MMBtu/hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 -Gas/Liquids Separation Technology Information (E£tP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 62 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 four (4) 2-phse separators where gas is separated from liquids. The liquids are transferred to four (4) heater treaters that are each equipped with a burner to facilitate further separation into streams of gas, crude oil, and produced water. The separated streams of crude oil and produced water are transferred to storage tanks. Form APCD-2O7 - Produced Water Storage Tank(s) APEN - Revision 02/2017 4IAY COLORADO 0,Armrn<at Pats, Hen b Er..Inn... Permit Number: 16WE0912 AIRS ID Number: 123 / 9ECii/ 004 Section 8 - Emissions Inventory Information Attach alt emissions calculations and emission factor documentation to this APEN form6. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant VOC Enclosed Combustor Overall Requested Control Efficiency (% reduction in emissions) 95 NOx CO HAPs Enclosed Combustor 95 Other: From what year is the following reported actual annual emissions data? 2016 Criteria Pollutant Emissions Inventory Pollutant Emission Factor6 Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled Basis Units Source (AP -42, Mfg. etc) ) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) VOC 22,892.8 lb/MMscf Flash Liberation 22.26 0.01 34.6 1.7 NOx 0.068 Ib/MMBtu AP -42 0.001 de minimis CO 0.31 lb/MMBtu AP -42 0.003 de minimis Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service CAS ( ) Number Emission Factor6 Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, ; Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled 7 Emissions (Pounds/year) Benzene 71432 187.74 lb/MMscf Flash Liberation 372.45 0.2 Toluene 108883 130.67 lb/MMscf Flash Liberation 259.10 0.1 Ethylbenzene 100414 13.15 lb/MMscf Flash Liberation 25.91 0.01 Xylene 1330207 22.95 Ib/MMscf Flash Liberation 43.72 0.02 n -Hexane 110543 246.90 lb/MMscf Flash Liberation 485.81 0.2 2,2'4- Trimethylpentane 540841 31.62 lb/MMscf Flash Liberation 61.54 0.03 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 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. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-2O7 • Produced Water Storage Tank(s) APEN - Revision 02/2017 AVCOLORADO Permit Number: 16WE0912 it 1 _L.1. CD AIRS ID Number: 123 / 9ECti/ 004 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 GP05 or GP08, I further certify that this source is and will be operated in f ompliance wit i ch condition of the applicable General Permit. /9/'2o/7 Si•y-• re of Legally Authorized Person (not a vendor or consultant) Date acob Parker Environmental Professional Name (print) Title Check the appropriate box to request a copy of the: ❑Q Draft permit prior to issuance 0✓ 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 $152.90 and the General Permit For more information or assistance call: registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Form APCD-2O7 - Produced Water Storar Tank(s) APEN - Revision 02/2017 6 AV COLORADO .n,r. fsv✓cnr.en. �tti�er�r d� See. A-4 AWt fd re.Lelv.--c) 577/ 2-0) ' Crude Oil Storage Tank(s) APEN Form APCD-210 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store crude oil associated with oil and gas industry gperat' If your emission source does not fall into this category, there may be a more specific APEN available for y Sur s d - e storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In additi n, th APCD-200) is available if the specialty APEN options will not satisfy your reporting needsi A list forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website www.colorado.gov/ pacific/cdphe /air -permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 16WE0914 AIRS ID Number: 123 / 9ECD/ 006 [Leave blank unless APCD has already assigned a permit_.# and .AR ID] Section 1 - Administrative Information Company Name': Whiting Oil and Gas Corporation Site Name: Razor 12F Production Facility Site Location: SENW Sec 12, T10N, R58W Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Jacob Parker Phone Number: 303-3574078 E -Mail Address2: CDPHECorrespondence@whiting.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-210 Crude Olt Storage Tank(s) /,'PEN - Revision 02/2017 366363 COLORADO 1 I m n® HvtF.b Lnruu'm n• Permit Number: 16WE0914 AIRS ID Number: 123 / 9ECD / 006 Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source O Request coverage under traditional construction permit O Request coverage under General Permit GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. - OR - • MODIFICATION to existing permit (check each box below that applies) O Change in equipment ❑ Change company name ✓❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) OR ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - 1=1 APEN submittal for permit exempt/grandfathered source Additional Info Ft Notes: Change in control equipment and permitted emissions 3 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: (16) 400 bbl produced water tanks For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 Storage tank(s) located at: May 25, 2016 hours/day 7 days/week 0 Exploration & Production (EftP) site 525,669 weeks/year 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? O Yes • No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No R 4 Are you requesting ≥ 6 ton/yr V0C emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes d No U Form APCD-210 Crude Oit Storage Tank(s) APEN - Revision 02/2017 2 AV COLORADO Ucyrmert, F.+l a hf oraanrw t Permit Number: 16WE0914 AIRS ID Number: 123 / 9ECD/ 006 Section 4 - Storage Tank(s) information Actual Annual Amount (bbl /year) Requested Annual Permit Limit4 (bbl/year) I Crude Oil Throughput: 503,593 From what year is the actual annual amount? Average API gravity of sates oil: Tank design: ❑✓ Fixed roof 2016 degrees ❑ Internal floating roof 912,500 RVP of sales oil: El External floating roof 5#orage Tank rage # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) TK-01 -TK-16 16 6,400 02/2016 05/2016 Wells Serviced by this Storage Tank or Tank Battery5 (EEtP Sites Only) API Number Name of Well ` Newly Reported Well 05 -123-38a Razor 12F -0101A ■ 05 -123 - 38a Razor 12F -0102B ■ 05 -123-38a Razor 12F -0103A ■ 05 -123 - 38a Razor 12F -0104B ■ 05 -123 - 38a Razor 12F -0105A El 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The HIP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report alt wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.85395/-103.83287 Operator Stack iD No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) COMB -01 32 >2000 150 0.05 Indicate the direction of the stack outlet: (check one) El Upward O Horizontal El Downward O Other (describe): Indicate the stack opening and size: (check one) I] Circular O Square/rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): 96t Interior stack width (inches): Interior stack depth (inches): Form APCD-21O Crude Oil Storage Tank(s) OPEN - P-,e;'rsien 02/2017 3 'AV COLORADO ot.r.Fem Neaten b trruunmrn: • Permit Number:. 16WE0914 AIRS ID Number: 123 / 9ECD / 006 [Leave:, blank unless A r'_J h- �I.tao) �� nod c rr-rn J ha'.- ILi Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor El Recovery Unit (VRU): Pollutants Controlled: Size: Make/Model: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): ❑ Combustion Device: Pollutants Controlled: VOC and HAPs Rating: MMBtu/hr Type: Enclosed Combustor Make/Model: Crimson Energy CE 1000 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: N/A Waste Gas Heat Content: 2516 Btu/scf Constant Pilot Light: O Yes ❑ No Pilot Burner Rating: 0.44 MMBtu/hr O Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 -Gas/Liquids Separation Technology Information (EEtP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 56 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 eight (4) 2-phse separators where gas is separated from liquids. The liquids are transferred to eight (4) heater treaters that are each equipped with a burner to facilitate further separation into streams of gas, crude oil, and produced water. The separated streams of crude oil and produced water are transferred to storage tanks. Form 4.PCD-210 Crude Coil Storage Tank(s) APE J - Revision 02/2017 �® COLDRA00 AIRS ID Number: 123 / 9ECD / 006 Permit Number: 16WE0914 perriiit g and iH> kD] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall Pollutant Description of Control Methods) Overall Requested Control fi'' (% reduction inn -emissions) VOC Enclosed Combustor 95% NOx CO HAPs Enclosed Combustor 95% Other: From what year is the following reported actual annual emissions data? 2016 Criteria Pollutant Emissions Inventory Pollutant Emission Factor6 Actual Annual Emissions Requested Annual Permit 4 Emission Limit(s) Uncontrolled Basis. Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/ year) Controlled Emissions? (Tons/year) Uncontrolled Emissions - (Tons/year) Controlled Emissions (Tonslyear) VOC 102,677 lb/MMscf HVSYS&Tanks cos 1572.5 0.97 64.78 3.24 NOx 0.068 Ib/MMBtu AP -42 - 0.03 - de minimis CO 0.31 Ib/MMBtu AP -42 - 0.14 - de minimis Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) NumberMfg. Emission Factor6 Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions 7 (Pounds/year) Benzene 71432 381.77 Ib/MMscf HYSYS&Tanks 4.09 14,453 8.9 Toluene 108883 344.04 lb/MMscf HYSYS&Tanks 4.09 13,244 8.2 Ethylbenzene 100414 58.36 Ib/MMscf HYSYS&Tanks 4.09 2,216 1.4 Xylene 1330207 136.42 Ib/MMscf HYSYS&Tanks 4.09 5,288 3.3 n -Hexane 110543 3,668.66 Ib/MMscf HYSYS&Tanks 4.09 92,006 56.7 2,2,4- Trimethylpentane 540841 66.66 IbiMMscf HYSYS&Tanks 4.09 2,065 1.3 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 Attach crude oil 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. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-210 Crude Viii Storage Tankis) APEN - Revision 02/2017 5 I AV COLORADO u.w»ce„<m VA a Permit Number: 16WE0914 AIRS ID Number: 123 / 9ECD / 006 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 GP08, I further certify that this source is and will be operated in full compliance with each condii ''on of the applicable General Permit. e).O017 ature of Legally Authorized Person (not a vendor or consultant) Date F/✓L%L✓/o.✓ r7EA1iq Pre SS _no L 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 $152.90 and the General Permit registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-21u - Crude Oil Storage- Tank(s) APEN - Revision 02/2017 6 AV COLORADO Nei Tnb t e�iuwrren. Crude Oil Storage Tank(s) APEN - Form APCD-210 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, updates. An application with missing information may be determined incomplete and may be returned longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store crude oil 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. condensate 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 alt available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/ pacific/ cdphe / air -permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 16WE0914 AIRS ID Number: 123 / 9ECD / 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Site Name: Whiting Oil and Gas Corporation Razor 12F Production Facility Site Location: SENW Sec 12, T10N, R58W Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Jacob Parker Phone Number: 303-357-4078 E -Mail Address2: CDPHECorrespondence@whiting.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017 1 fCOLY.RA6O. • t., 'v:,eat PueuG iiranma �,w:knxwar. Permit Number: 16WE0914 MRS ID Number: 123 / 9ECD / 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source ❑ Request coverage under traditional construction permit ❑ Request coverage under General Permit GP08 If General Permit coverage is requested, the General Permit registration fee of $250 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 ❑ Transfer of ownership3 ❑ Other (describe below) OR ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El APEN submittal for permit exempt/grandfathered source Additional Info a Notes: Change in control equipment and permitted emissions 3 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: (16) 400 bbl produced water tanks For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day May 25, 2016 7 El Exploration & Production (EEP) site days/week 52 weeks/year ❑ Midstream or Downstream (non E&P) site Wilt this equipment be operated in any NAAQS nonattainment area? ■ Yes O No Are Flash Emissions anticipated from these storage tanks? • Yes ■ No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 8O5 series rules? If so, submit Form APCD-105. Yes No • J Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actualU emissions ≥ 6 ton/yr (per storage tank)? Yes No is Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017 2 $,. COLORADO C e s tzFartszons a; raatc Permit Number: 16WE0914 AIRS ID Number: 123 / 9ECD / 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information • Actual Annual Amount' (bbl /year) • Requested Annual Permit Limit4 (bbl/year) Crude Oil Throughput: 730,000 From what year is the actual annual amount? Average API gravity of sales oil: Tank design: ❑✓ Fixed roof Permit Condtions degrees ❑ Internal floating roof 730,000 RVP of sates oil: D. External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage-Tanki(month/year)" Date of First Production `" (month/year) TK-01 -TK-16 16 6,400 02/2016 05/2016 API. Number. Wells Serviced" by this Storage. Tank or Tank Batterys. (E&P Sites Only) Name of Well;. Newly Reported'Well 05 -123-38a Razor 12F -0101A 05 -123-38a Razor 12F -0102B 05 -123-38a Razor 12F -0103A 05 -123-38a Razor 12F-01048 05 -123-38a Razor 12F -0105A El 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The EEtP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.85395/-103.83287 Operator Stack ID No.... . Discharge Height Above Ground Level (feet)' Temp. (°F) Flow Rate (ACFM). Velocity (ft/sec) ... COMB -01 35 >2000 33 0.01 Indicate the direction of the stack outlet: (check one) 0 Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) Q Circular Interior stack diameter (inches): 96' ❑ Square/rectangle Interior stack width (inches): ❑ Other (describe): Interior stack depth (inches): Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017 3 I -COLORADO r•_,n Permit Number: 16WE0914 AIRS ID Number: 123 / 9ECD / 006 [Leave blank unless APCD has already assigned a permit t+ and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Make/Model: Requested Control Efficiency: % VRU Downtime or Bypassed (emissions vented): ❑ Combustion Device: Pollutants Controlled: VOC and HAPs Rating: 42.5 Type: Enclosed Combustor MMBtu/hr Make/Model: Crimson Energy CE 1000 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: NIA Waste Gas Heat Content: Constant Pilot Light: ❑✓ Yes ❑ No Pilot Burner Rating: 2355 0.17 Btu/scf scf MMBtu/hr O Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: % Section 7 -Gas/Liquids Separation Technology Information (MP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 37 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 four (4) 2-phse separators where gas is separated from liquids. The liquids are transferred to four (4) heater treaters that are each equipped with a burner to facilitate further separation into streams of gas, crude oil, and produced water. The separated streams of crude oil and produced water are transferred to storage tanks. Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017 4 I t©10.!ADO ,. Ps}vnr� e: PuMlc Benzene Permit Number: 16WE0914 AIRS ID Number: 123 / 9ECD I 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant VOC Description of Control Method(s) Enclosed Combustor erall Requested'! Control Efficiency % reduction in emissions) 95% NOx CO HAPs Enclosed Combustor 95% Other: Permit Conditions From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant VOC Emission Factor6 Actual Annual Emissions Requested Annual Permit Emission L. 1( Uncontrolled Basis lb/bbl Source (AP -42. Mfg. etc) Uncontrolled Emissions (Tons/year), Controlled Emissions? (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) 2.3876 Flash Liberation 871.49 43.57 871.49 43.57 NOx 0.068 lb/MMBtu AP -42 de minimis de minimis CO 0.31 lb/MMBtu AP -42 de minimis de minimis Non -Criteria Reportable Pollutant Emissions Inventory ................... _.... . Chemical Abstract Service (CAS) Number Emission Factorb Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrol le Emissions (Pounds/year) Controlled Emissions? (Pounds/year) 71432 0.00497 lb/bbl Flash Liberation 3,629 182 Toluene 108883 0.00371 lb/bbl Flash Liberation 2,710 136 Ethylbenzene Xylene 100414 1330207 0.00053 0.001'75 lb/bbl lb/bbl Flash Liberation Flash Liberation 390 1,279 20 64 n -Hexane 110543 0.04479 lb/bbl Flash Liberation 32,699 1,635 2,2,4- Trimethylpentane 540841 0.00440 lb/bbl Flash Liberation 3,213 161 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 Attach crude oil 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. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. C OLGR A DO Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017 5 I Permit Number: 16WE0914 AIRS ID Number: 123 / 9ECD / 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP08, I further certify that this source is and will be operated in full compliance with ea45ondition af.Lhe applicable General Permit. 5/3/2018 Siture of Legally Authorized Person (not a vendor or consultant) Date Jacob Parker Environmental Professional Name (print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance O Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-210 Crude Oil Storage Tankis) APEN - Revision 02/2017 6 I WAN. gammasmor COLORADO Natural Gas Venting APEN - Form APCD-211 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APE -N7 updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is f incorrectly or is missing information and requires re -submittal. This APEN is to be used for Natural Gas Venting only. Natural Gas Venting includes emissions from/liq separators, well head casing, pneumatic pumps, blowdown events, among other events. If youremissionunit dogs_. not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Qov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 16WE0915 AIRS ID Number: 123 / 9ECD/ 007 [Leave bLeeP ur.!e._, 'PCD Las _rear' ned a permit PS ID] Company equipment Identification: SEP-01 thru SEP-04, FLR-01 [Provide Facility Equipment ID to identify h this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Whiting Oil & Gas Corporation Site Name: Razor 12F Production Facility Site Location: SENW Sec 12, T1 ON, R58W Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Denver, CO 80290 E -Mail Address2: CDPHECorrespondence@whiting.com Site Location . County: Weld NAICS or SIC Code: 1311 Permit Contact: Jacob Parker Phone Number: (303) 357-4078 Please 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 APCD via e-mail to the address provided. Form APCD-205 - Naturai-, os Venting APEN - Rev 03/2017 1 ®® COLORApO . b L.vu.:nm.nr 366364 Permit Number: 16WE0915 AIRS ID Number: 123 / 9ECD / 007 [Leave .e [aIard, [odes. APCD Pta d[,d ' RS [Di Section 2- Requested Action ❑ NEW permit OR newly -reported emission source - OR - ❑✓ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment ❑ Change company name ❑ Add point to existing permit 0 Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) - OR ❑ APEN submittal for update only (Please 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 Et Notes: Update with lower throughput and permit limits 3 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: during gas gathering downtime Flaring associated gas from separator For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 05 / 25 / 2016 / / (] Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions days/week weeks/year ❑ Yes O No ❑ Yes i J No Form m APCD-205 -Natural Gas Venting APEN - Rev 03/2017 2 I�® COLORADO xu.1, a ri.n,.an.,,mt Permit Number: 16WE0915 • AIRS ID Number: 123 / 9ECD / 007 Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: ❑ Other Description: Serial #: Capacity: Gal/min # of Pistons: Leak Rate: Scf/hr/pist Volume per event: MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ✓❑ Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: 125,000 SCF/hr Vent Gas Heating Value: 1486 BTU/SCF Requested: 32.9 MMSCF/year Actual: 0.34 MMSCF/year -OR- Requested: Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: Molecular Weight: VOC (mole %) 21.553 VOC (Weight %) 42.27 Benzene (mole %) 0.026 Benzene (Weight %) 0 Q$ Toluene (mole %) 0.012 Toluene (Weight %) 0.04 Ethylbenzene (mole %) 0.003 Ethylbenzene (Weight %) 0.01 Xylene (mole %) 0.014 Xylene (Weight %) 0.05 n -Hexane (mole %) 0.234 n -Hexane (Weight %) 0.75 2,2,4 Tnmethylpentane (mole %) 2,2,4-Trimethylpentane 0.018 (Weight %) 0.08 Additional Required information: ❑r Attach a representative gas analysis (including BTEX B n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX 8 n -Hexane, temperature, and pressure) Form APCD-205 -Natural Gas Venting APEN Rev 03/2017 31 AV COLORADO tier.nmu.., ee r mK Permit Number: 16WE0915 AIRS ID Number: 123 / 9ECD / 007 Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.808914/-103.844297 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. ('f) Flow Rate (ACFM) Velocity (ft/sec) FLR-01 20 >2000 Indicate the direction of the stack outlet: (check one) ❑✓ Upward D Horizontal ❑ Downward 0 Other (describe): Indicate the stack opening and size: (check one) D Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap 8 Section 6 - Control Device Information 2 VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency % VRU Downtime or Bypassed ❑ Combustion Device: Pollutants Controlled: VOC and HAPs Rating: 12 MMBtu/hr Type: Flare Make/Model: Flare Industries SFVP-0824 Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: N/A 95 % 98 % Waste Gas Heat Content Constant Pilot Light: ❑✓ Yes 0 No Pilot burner Rating 1486 Btu/scf 0.44 MMBtu/hr 0 Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 Form APCD-205 -Natural Gas \Ientrn APEN - Rev 03/2017 4 I AV COLORADO (kpartanvre N 6.. , 6,,00nmr•nr Permit Number: 16WE091 5 AIRS ID Number: 123 /9ECD/ 007 Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes D No ntrol equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM 50. NO. VOC Gas is sent to Pipeline w/ Flare Industries Flare as backup 95% CO HAPs Gas is sent to Pipeline wl Flare Industries Flare as backup 95% Other: From what year is the following reported actual annual emissions data? 2016 Use the following table to report the criteria pollutant emissions from source: Pollutant Uncontrolled Emission Factor Emission ; Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Reauested_Annual Permit Emission Limit(se Uncontrolled (Tons/year) Controlled6 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM SOx NOx 0.068 lb/MMBtu AP -42 - 0.10 - de minimis VOC 29,952 lb/MMscf Gas Analysis 5.16 0.26 492.0 24.60 CO 0.310 lb/MMBtu AP -42 - 0.40 - 7.45 Benzene 53.53 lb/MMscf Gas Analysis 0.009 0.0005 0.88 0.04 Toluene 27.93 lb/MMscf Gas Analysis 0.005 0.0003 0.46 0.02 Ethylbenzene 8.67 lb/MMscf Gas Analysis 0.001 0.00007 0.14 0.01 Xylenes 38.33 lb/MMscf Gas Analysis 0.007 0.0003 0.63 0.03 n -Hexane 532.21 lb/MMscf Gas Analysis 0.092 0.005 8.74 0.44 2,2,4- Trimethylpentane 53.59 lb/MMscf Gas Analysis 0.009 0.0005 0.88 0.04 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-205 Nat'urat Gas Venting APEN Rev /2017 5 ACS' COLORADO xw,r. a re..-...:1lIn..n, Permit Number: 1 6WE091 5 AIRS ID Number: 123 / 9ECDi 007 ri pavp b[ank ;nit APCD has aRerady pcRi sRi:i AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Sigpure of Legally Authorized Person (not a vendor or consultant) Date Environmental Professional III O7/7/' 17 Jacob Parker Name (please 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) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO -B0246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-2O5 -Natural Gas Venting APEN - Rev 03/2017 6 Alf COLORADO um,n wotPt1, St-11-e.f—S2 G,.4) N I r -•v r -Lie/ C..4 ,.� r �Cav cc' t,II Natural Gas Venting APEN - Form APCD-211 , Air Pollutant Emission Notice (APEN) and ) )L Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled incorrectly or is missing information and requires re -submittal. This APEN is to be used for Natural Gas Venting only. Natural Gas Venting includes emissions from gas/li.. d 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. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Qov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit.Number: l 7 WE077/0 AIRS ID Number: 123 / 9ECD/ 00 S eF. r Lr1.__a ,'�D' aHra,s,sty assIsaesiapecns, and AIRSID] Company equipment Identification: SEP-11 thru SEP-12, FLR-01 FProvid aci!L.t EquIpmar,r iD i'.I:.. ..ail:.'! l is ref,arenced voLIs organization] Section 1 - Administrative Information Company Name': Whiting Oil & Gas Corporation Site Name: Razor 12F Production Facility Site Location: SENW Sec 12, T1 ON, R58W Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Denver, CO 80290 E -Mail Address: CDPHECorrespondence@whiting.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Jacob Parker Phone Number: (303) 357-4078 Please 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 APCD via e-mail to the address provided. Form APCD-205 - Piatu at Gas Venting APEN - Rev 03/2017 1 I AVCOLORADO :,- ; �., 3663 Permit Number: TBD AIRS ID Number: 123 / 9ECD / [Ledve hLdnk unless APCD has .dt-eady pe f _ and zdRS 1�I� 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 name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) OR ❑ APEN submittal for update only (Please note blank APENs wilt not be accepted) - ADDITIONAL PERMIT ACTIONS - Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info & Notes: Permitting Vapor Recovery Towers (VRT) 3 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 flash gas from VRTs For existing sources, operation began on: / / For new or reconstructed sources, the projected start-up date is: / / Permit Issuance E 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 nonattainment area Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions ❑ Yes ❑ Yes Form APCD-2O5-Naturai Gas Venting APEN Rev 03/2017 2 2 No AV No COLORADO AIRS ID Number: 123 / 9ECD / Permit Number: TBD ,FLE, h _,c61, Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: ❑ Other Description: Serial #: Capacity: Gal/min # of Pistons: Leak Rate: Scf/hr/pist Volume per event: MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ✓❑ Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: BTU/SCF, Requested: MMSCF/year Actual: MMSCF/year -OR- Requested: 912,500 Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: Molecular Weight: VOC (mole %) 60.25 VOC (Weight %) 77.50 Benzene (mole %) 0.19 Benzene (Weight %) 0.34 Toluene (mole %) 0.15 Toluene (Weight %) 0.31 Ethylbenzene (mole %) 0.02 Ethylbenzene (Weight %) 0.05 Xylene (mole %) 0.05 Xylene (Weight %) 0.13 n -Hexane (mole %) 1.47 n -Hexane (Weight %) 2.9 entane 2,2,4 Trimethy(mole %) 0ntane .02 2,2,4 Trimethe ght %) 0.05 Additional Required Information: ✓❑ Attach a representative gas analysis (including BTEX &t n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 3I AV COLORADO Oep.nmine;.t {"lYrC Permit Number: TBD AIRS ID Number: ,`L-. _F' bl_.r unless APCD has _ii -6dy 4' 91;0 AKS iUj 123 /9ECD/ Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.808914/-103.844297 Operator -- - Stack ID No. Discharge Height Above Ground Level (Feet) Temp {'F)AtfiN) Flow Rate Velocity (ft/sea) FLR-01 20 >2000 Indicate the direction of the stack outlet: (check one) • Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap 8 Section 6 - Control Device Information ❑✓ VRU: Pollutants Controlled: VRT Gas (VOC and HAPs) Size: 60 HP Make/Model: Jordon Technologies J-SCG10-3.05-60-4803 Requested Control Efficiency VRU Downtime or Bypassed 100 7 % ❑ Combustion Device: Pollutants Controlled: VRT Gas (VOC and HAPs) Rating: 12 MMBtu/hr Type: Flare Make/Model: Flare Industries SFVP-0824 Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: N/A 95 98 % Waste Gas Heat Content Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating 2,419 0.44 Btu/scf MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested 0 Form APCD-2U5 Naturai Gas Venting APEN - Rev 03/2017 �w 'K.6l0Rd00 4 CV7 Knee, v b .' t Permit Number: TBD AIRS ID Number: 123 / 9ECD/ .L _ e blank� ..... �� b .RS ID Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SOx NOx VOC Gas is sent to Pipeline wl Flare Industries Flare as backup 95% CO HAPs Gas is sent to Pipeline w/ Flare Industries Flare as backup 95% Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions `- Requested Annual Permit Emission Limit(s)5 Uncontrolled (Tons/year) Controlled6 (Tons/year) Uncontrolled (Tons/year) ' Controlled (Tons/year) PM SOx NOx 0.068 lb/MMBtu AP -42 - de minimis VOC 89,079 Ib/MMscf Gas Analysis 164.69 —x:40. CO 0.310 lb/MMBtu AP -42 - de minimis Benzene 390.1 Ib/MMscf Gas Analysis 0.72 0.04 Toluene 358.1 Ib/MMscf Gas Analysis 0.66 0.03 Ethytbenzene 61.5 lb/MMscf Gas Analysis de minimis de minimis Xylenes 143.8 lb/MMscf Gas Analysis 0.27 0.01 n -Hexane 3,335.8 lb/MMscf Gas Analysis 6.17 0.31 2,2,4- Trimethylpentane 61.9 lb/MMscf Gas Analysis de minimis de minimis Other: 5 Requested values wilt become permit limitations. Requested limits) should consider future process growth. 6Annual emission fees wilt be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APC©-2Q5 -Natural Gas Vent.ng APEN - Rev 03/2017 5 I AY COLORADO [curt, Permit Number: TBD AIRS ID Number: 123 / 9ECD / b� r'ie PLD i, ors: q- cr.-11: Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. O7 /0a/7 Lire of Legally Authorized Person (not a vendor or consultant) Date Jacob Parker Environmental Professional III Name (please print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance O Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-205 -Natural Gas Venting AP -EN - Rev 03/2017 6 I LAY COLORADO iky.nMm,, N., Natural Gas Venting APEN - Form APCD- Air Pollutant Emission Notice (AP£N) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee If the APEN ₹s filled incorrectly or Is missing information and requires re -submittal. This APEN is to be used for Natural Gas Venting only. Natural Gas Venting includes emissions from g separators, well head casing, pneumatic pumps, btowdown events, among other events. If your emission un not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.cotorado.Rov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: TBD MRS ID Number. 123 / 9ECD/ [Leave blank unless APCD has already assigned a periiiit 4 and AIRS ID] Company equipment Identification: SEP-11 thru SEP-12, FLR-01 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Whiting Oil & Gas Corporation Site Name: Razor 12F Production Facility Site Location: SENW Sec 12, T1 ON, R58W Mailing Address: , Suite 2300 1700 Broadway, (Include zlc code} Y Denver, CO 80290 E -Mail Address2: CDPHECorrespondence@whiting.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Jacob Parker Phone Number: (303) 357-4078 'Please 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 APCD via e-mail to the address provided. Form APCD-205 - Natural Gas Venting APEN - Rev 03/2017 COLOR ADO Permit Number. TBD MRS ID Number: 123 /9ECD/ [Leave blank unless APCD has already assigned a permit and AIRS ID] Section 2- Requested Action O NEW permit OR newly -reported emission source OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name ❑ Add point to existing permit ❑ Change permit limit O Transfer of ownership3 Cl Other (describe below) - OR APEN submittal for update only (Please note blank APENs will not be accepted) - ADDcnoNAL PERMIT AcrioNs - • Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info & Notes: Permitting Vapor Recovery Towers (VRT) 3 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 flash gas from VRTs For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / I / / Permit issuance f❑ 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 nonattainrnent area is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions Form APCD-205 Natural Gas Venting APEN Rev 03/2017 O Yes ❑r No O Yes 0 No 2l COLORADO Permit Number: TBD AIRS ID Number: 123 /9ECD/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information E] Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Biowdown Events # of Events/year: ❑ Other Description: Serial #: Capacity: Gal/min # of Pistons: Leak Rate: Scf/hr/pist Volume per event: MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? 0 Yes Natural Gas Venting Process Parameters°: Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: BTU/SCF Requested: MMSCF/year Actual: MMSCF/year -OR- Requested: 912,500 Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: Molecular Weight: VOC (mole %) 60.25 VOC (Weight %) 77.50 Benzene (mole %) 0.19 Benzene (Weight %) 0.34 Toluene (mole %) 0.15 Toluene (Weight %) 0.31 Ethylbenzene (mole %) 0.02 Ethylbenzene (Weight %) 0.05 Xylene (mote %) 0.05 Xylene (Weight %) 0.13 n•Hexane (mole %) 1.47 n -Hexane (Weight %) 2.9 2,2,4•Trimethylpentane (mole %) 0.02 2,2,4-Trimethylpentane (Weight %) 0.05 Additional Required Information: 0 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) Form APCD-205 -Natural Gas Venting APEN • Rev 03/2017 COLORADO 3 IAIM mo. Permit Number: TBD AIRS ID Number: 123 / 9ECD/ [Leave blank unle s APCD has already assigned a permit it and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude cr UTM), 40.808914/403.844297 OperatorTempF� tack iD No Discharge Height Above Ground Leven (Feeeet} ( ' ff Rates �A } Velocity sec ) FLR-01 20 >2000 indicate the direction of the stack outlet: (check one) r❑ Upward ❑ Horizontal ❑ Downward O Other (describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): O Other (describe): ❑ Upward with obstructing raincap 8 Section 6 - Control Device Information VRU: Pollutants Controlled: VRT Gas (VOC and HAPs) Size: 60 HP Requested Control Efficiency VRU Downtime or Bypassed Make/Model: joq on Tattgaftlesr.sctsto.a.as.eo.4eo3 100 % 7 Q Combustion Device: Pollutants Controlled: VRT Gas (VOC and HAPs) Rating: 12 MMBtu/hr Type: Flare Make/Model: Flare Industries SFVP-0824 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency Minimum Temperature: N/A 98 Waste Gas Heat Content Constant Pilot Light: D Yes ❑ No Pilot burner Rating 2,419 0.44 Btu/scf MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested Form APCD-205 -Natural Gas Venting APEN Rev 03/2017 41 br,stramosOlg Mkt COLOR£00 topormemat PM PM Permit Number. TBD AIRS ID Number. 123 f 9ECD/ [Leave blank unless AFCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emissionfactor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes 0 No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): cntrol Equipment Description-: Overall Requested Control Efficiency (% reduction in emissions) SO„ NO„ VOC Gas is sent to Pipeline wl Flare Industries Flare as backup 95% CO HAPs Gas is sent to Pipeline w/ Flare Industries Flare as backup 95% Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission' Factor' Emission Factor Units Emission. Factor Source (AP -42, Mfg. etc) nual Emi Uncontrolled f%ns/year) Controlled'.: (Tans/year).. uested Annual Pe mission Limit(s) Uncontrolled (Tons/year) Controlled. (Tons/year) SO„ NO„ 0.068 lb/MMBtu AP -42 de minimis VOC 89,079 lb/MMscf Gas Analysis 164.69 16.40 CO 0.310 lb/MMBtu AP -42 de minimis Benzene 390.1 Ib/MMscf Gas Analysis 0.72 0.04 Toluene 358.1 Ib/MMscf Gas Analysis 0.66 0.03 Ethylbenzene 61.5 Ib/MMscf Gas Analysis de minimis de minimis Xylenes 143.8 Ib/MMscf Gas Analysis 0.27 0.01 n -Hexane 3,335.8 Ib/MMscf Gas Analysis 6.17 0.31 2,2,4 Trimethylpentane 61.9 lb/MMscf Gas Analysis de minimis de minimis Other:. 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. ‘Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 5[ COLORADO tapimegesurf NW! Permit Number. TBD AIRS ID Number: 123 / 9ECD! Section 8 Applicant Certification I hereby certify that alt Information contained herein and information submitted with this application is complete, true and correct. Jacob Parker of Legally Authorized Person (not a vendor or consultant) Veal Date Environmental Professional Ill Name (please 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) Send this form along with $152.90 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 or (303) 592-3148 APCD-SS-91 4300 Cherry Creek Drive South Or visit the APCD website at: Denver. CO 80246-1530 https://www.colorado.gov/cdphe/apcd Make check payable to: Colorado Department of PubUc Health and Environment Telephone; (303) 692-3150 Farm APCD-205 Natural Gas Venting APEX 'Rev 0312017 law COLORADO Hello