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Home My WebLink About20161377.tiff Ark COPHE COLORADO Co Department of Public Health€r Environment Dedicated to protecting and improving the health and environment of the people of Colorado RECEIVED Weld County - Clerk to the Board APR 2 0 2016 1150 O St PO Box 758 WELD COUNTY Greeley, CO 80632 COMMISSONERS April 14, 2016 Dear Sir or Madam: On April 20, 2016, the Air Pollution Control Division will begin a 30-day public notice period for Whiting Oil and Gas Corporation - Horsetail 08D Production Facility . A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Ft 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 U/. PLI , /4[. '04 2016-1377 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.cotorado.gov,...,p= John W. Hickenlooper, Governor Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer ti ?t , 02.5/lP A CD HE Air Pollution Control Division co Notice of a Proposed Project or Activity Warranting Public ,M Comment Website Title: Whiting Oil and Gas Corporation - Horsetail 08D Production Facility - Weld County Notice Period Begins: April 20, 2016 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: Horsetail 08D Production Facility Oil 8t gas production facility NWNW Section 8, T10N, R57W Weld County The proposed project or activity is as follows: Applicant will operate a newly constructed exploration and production facility. Produced gas from gas/liquid separators will be routed to open flares during Redtail gathering system downtime. Produced hydrocarbon liquids will be stored in atmospheric tanks with emissions controlled by enclosed flares. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permits 15WE1379, 16WE0301, 16WE0300, and 16WE0302 have been filed with the Weld County Clerk's office. Copies of the draft permits and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Bradley Eades Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us COLORADO 1 I AM ,==t Colorado Air Permitting Project Project Details Review Engineer: Bradley Eades Package#: 338169 Received Date: 1/15/2016 Review Start Date: 3/22/2016 Section 01-Facility Information Company Name: Whiting Oil and Gas Corporation County AIRS ID: 123 Plant AIRS ID: 9E2A Facility Name: Horsetail 08D Production Facility Physical Address/Location: NWNW Section 8 TiON R57W Type of Facility: Exploration&Production Well Pad What industry segment? Oil&Natural Gas Production&Processing Is this facility located in a NAAQS non-attainment area? No If yes,for what pollutant? ❑Carton Monoxide(CO) ❑Particulate Matter(PM) ❑Ozone(NOx&VOC) Section 02-Emissions Units In Permit Application Emissions Self Cert AIRs Point# Emissions Source Type Permit# Issuance# Action Engineering Remarks Control? Required? Permit Initial 001 Separator Venting Yes 15WE1379 1 Yes Issuance-„,: Permit Initial' 002 Crude Oil Storage Tank Yes 16WE0301 1 Yes; „ Issuance Permit Initial 003 Hydrocarbon Liquid Loading Yes 16WE0299 1 Yes Issuance Permit Initial 004 Produced Water Storage Tank Yes 16WE0300 1 Yes Issuance Permit Initial 005 Separator Venting Yes 16WE0302 1 Yes Issuance Flaring of gas from VRT intermittent bleed 006 Other(Explaln) No 16WE0303 1 Yes Cancellation, pneumatic devices Section 03-Description of Project Horsetail 08D is a oil and gas production facility located north of the ozone non-attainment area in.Weld County.Streams of liquid and gas from four wells flow into two 2-phase sparators(Point 001)where gas is separated from liquids.Liquids are transferred to two 3-phase"heater-treaters". Produced gas from the separators and heater-treaters are routed to Redtail Gas Gathering System during normal operations.When Recital{Gas Gathering system is not available,the produced gas is routed to the open flare(FLR-01).Produced water from the heater treaters is transferred to storage tanks and subsequently transferred offsite by pipline,or by loadout when pipeline is unavailable.Crude oil from the heater-treaters is transferred to the vapor recovery tower(VRT).Vapors generated in the VRT are captured by a vapor recovery unit(VRU)and routed to gas gathering, During VRU downtime,(maximum of 12%annually requested)the vapors mil be routed to the"backup/emergency low pressure open flare (FLR-02). Crude oil is subsequently transferred ofsite using lease automatic custody transfer unit(LACT)or by truck loadout(point 003).Vapors generated in the crude oil and produced water tanks are routed to the"process enclosed combustor"(COMB-01).Application was originally received 09/28/2015 however a revised application was received January 2016 and added to this service. Section 04-Public Comment Requirments Is Public Comment Required? Yes If yes,why?1 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 Colorado Air Permitting Project Is this stationary source a true minor? No Is this stationary source a synthetic minor? Yes If yes,explain what programs and which pollutants here: Prevention of Significant Deterioration(PSD):VOC, Title V Operating Permits(OP):VOC,HAPs Non Attainment New Source Review(NANSR}:N/A Is this stationary source a major source? No If yes,explain what programs and which pollutants here: Two(2)high-pressure,2--phase separators controlled by flare during downtime of the gas gathering system.Flare 001 has a minimum control efficiency of 95%. SEP-01 through SEP-02 Equipment Description This source vents natural gas from: a well head separator Emissions from this source are: routed to a flare Natural gas venting from a well head separator.Emissions from this source are routed to a flare. *Emissions are only routed to flare during VRU gathering system(Redtail Gathering System)downtime. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q*MW*Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas*MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm Throughput(0) 42.8 MMscf/yr 4883.561644 scf/hr MW 25.06 Ib/Ib-mol 0.117205479 MMscf/d mole% MW Ibx/Ibmol mass fraction lb/hr lb/yr tpy Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 2.36 44.01 1.041 0.042 13.41 117480.48 58.74 N2 1.03 28.013 0.290 0.012 3.73 32698.19 16.35 methane 63.83 16.041 10.239 0.409 131.94 1155784.60 577.89 ethane 12.15 30.063 3.653 0.146 47.07 412293.60 206.15 propane 11.51 44.092 5.077 0.203 65.41 573018.62 286.51 isobutane 1.22 58.118 0.710 0.028 9.15 80151.63 40.08 n-butane 4.31 58.118 2.507 0.100 32.30 282971.07 141.49 isopentane 0.88 72.114 0.634 0.025 8.17 71582.62 35.79 n-pentane 1.18 72.114 0.854 0.034 11.01 96433.86 48.22 cyclopentane 0.32 70.13 0.227 0.009 2.92 25608.24 12.80 n-Hexane 0.30 86.18 0.255 0.010 3.28 28764.67 14.38 cyclohexane 0.04, 84.16 0.035 0.001 0.45 3961.35 1.98 Other hexanes 0.11 86.18 0.093 0.004 1.20 10535.05 5.27 heptanes 0.32 100.21 0.324 0.013 4.17 36535.51 18.27 methylcyclohexane 0.07 98.19 0.069 0.003 0.89 7802.64 3.90 224-TMP 0.00 114.23 0.000 0.000 0.00 0.00 0.00 Benzene 0.04 78.12 0.031 0.001 0.39 3447.79 1.72 Toluene 0.05 92.15 0.048 0.002 0.62 5450.40 2.73 Ethylbenzene 0.01 106.17 0.012 0.000 0.15 1306.26 0.65 Xylenes 0.02 106.17 0.022 0.001 0.29 2516.65 1.26 C8+Heavies 0.22 120.37 0.264 0.011 3.40 29808.39 14.90 VOC mass frac. 0.4454 Total VOC(Uncontrolled) 629.95 Notes Mole%,MW,and mass fractions from Horsetail 08 CPF South Master Sales gas analysis collected 08/28/2015. Emissions are based on 8760 hours of operation per year. I calculated the average MW of C8+based on the average MW on the analysis for the gas. 15WE1379.CP1.xlsm E1379.CP1.xlsm Two(2)high-pressure,2--phase separators controlled by flare during downtime of the gas gathering system.Flare 001 has a minimum control efficiency of 95%. Flaring Information Equipment Description Flare to combust separator gas during collection system downtime. Equipment ID FLR-01 Manufacturer Flare Industries Model SFVP-0824 Serial Number TBD Gas Heating Value 1483 Btu/scf Throughput 65958.74 MMBtu/yr Control Efficiency 95.00% *An additional 1 MMscf/yr is added to the total volume to account for pilot gas(for secondary emissions of Nox and CO).A pilot fuel HV of 2516 is used(Propane). Combustion emission factor source: AP-42:Chapter 13.5 0.07 IIb NOX/MMBtu 0.31 IIb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 29450.55 Ib/MMscf 1472.53 lb/MMscf 629.9 tpy 31.50 tpy Gas Analysis Nox 104.84 lb/MMscf 104.84 lb/MMscf 2.24 tpy 2.24 tpy AP-42 CO 477.96 lb/MMscf 477.96 lb/MMscf 10.2 tpy 10.22 tpy AP-42 Benzene 80.593 lb/MMscf 4.03 lb/MMscf 3448 lb/yr 172 lb/yr Gas Analysis n-Hexane 672.386 lb/MMscf 33.6193 lb/MMscf 28765 lb/yr 1438 lb/yr Gas Analysis Toluene 127.405 lb/MMscf 6.3703 lb/MMscf 5450 lb/yr 273 lb/yr Gas Analysis Xylenes 58.828 lb/MMscf 2.9414 lb/MMscf 2517 lb/yr 126 lb/yr Gas Analysis Ethylbenzene 30.534 lb/MMscf 1.5267 lb/MMscf 1306 lb/yr 65 lb/yr Gas Analysis Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity.' AQCC Regulation 2 Section I.A applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air." AQCC Regulation 7 Was the well newly constructed,hydraulically fractured,or recompleted on or after August 1,2014? yes This separator is subject to Reg 7,Section XVII.G.and control requirements of Reg 7,Section XVII.B.2 NOTES: **Application requested 2%control device downtime during periods when emissions are routed to the Flare.This request was denied based on complications with Reg 7 Section XVII applicabilty. For the purposes of this permit an overall control efficiency of 95%is granted. It is assumed that this granted control efficiency considers downtime,destruction efficiency,and collection/capture efficiency.The applicant originally requested 31 MMscf/yr as the throughput,however this was increased to 42.8 MMscf/yr to allow the operator to report up to 2%of the throughput as uncontrolled without exceeding emissions limits. **Since the separation equipment covered by this permit is subject to Section XVII.G.,the open flare is subject to control device requirements per XVII.G.and XVII.B.Per applicant,this flare is in compliance with all applicable sections of Section XVII except section XVIl.B.2.b requirement for enclosed combustion device. Application indicates '.. that Whiting is requesting use of the open flare as an alternative emissions control equipment per XVII.B.2.e..This request has been approved since the control device meets requiremetns outlined in section 2.3 of PS-Memo 15-03.Primarily,the operator will ensure compliance with all requiements of section XVII(besides being enclosed), and the control device serves as a backup to the primary collection system which utilizes a VRU. **Secondary emissions resulting from combution of waste gas are calculated assuming the entirety of the gas is controlled by the flare for permitting puposes.As '.. previously noted,applicant has notified that a small amount of downtime is expected for the control device whichWhiting intends to report as uncontrolled. **Per email correspondence from Chenine Wozniak,FLR-01 is equipped with a meter that directly measures the volume of gas routed to it from the Separators.for Point 001. '.. **I added 1 MMscf/yr to gas total for calculating MMBtu/yrthrougput when calculating secondary emissions of Nox and CO.This value was derived by operator based on 114 scf/hr and continuous operation of the pilot. 15WE1379.CP1.xlsm • 002 Fourteen(14)above ground 400 bbl atmospheric crude oil storage tanks. Calculations Requsted Throughput 1163547 bbl Control Flare Efficiency 95.00%J Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.2435 lb/bbl 141.66 tpy 7.08 tpy Hysys/EPA Tai Benzene 0.0014 lb/bbl 1583.80 lb/yr 79.19 lb/yr Hysys/EPATai Toluene 0.0012 lb/bbl 1352.60 lb/yr 67.63 lb/yr Hysys/EPATai Ethylbenze 0.0005 lb/bbl 567.40 lb/yr 28.37 lb/yr Hysys/EPA Tai Xylenes 0.0003 lb/bbl 400.00 lb/yr 20.00 lb/yr Hysys/EPATai 2,2,4-IMP 0.0010 lb/bbl 1135.60 lb/yr 56.78 lb/yr Hysys/EPA Tai n-Hexane 0.0077 lb/bbl 9014.40 lb/yr 450.72 lb/yr Hysys/EPA Tai Secondary Emissions-Combustion Device(s) FROM HYSYS"VAPOR TO CONTROL" gas= 2750 Btu/scf .004024 MMSCFD Volume of waste gas emitted per BBL of liquids produced= 1.7813''scf/bbl* 2259 bbl/day Request heat content of waste gas routed to combu≤ 5,699.7220 MMBTU per year Potential to Emit(PTE)heat content of waste gas 5,700 MMBTU per year *scf/bbl is based on std.gas flow(Hysys simulation) Pollutant Emission Factor Emissions while controlled Source Nox 0.068 lb/MMbtu 0.2 tpy AP-42 CO 0.31 lb/MMBtu 0.9 tpy AP-42 Regulatory Review Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20%opacity.This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes.The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR, Part 60,Appendix A(July, 1992))in all subsections of Section II.A and B of this regulation. Section II.A.5-Smokeless Flare or Flares for the Combustion of Waste Gases 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 for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2—Odor Section I.A-No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air. Regulation 6-New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. This source is not subject because each tank is less than 19,800 gallons(471 bbl) NSPS OOOO:for storage vessels in the natural gas production,transmission,and processing segments. This source is not subject because each"storage vessel"emits less than 6 tpy VOC. Regulation 7"-Volatile Organic Compounds XII.VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is not subject to the emission control requirements for condensate tanks since it is located in an attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... Applicant is subject to Section XVII.C because uncontrolled acutal emissions are permitted greater than 6 tpy VOC. NOTES: *Liquids from wellhead undergo three stages of gas/liquid separation prior to storage in tanks(2-phase Separator->3-phase Separator/Heater Treater->VRT-->Tanks)Emissions from the VRT and Tanks were modeled in Hysys using a pressurized liquid sample from the 3-phase heater-treater.Working and breathing losses were calculated using EPA Tanks and a full speciation of the sales oil obtained from the Hysys model. *Secondary emissions are below APEN thresholds and will therefore not be included as permit limits **Application requested 2%control device downtime during periods when emissions are routed to the Flare. This request was denied based on complications with Reg 7 Section XVII applicabilty. For the purposes of this permit an overall control efficiency of 95%is granted. It is assumed that this granted control efficiency considers downtime,destruction efficiency,and collection/capture efficiency. The applicant originally requested 843,150 bbl/yr as the throughput,however this was increased to 1,163,547 bbl/yr to allow the operator to report up to 2%of the throughput as uncontrolled without exceeding emissions limits. 003 Hydrocarbon Loadout to Tanker Trucks *Requested throughput is based on assumption of 90%of total oil througput is with Lease Automatic Custody Transfer Unit in use. Calculations L=12.46*S*P*M/T(AP-42:Chapter 5.2,Equation 1) L=loading losses in lb per 1000 gallons loaded Factor Meaning Value Units Source 5 Saturation Factor 0.6 AP-42 P True Vapor Pressure 2.33 psia TANKS 4.0/Sales Oil Composition from Hysys M Molecular Weight of Vap 52.75 lb/lb-mole TANKS 4.0/Sales Oil Composition from Hysys T Liquid Temperature 507.51 deg.R TANKS 4.0/Sales Oil Composition from Hysys L 1.81 lb/10^3 gal 7.60E-02 lb/bbl Annual requested Throughput 116354.7 BBL/yr 4886897.2 gal/yr Annual requested VOC emissions 8848 lb/yr 4.42 tpy Control: Flare Efficiency: 95% NCRPs Component Mass Fraction Benzene 0.0030 n-hexane 0.0250 Toluene 0.0020 Xylenes 0.0010 Source: Stable Sales Oil composition(Hysys) Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.0760 lb/bbl 4.42 tpy 0.22 tpy AP-42 Benzene 0.0002 Ib/bbl 26.5 lb/yr 1.3 lb/yr AP-42 n-Hexane 0.0019 lb/bbl 221.2 lb/yr 11.1 lb/yr AP-42 Toluene 0.0002 lb/bbl 17.7 lb/yr 0.9 lb/yr AP-42 Xylenes 0.0001 lb/bbl 8.8 lb/yr 0.4 lb/yr AP-42 Regulatory Review 'Regulation 3-APEN and Permitting Requirements Is this site considered an exploration and production location(e.g.well pad)? Yes If yes,review the following two exemptions for applicability: Does the operator unload less than 10,000 gallons(238 BBLs)per day of crude oil on an annual average basis? No If yes,this emissions point is categorically exempt from permit requirements per Regulation 3,Part B,Section II.D.1.1 Does this operator unload less than 6,750 bbls per year of condensate via splash fill or 16,308 bbls per year of condensate via submerged fill procedure? No If yes,this emissions point is categorically exempt from permit requirements per Regulation 3,Part B,Section I I.D.1.1 NOTES: 'Requested throughput is conservatively based on 10%of the total throughput to the tanks(point 002)since LACT is expected to be in use a minimum 90%of the time(liquids routed directly to pipeline). *Application requested 2%control device downtime during periods when emissions are routed to the Flare. This request was denied based on complications with Reg 7 Section XVII applicabilty. For the purposes of this permit an overall control efficiency of 95%is granted. It is assumed that this granted control efficiency considers downtime,destruction efficiency,and collection/capture efficiency. The applicant originally requested 84,315 bbl/yr as the throughput,however this was increased to 116,355 bbl/yr to allow the operator to report up to 2%of the throughput as uncontrolled without exceeding emissions limits. Six(6)above ground 400 bbl produced water storage tanks.Emissions from the tanks are controlled by an enclosed flare 004 Emissions Calculations Requsted Throughput 1,208,880 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.262 lb/bbl 158.36328 tpy 7.918164 tpy CDPHE Benzene 0.007 lb/bbl 8462.16 lb/yr 423.108 lb/yr CDPHE n-Hexane 0.022 lb/bbl 26595.36 lb/yr 1329.768 lb/yr CDPHE Regulatory Review Section II.A.1-Except as provided in paragraphs 2 through 6 below,no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20%opacity.This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes.The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR,Part 60,Appendix A(July,1992))in all subsections of Section II.A and B of this regulation. • Section II.A.5-Smokeless Flare or Flares for the Combustion of Waste Gases 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 for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2—Odor Section I.A-No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air. NOTES: *Application requested 2%control device downtime during periods when emissions are routed to the Flare.This request was denied based on complications with Reg 7 Section XVII applicabilty. For the purposes of this permit an overall control efficiency of 95%is granted. It is assumed that this granted control efficiency considers downtime,destruction efficiency,and collection/capture efficiency.The applicant originally requested 876,000 bbl/yr as the throughput,however this was increased to 1,208,880 bbl/yr to allow the operator to report up to 2%of the throughput as uncontrolled without exceeding emissions limits. One(1)vapor recovery tower(VRT)controlled by flare during downtime of the gas gathering systemNRU.Flare has a 005 minimum control efficiency of 95%. SEP-04,FLR-02 Equipment Description This source vents natural gas from: a well head separator Emissions from this source are: routed to a flare Natural gas venting from a well head separator.Emissions from this source are routed to a flare. *Emissions are only routed to flare during VRU downtime. Emission Calculation Review A Hysys model was run based on a pressurized liquid sample from the Heater-treater(3-phase separator)prior to the VRT.The model was run assuming a liquid throughput of 843,150 bbl/yr(2310 bbl/day).lb/hr emission rates are from Hysys model'Vapor to VRU"stream.The lb/yr emission rate was calculated assuming 8760 hr/yr operation and divided by the total throughput in the model(2259 bbl/day).This results in a lb/bbl emission factor.Emissions are calculated based on the requested liquid througput to the VRT during VRU downtime. Calculations Data from HYSYS: Total throughput to VRT: 843,150 bbl/yr Pollutant Emissions rate(Hysys) Emissions rate Uncontrolled Emissions Factor VOC 209.0746 lb/hr 1831493.496 lb/yr 2.17 lb/bbl Benzene 1.2561 lb/hr 11003.436 lb/yr 0.01 lb/bbl Toluene 1.0842 lb/hr 9497.592 lb/yr 0.01 lb/bbl Ethylbenzene 0.4583 lb/hr 4014.708 lb/yr 0.00 lb/bbl Xylenes 0.3246 lb/hr 2843.496 lb/yr 0.00 lb/bbl n-Hexane 6.7739 lb/hr 59339.364 lb/yr 0.07 lb/bbl 2,2,4-TMP 0.8642 lb/hr 7570.392 lb/yr 0.01 lb/bbl 15WE1379.CP1.xlsm One(1)vapor recovery tower(VRT)controlled by flare during downtime of the gas gathering systemNRU.Flare has a 005 minimum control efficiency of 95%. Requested Permit Limits: Total throughput to VRT: 1,163,547.00 bbl/yr collection system downtime: 12%(VRU/Redtail gathering) 'Throughput during downtime: I 139,626Ibbl/yr Flaring Information Equipment Description Flare to combust separator gas during collection system downtime. Manufacturer Flare Industries Model MAVP-0824 Serial Number TBD Gas Heating Value 2602 Btu/scf GOR 20.06197 scf/bbl 52201.24594 Btu/bbl Throughput 139,626.00 bbl/yr 7,288.65 MMBtu/yr 'Control Efficiency 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.07 Ilb NOX/MMBtu 0.31 llb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 2.172'Ib/bbl 0.109 lb/bbl 151.6 tpy 7.58 tpy Gas Analysis Nox 0.004 lb/bbl 0.004 lb/bbl 0.2 tpy 0.2 tpy AP-42 CO 0.016 lb/bbl 0.016 lb/bbl 1.1 tpy 1.1 tpy AP-42 Benzene 0.013 lb/bbl 6.5E-04 lb/bbl 1822 lb/yr 91 lb/yr Gas Analysis n-Hexane 0.070 lb/bbl 3.5E-03 lb/bbl 9827 lb/yr 491 lb/yr Gas Analysis Toluene 0.011 lb/bbl 5.6E-04 lb/bbl 1573 lb/yr 79 lb/yr Gas Analysis Xylenes 0.003 lb/bbl _ __1.7E-04 lb/bbl 471 lb/yr 24 lb/yr Gas Analysis Ethylbenzene 0.005 lb/bbl 2.4E-04 lb/bbl 665 lb/yr 33 lb/yr Gas Analysis Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' AQCC Regulation 2 Section I.A applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air." AQCC Regulation 7 Was the well newly constructed,hydraulically fractured,or recompleted on or after August 1,2014? yes This separator is subject to Reg 7,Section XVII.G.and control requirements of Reg 7,Section XVII.B.2 NOTES: **Application requested 2%control device downtime during periods when emissions are routed to the Flare.This request was denied based on complications with Reg 7 Section XVII applicabilty. For the purposes of this permit an overall control efficiency of 95%is granted. It is assumed that this granted control efficiency considers downtime,destruction efficiency,and collection/capture efficiency.The originally requested througput was increased to 139,626 bbl/yr to allow the operator to report up to 2%of the throughput to the VRT during VRU downtime as uncontrolled without exceeding emissions limits.based on 95%overall control **Since the separation equipment covered by this permit is subject to Section XVII.G.,the open flare is subject to control device requirements per XVII.G.and XVII.B.Per applicant, this flare is in compliance with all applicable sections of Section XVII except section XVII.B.2.6 requirement for enclosed combustion device.Application indicates that Whiting is requesting use of the open flare as an alternative emissions control equipment per XVII.B.2.e.This request has been approved since the control device meets requiremetns outlined in section 2.3 of PS-Memo 15-03.Primarily,the operator will ensure compliance with all requiements of section XVII(besides being enclosed),and the control device serves as a backup to the primary collection system which utilizes a VRU. **Secondary emissions are below APEN thresholds and will therefore not be included as permit limits **Per correspondence from Chenine Wozniak,this emission unit is not equipped with a meter to directly measure the volume o f gas directed to the flare.As a result,Whiting has requested to monitor compliance using the crude oil throughput to the VRT during VRU(collection system)downtime.This request has been approved since emissions were modeled using a site-specific pressurized liquid sample was taken upstream of the VRT.A permit condition will be included that requires monitoring of VRU downtime 15 W E1379.CP 1.xlsm COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION FACILITY EMISSION SUMMARY Company Name Whiting Oil and Gas Corporation County AIRS ID 123 History File Edit Date 3/24/2016 Plant AIRS ID 9E2A Ozone Status Attainment Facility Name Horsetail 08D Production Facility EMISSIONS-Uncontrolled(tons per year) EMISSIONS With Controls(tons per year) POINT PERMIT Description PM10 PM2.5 H2S 5O2 NOx VOC Fug CO Total PM10 PM2.5 H2S SO2 NOx VOC Fug CO Total REMARKS AIRS VOC HAPs VOC HAPs ID Previous FACILITY TOTAL 0.0 0.0 0.0 0.0 0.0 TO 0.0 0.0 0.0 0.0 0.0 0.0 U.S 0.0 0.0 00 0.0 0.0 New Facility-No Previous Total Previous Permitted Facilit'total 0.0 0.0 0.0 0.0 00 00 0.0 0.0 0.0 0.0 0.0 00 00 00 0.0 00 0.0 U.S 001 15WE1379 Flaring of Gas from HP separators 629.9 20.7 2.3 31.5 10.3 1.0 New CP 002 16WE0301 14-Crude oil storage tanks 141.7 7.0 0.2 7.1 0.9 0.4 New CP 003 16WE0299 Crude oil loadout to trucks 44 0.1 0.3 0.0 New CP 004 16WE0300 Sic(6)Produced water Tanks 158.4 17.5 8.0 0.9 New CP 005 16WE0302 VRT flaring during collection 151.6 7.2 0.2 7.6 1.1 0.4 New CP downtime 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 FACILITY TOTAL 0.0 0.0 0.0 0.0 0.0 1,085.9 0.0 0.0 52.6 0.0 0.0 0.0 0.0 2.7 54.5 0.0 12.3 2.8 VOC:Syn Minor(PSD and OP) NOx:Minor(PSD and OP) CO: Minor IPSO and OP) HAPS:Syn Minor B.n-hex 8 Total HH:not an affected area source Z2ZZ:NA Permitted Facility Total 0.0 0.0 00 0.0 0.0 1,085.9 0.0 0.0 52.6 0.0 0.0 00 00 2.7 54.5 00 12.3 2.6 Excludes units exempt from permds/APENs (A)Change in Permitted Emissions 00 0.0 00 00 2.7 545 0.0 12.3 Pubcom 8 modeling not required based on (A change in emissions) Total VOC Facility Emissions(point and fugitive) 545 Facility is eligible for GP02 because<90 tpy (t1)Change in Total Permitted VOC emissions(point and fugitive) 54.5 Protect emissions less than 25150 tpy Note 1 15WE1379.CP1,16WE0301.CP1,16WE0300.CP1,16WE0302.CP1 will go to public notice since each permit contains new synthetic minor limits on PTE. Note 2 Page 11 0112 Printed 4/11/2016 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY-HAPs Company Name Whiting Oil and Gas Corporation County AIRS ID 123 Plant AIRS ID 9E2A Facility Name Horsetail 08D Production Facility Emissions-uncontrolled(ibs per year) POINTIPERMIT 'Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n-Hexane McOH 224 TMP H2S TOTAL(tpy) 'Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 15WE1379 Flaring of Gas from HP separators 3448 5450 1306 2517 28765 20.7 002 16WE0301 14-Crude oil storage tanks 1629 1396 582 349 8959 1164 7.0 003 16WE0299 Crude oil loadout to trucks 27 221 0.1 004 16WE0300 Six(6)Produced water Tanks 8462 26595 17.5 005 16WE0302 VRT flaring during collection downtime 1822 1573 665 471 9827 7.2 0.0 0.0 0.0 0.0 0.0 0.0 0.0 TOTAL(tpy) 0.0 0.0 0.0 7.7 4.2 1.3 1.7 37.2 0.0 0.6 0.0 0.0 52.6 I 'Total Reportable=all HAPs where uncontrolled emissions>de minimus values Red Text: uncontrolled emissions<de minimus . Emissions with controls(lbs per year) POINTIPERMIT 'Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n-Hexane McOH 224 TMP H2S TOTAL(tpy) Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 15WE1379 Flaring of Gas from HP separators 172.4 272.5 65.3 125.85 1438.25 1.0 002 16WE0301 14-Crude oil storage tanks 81.45 69.8 29.1 17.45 447.95 58.2 0.4 003 16WE0299 Crude oil loadout to trucks 1.3 11 0.0 004 16WE0300 Six(6)Produced water Tanks 423 1330 0.9 005 16WE0302 VRT flaring during collection downtime 91.1 78.65 33.25 23.55 491.35 0.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 TOTALittpy) 0.0 0.0 0.0 0.4 0.2 0.1 0.1 1.9 0.0 0.0 0.0 0.0 2.6 12 15WE1379.CP1.xlsm 4/11/2016 e 0 'irek la CDPHE Construction Permit CO %' Air Pollution Control Division t� Permit number: 15WE 1379 Issuance: 1 Date issued: Issued to: Whiting Oil and Gas Corporation Facility Name: Horsetail 08D Production Facility Plant AIRS ID: 123/9E2A Physical Location: NWNW SEC 8 T10N R57W County: Weld County General Description: Well Production Facility Equipment or activity subject to this permit: Facility AIRS Emissions Control Equipment ID Point Equipment Description Description SEP-01 through Flaring of natural gas from two (2) high- SEP-02, FLR-01 001 pressure separators during gas gathering Open Flare system downtime. 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. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) :e aratcr Version S_rn Minor 2015-' Page 1 of 7 Y: � ati 3. o. a' _, s ₹ ll ply a all i ial compliance testing and sampling as required in this `y✓` •ermi . d •:"" it = = ults "'• he Division as part of the self-certification process. (Regulation Number 3, Part B, Section III.E.) 4. The operator shall retain the permit final authorization letter issued by the Division, after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 5. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility AIRS Tons per Year Emission Equipment ID Point PM2.5 NO, VOC CO Type SEP-01 through 001 --- 2.3 31.5 10.3 Point SEP-02, FLR-01 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. 6. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility AIRS Control Device Pollutants Equipment ID Point Controlled SEP-01 through SEP- 001 Open Flare VOC and HAP 02, FLR-01 PROCESS LIMITATIONS AND RECORDS 7. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the 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 AIRS Process Parameter Annual Limit Equipment ID Point SEP-01 through SEP- 001 Natural Gas Flaring 42.8 MMSCF 02, FLR-01 44, CDFHE COLORADO CO Air Pollut,on Control Division „ . _ �_ :,�,� Page 2 of 7 illor o r o• rat. ha monito onthly process rates based on the calendar month. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 8. The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas flared from the high-pressure separator(s) using a flow meter. The flow meter shall continuously measure flow rate and record total volumetric flow routed to the open flare from the separators. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits specified and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 9. 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) 10. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 11. 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 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. 12. 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 13. 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 Initial Testing Requirements 14. The owner or operator shalt 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 C"PHE COLORADO a. O ' Aar Pollutant Control Divr con .,.,T I,unl }e _s 'i IL Page 3 of 7 dti g to tha or equal tokR•ne minute in any fifteen minute period during normal -`•pera . ( ti •-r 7, - `ons XVII.B.2. and XVII.A.16) 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,t per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; 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 CPPHE '. COLORADO co Air Pollution Control Dtvr..ton •:_ra - ran—_r,c Page 4 of 7 of ch in u oriz ion Details r obtaining final authorization to operate are located in e R re t -� rtify'"• ' inal Authorization section of this permit. 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: Bradley Eades Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Whiting Oil and Gas Corporation Synthetic Minor facility CEE COLORADO Co Air Pollution Control Division 7,,-I,Jt<I f , Page 5 of 7 No -r -, . ° th;3 = -. this - ' it 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 Uncontrolled Controlled Point Pollutant CAS# Emissions Emissions (lb/yr) (lb/yr) Benzene 71432 3448 172 Toluene 108883 5450 273 001 Ethylbenzene 100414 1306 65 Xylenes 1130207 2517 126 n-Hexane 110543 28765 1438 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 001: Uncontrolled Controlled CAS# Pollutant Emission Factors Emission Factors Source lb/MMSCF lb/MMSCF N0x --- 104.84 AP 42 CO --- 477.96 V0C 29450.55 1472.53 71432 Benzene 80.59 4.03 108883 Toluene 127.41 6.37 100414 Ethylbenzene 30.53 1.53 Gas Analysis 1330207 Xylene 58.83 2.94 110543 n-Hexane 672.39 33.62 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Emission factors for NOx and CO are from AP-42 Chapter 13.5 and HHV of 1,483 Btu/scf. CI' COLORADO O ' Air Pollution Control Dxvx..kon �, f E Page 6 of 7 i 6) I i`. R •a e h R.S. 5 14.1, e h Air Pollutant Emission Notice (APEN) associated with erm a a :`'"ive y-. by from the date it was received the Division. A revised <x� APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, n-Hexane, Total HAPs 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 come COLORADO Fair Pollution Control Division _ JTPt2'tL Page 7 of 7 CDPHE Construction Permit CO ,f Air Pollution Control Division Permit number: 1 6WE0300 Issuance: 1 Date issued: Issued to: Whiting Oil and Gas Corporation Facility Name: Horsetail 08D Production Facility Plant AIRS ID: 123/9E2A Physical Location: NWNW Sec 8 T10N R57W County: Weld County General Description: Well Production Facility Equipment or activity subject to this permit: Facility AIRS Emissions Control Equipment Point Equipment Description Description ID PW-01 THOUGH Six (6) 400 barrel fixed roof storage vessels Enclosed Combustion PW-06, 004 used to store produced water Device COMB-01 This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit 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. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated 5tcrage Tank'+'er=cr 3',n Amor 2015-, Page 1 of 7 i • •l on at Th Div 'on ma °':rant extensions of the deadline. (Regulation Number 3, 'art , ct .F. r. :., 3. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Regulation Number 3, Part B, Section III.E.) 4. The operator shall retain the permit final authorization letter issued by the Division, after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 5. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility AIRS Tons per Year Emission Equipment ID Point PM2.5 NO, VOC CO Type PW-01 THOUGH PW- 004 --- --- 8.0 --- Point 06, COMB-01 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. 6. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility AIRS Control Device Pollutants Equipment ID Point Controlled PW-01 THOUGH PW- 004 Enclosed Combustor(s) VOC and HAP 06, COMB-01 PROCESS LIMITATIONS AND RECORDS 7. 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.) come COLORADO CO ` Aar Pollution Control Division ,t,,v rkt, 1,„kt k k ik, . , ,.-;,I: Page 2 of 7 y :Lt r Facility AIRS Process Parameter Annual Limit Equipment ID Point PW-01 THOUGH PW- 004 Produced Water throughput 1,208,880 barrels 06, COMB-01 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 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 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, 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. 11. 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. 12. 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 £t MAINTENANCE REQUIREMENTS 13. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEM) 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 CDPHE COLORADO 430 O Azr Pollution Control Division I . ,,_ Page 3 of 7 ens 14. 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) 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 (NOX) in ozone nonattainment areas emitting less than 100 tons of VOC or NO. per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or 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 CDPHE : COLORADO CO Au Pollution Control Division Page 4 of 7 1 of e nt un th operati or activity commences and has been verified by the APCD s co i all = wit = 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. 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: Bradley Eades Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation GDPHE COLORADO Co ' Air Pollution Control Division x 1 _3"dk, x„ri Page 5 of 7 � F or A No - -r • u .th- , this it issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Uncontrolled Controlled Point Pollutant CAS# Emissions Emissions (Ib/yr) (Ib/yr) Benzene 71432 8462 423 004 n-Hexane 110543 26595 1330 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: Uncontrolled Controlled CAS# Pollutant Emission Factors Emission Factors Source lb/bbl lb/bbl V0C 0.262 0.013 CDPHE 71432 Benzene 0.007 3.5E-04 CDPHE 110543 n-Hexane 0.022 1.1E-03 CDPHE Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: CDPHE COLORADO COAu Pollution Control,Dim ton 1 Page 6 of 7 6 D a .rat...,.. Requirement a us Operating Permit Synthetic Minor Source of: VOC, n-Hexane, total HAPs PSD Synthetic Minor Source of: VOC MACT HH Area Source Requirements: Not Applicable 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.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 4 cDPHE COLORADO O ,Air Pollution Control Division Page 7 of 7 4;. 6 CDPHE Construction Permit CO 10 Air Pollution Control Division ,w Permit number: 1 6WE0301 Issuance: 1 Date issued: Issued to: Whiting Oil and Gas Corporation Facility Name: Horsetail 08D Production Facility Plant AIRS ID: 123/9E2A Physical Location: NWNW SEC 8 T10N R57W County: Weld County General Description: Well Production Facility Equipment or activity subject to this permit: Facility AIRS Emissions Control Equipment Point Equipment Description Description ID TK-01 Fourteen (14) 400 barrel fixed roof storage Enclosed Combustion through TK- 002 vessels used to store crude oil Device 14 This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit 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. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) Storage Tanh.'rer=_-acr Svn Mincr IL:15-1 G-1 Page 1 of 7 3. o a s ll ply a all i .ial compliance testing and sampling as required in this :ermi d it ults • he Division as part of the self-certification process. (Regulation Number 3, Part B, Section III.E.) 4. The operator shall retain the permit final authorization letter issued by the Division, after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 5. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility AIRS Tons per Year Emission Equipment ID Point PM2.5 NO, VOC CO Type TK-01 THROUGH TK- 002 --- --- 7.1 --- Point 14 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. 6. The emission points in the table below shalt be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility AIRS Control Device Pollutants Equipment ID Point Controlled TK-01 THROUGH TK- 002 Enclosed Combustor(s) VOC and HAP 14 PROCESS LIMITATIONS AND RECORDS 7. 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 AIRS Process Parameter Annual Limit Equipment ID Point TK-01 THROUGH TK- 002 Crude Oil throughput 1,163,547 barrels COLORADO ` CD C PHE OLORADO Air Pollution Control Divxsion Page 2 of 7 � I • pli c it th nn l throw put limits shall be determined on a rolling twelve (12) ont al. he each``'• th 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 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 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, 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. 11. 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. 12. 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 13. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEM) 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 Initial Testing Requirements 14. 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) 4, CD1NE COLORADO CO Aix Pollution Control Division E≥., rm J..,h1 E, , R-',,,: Page 3 of 7 il', ii.- •d in. g -nts 15. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 16. 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 (NO),) in ozone nonattainment areas emitting less than 100 tons of VOC or NOX 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. 17. 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). 18. MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this stationary source at any such time that this stationary source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of Subpart HH. (Regulation Number 8, Part E, Subpart HH) GENERAL TERMS AND CONDITIONS 19. 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. 20. 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 coPME COLORADO r0 7 Air Pollution Control nnoston Page 4 of 7 . , d fi " a ho f. this ac z ity or operation of this source. Final authorization of the sermi s ec the ', ` D 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. 21. 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. 22. 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. 23. 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. 24. 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. 25. 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: Bradley Eades Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation 4 ctAHE COLORADO 0 Air Pollution Control Dunstan - .:r, -Y 0,t I l 2_ u to+'tit, Page 5 of 7 No - -r • l th • this = 3,, it issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Uncontrolled Controlled Point Pollutant CAS# Emissions Emissions (Ib/yr) (Ib/yr) Benzene 71432 1584 79 Toluene 108883 1353 68 Ethylbenzene 100414 567 28 002 Xylenes 1130207 400 20 n-Hexane 110543 9014 451 2,2,4- 540841 1136 57 Trimethylpentane 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 002: Uncontrolled Controlled CAS# Pollutant Emission Factors Emission Factors Source lb/bbl lb/bbl VOC 0.2435 0.0122 71432 Benzene 0.0014 6.81E-05 108883 Toluene 0.0012 5.81E-05 100414 Ethylbenzene 0.0005 2.44E-05 HYSYS/EPA Tanks 1130207 Xylenes 0.0003 1.72E-05 110543 n-Hexane 0.0077 3.87E-04 540841 2'2'4 0.0010 4.88E-05 Trimethylpentane Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. COP COLORADO O Alt Pollution Control Division Page 6 of 7 6) I '. • •a e h R.S. 5 14.1, e a h Air Pollutant Emission Notice (APEN) associated with perm a a • ive y from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, n-Hexane, Total HAPs PSD Synthetic Minor Source of: VOC MACT HH Area Source Requirements: Not Applicable 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.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 came ' COLORADO Air Pollution Control Division ��,; 'Pub_zt ��;.,�0.,_ .1, Page 7 of 7 up II Alk. 'Irk la CDPHE Construction Permit CO "` Air Pollution Control Division Permit number: 1 6WE0302 Issuance: 1 Date issued: Issued to: Whiting Oil and Gas Corporation Facility Name: Horsetail 08D Production Facility Plant AIRS ID: 123/9E2A Physical Location: NWNW SEC 8 T10N R57W County: Weld County General Description: Well Production Facility Equipment or activity subject to this permit: Facility AIRS Emissions Control Equipment Point Equipment Description Description ID SEP-05, FLR- Flaring of natural gas from one (1)Vapor 02 005 Recovery Tower (VRT) during gas gathering Open Flare system downtime. 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. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) F.4.) Separator Version S'rn Minor zC,1S-1 Page 1 of 7 y 111 3. o a s it pl a all i ial compliance testing and sampling as required in this •ermi d it "- ults • he Division as part of the self-certification process. (Regulation Number 3, Part B, Section III.E.) 4. The operator shall retain the permit final authorization letter issued by the Division, after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 5. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility AIRS Tons per Year Emission Equipment ID Point PM2.5 NO, VOC CO Type SEP-05, FLR-02 005 --- --- 7.6 --- 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. 6. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility AIRS Control Device Pollutants Equipment ID Point Controlled SEP-05, FLR- 005 Open Flare VOC and HAP 02 PROCESS LIMITATIONS AND RECORDS 7. 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 AIRS • Process Parameter Annual Limit Equipment ID Point SEP-05, FLR- Crude Oil Throughput to the VRT 02 005 during vapor recovery unit (VRU) 139,626 barrels downtime The owner or operator shall monitor monthly process rates based on the calendar month. 44, LDPHE COLORADO CO Air Pollution Control Division 4L1 He ._ r Page 2 of 7 • pli c it th nn l throw' F put limits shall be determined on a rolling twelve (12) ont al. he •° :""each . th a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 8. The owner or operator shall continuously monitor and record VRU downtime. VRU downtime shall be defined as times when the VRT gas is routed to the flare. The total hours of downtime and liquid throughput during VRU downtime shall be recorded on a monthly basis and used to demonstrate compliance with the process limits specified and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 9. 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) 10. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 11. 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 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. 12. 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 £t MAINTENANCE REQUIREMENTS 13. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEtM) 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 Initial Testing Requirements 14. 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 4 CWE COLORADO co 4r, An Pollution Control Diva eon ,,, .I'm f Page 3 of 7 • 15. s• rc 's •t r iuir • to co •uct periodic testing, unless otherwise directed by the rrvisi• • o - tat- • = ral r-•T ement. ADDITIONAL REQUIREMENTS 16. 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. 17. 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 18. 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. 19. 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 CORNE COLORADO . Air Pollution Control Division Page 4 of 7 IIch in u oriz ion Details Tr obtaining final authorization to operate are located in e R re t rtify` • inal Authorization section of this permit. 20. 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. 21. 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. 22. 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. 23. 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. 24. 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: Bradley Eades Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation � cAE COLORADO Co Air Poffut,an Control Dan Gan Page 5 of 7 No . . °-r • l th • this - F it issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Uncontrolled Controlled Point Pollutant CAS# Emissions Emissions (lb/yr) (Ib/yr) Benzene 71432 1822 91 Toluene 108883 1573 79 Ethylbenzene 100414 665 33 005 Xylenes 1130207 471 24 n-Hexane 110543 9827 491 2,2,4- 540841 1254 63 Trimethylpentane 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 005: Uncontrolled Controlled CAS# Pollutant Emission Factors Emission Factors Source lb/bbl lb/bbl CO --- 0.016 AP 42 N0x --- 0.004 V0C 2.172 0.109 71432 Benzene 0.013 6.5E-04 108883 Toluene 0.011 5.6E-04 HYSYS Version 8.4 100414 Ethylbenzene 0.005 2.4E-04 1330207 Xylene 0.003 1.7E-04 110543 n-Hexane 0.070 3.5E-03 Drh Ce COLORADO : co vr! Air Follutxon Control Di'n ion r11. , _ .,_ Page 6 of 7 AV. controlled Controlled S# ' • tut. 1 ion Factors Emission Factors Source lb/bbl lb/bbl 540841 2,2,4 0.009 4.5E-04 HYSYS Version 8.4 Trimethylpentane Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Emission factors for VOC and HAPs are based on HYSYS model and pressurized liquid analysis from the 3-phase heater- treater (26 psig/119°F). NOx and CO emission factors were based on waste gas HHV of 2602 Btu/scf. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Status Requirement Synthetic Minor Source of: Operating Permit V0C, n-Hexane, total HAPs PSD Synthetic Minor Source of: V0C 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 CO�P++4HE COLORADO CO Air Pollution Control Division ,e.�. , ,,+3ht Ile n, 1, Page Page 7 of 7 o O la d Y C a. 0 O N �� a. 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