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Home My WebLink About20173748.tiffCOLORADO Department of Public Health Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 11500 St PO Box 758 Greeley, CO 80632 October 26, 2017 Dear Sir or Madam: On November 2, 2017, the Air Pollution Control Division will begin a 30 -day public notice period for Whiting Oil and Gas Corporation - Redtail Gas Plant. 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. Regards, 1, • Colorado Dept. of Public Health a Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure R ,l;c R.vic - Corr`r 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor i Larry Wo c. MD, MSPW, €xoUitive Director and Chiel Medical Officer cC'PLOmni Tei, t-iLC.7TTi, {'W ( E-Rf(fr f JrnJCk) +0/30/17 2017-3748 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Whiting Oil and Gas Corporation - Redtail Gas Plant - Weld County Notice Period Begins: November 2, 2017 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: Redtail Gas Plant Natural Gas Processing Plant NE SEC 21 T1ON R58W Weld County The proposed project or activity is as follows: Modification to incorporate MACT language; permit limit updates The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) • the source is subject to control requirements under a Federal Maximum Available Control Technology requirement for major sources • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 13WE3003 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Timothy Sharp Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us t COLORADO 1I1. Construction Permit Application Preliminary Analysis Summary Section 1 — Applicant Information Company Name: Whiting Oil and Gas Corporation Permit Number: 13WE3003 Source Location: NE 1/4 Sec. 21 T14N R58W, Weld County (attainment) Equipment Description: Plant flare with a minimum combustion efficiency of 95%. AIRS ID: 123-9AD0.013 Date: 08/09/2016 Review Engineer: Timothy Sharp Control Engineer: Stefanie Rucker Section 2 — Action Completed Grandfathered X Modification APEN Required/Permit Exempt X CP2 Transfer of Ownership APEN Exempt/Permit Exempt Section 3 — Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no" to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? 08/09/2016 Section 4 — Source Description AIRS Point Equipment Description 013 Flare is used for upsets and/or emergencies. This flare receives: purge gas, emissions from electric compressor and amine blowdowns, and plant blowdowns. The flare has a minimum combustion efficiency of 95%. The flare is not enclosed. Is this a portable source? Yes X No Is this location in a non -attainment area for any criteria pollutant? Yes X No If "yes", for what pollutant? PMia CO Ozone Is this location in an attainment maintenance area for any criteria pollutant? Yes X No If "yes", for what pollutant? (Note: These pollutants are subject to minor source RACT per Regulation 3, Part B, Section III.D.2) Philip CO Ozone Is this source located in the 8 -hour ozone non - attainment region? (Note: If "yes" the provisions of Regulation 7, Sections XII and XVII.C may apply) Yes { X No Page 1 Section 5 — Emission Estimate Information AIRS Point Emission Factor Source 013 Site -specific (Refer to Section 14 for calculations) Did the applicant provide actual process data for the emission inventory? X Yes No Basis for Potential to Emit (PTE) AIRS Point Process Consumption/Throughput/Production 013 193.1 mmscf/yr Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 013 193.1 mmscf/yr NA Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 013 193.1 mmscflyr Does this facility use control devices? I "-- Yes No AIRS Point Process Control Device Description % Reduction Granted 013 01 Continuous- Pilot Plant Flare 95 Point NOx VOC CO Single HAP Total HAP PTE: 008 7.5 423.6 30.8 3.33 (n -hexane) 1.31 Uncontrolled point source emission rate:(n-hexane) 008 7.5 423.6 30.8 3.33 1.31 Controlled point source emission rate: 008 7.5 423.6 30, g 3.33 (n -hexane) 0.065 Section 7 — Non -Criteria / Hazardous Air Pollutants— Pollutant CAS # BIN Uncontrolled Emission Rate ilb/yr) Are the Controlled Emission emissions reportable? Rate (Iblyr) n -Hexane 110543 C 6653 Yes 333 Note: Regulation 3, Part A, Section II.B,3.b APEN emission reporting requirements for non -criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8 —Testing Requirements Will testing be required to show compliance with any emission rate or regulatory standard? Yes X No If "yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 008 01 VOC, HAPS State only requirement Site -specific gas analysis Page 2 Section 9 -- Source Classification Is this a new previously un-permitted source? Yes X No What is this facility classification? True Minor Synthetic Minor X Major Classification relates to what programs? X Title V X PSD NA NSR X MACT Is this a modification to an existing permit? X Yes No If "yes" what kind of modification? Minor X Synthetic Minor Major Section 10 — Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If "yes", for which pollutants? Why? VOC, HAPs For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? Yes X No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 — Modeling Is modeling required to demonstrate compliance with National Ambient Air Quality Standards (NAAQS)? If "yes", for which pollutants? Why? NOx emissions are less than 40 TPY. Yes X No AIRS Point Section 12 — Regulatory Review I Regulation1 - Particulate, Smoke. Carbon Monoxide and Sulfur Dioxide 013 Section Il.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 013 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 3 - APENs. Construction Permits. Operating Permits. PSD 013 Part A-APEN Requirements Criteria Pollutants: Applicant is required to file an APEN since emissions exceed 2 tons per year VOC 013 Part B — Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 5.0 TPY threshold (Reg. 3, Part B, Section ll.D.3.a) Regulation 6 - New Source Performance Standards 013 None Regulation 7 - Volatile Organic Compounds 013 None Regulation 8 - Hazardous Air Pollutants 013 None Page 3 Section 13 — Aerometric Information Retrieval System Coding Information Point Process Process Description Emission Pollutant/ Factor CAS # Fugitive {YIN) Emission Factor Source Control OA) 013 01 4116 lb/MMscf VOC No Engineering Calculation 95 0.068 lb/MMBtu NOx No AP -42, Table 13.5-1 NA Flare 0.37 lb/MMBtu CO No AP -42, Table 13.5-1 NA 106.26 lb/MMscf n -hexane No Engineering Calculation 95 SCC 31000205 -Flares Section 14— Miscellaneous Application Notes AIRS Point 013 Flare Emissions were calculated using: ((scf/hr) * (Ib/Ib-mol)) / (379.4 scf/1b-mol) = lb/hr * (hr/yr) 12000 lb/T) = TPY V0C = (423.6 TPY * 2000 lb/T) / (193.1 mrnscf/yr) = 4388 lb/mmscf NOx and CO (from AP -42, Chapter 13, Table 13.5-1 (NOx = 0.068 lb/mmbtu; CO = 0.31 Ib/mmbtu) Emissions were based on a weighted average from various plant sources (blowdowns, pilot, residue gas, etc.) Emission factors for HAPS are: To calculate emission factors, take the emissions (Ib/yr) and divide it by total throughput (mmscf/yr). n -hexane = (6653 Ib/yr) / 193.1 mmscf/yr = 34.26 Ib/mmscf Emissions generated from the flare are: Uncontrolled Total (tpy) Controlled Total (tpy) NOx 0 7.5 VOC 423.6 21.2 CO 0 30.8 n -hexane 6653 (Ibs/yr) 333 (lbs/yr) An extended gas analysis was provided in the application dated 11/10/2015. The gas analysis was performed less than a year of submittal. An updated extended gas analysis will not be required. Page 4 Construction Permit Application Preliminary Analysis Summary Section 1 — Applicant Information Company Name: Whiting Oil and Gas Corporation Permit Number(s): 13WE3004 Source Location Redtail Gas Plant, NE 1/4 Section 21, -NON R58W (Weld County attainment) Equipment Description: Natural gas -fired hot oil heater AIRS ID: 123/9AD0/014 Date: 08/09/2016 Review Engineer: Timothy Sharp Control Engineer: Stefanie Rucker Section 2 — Action Completed X CP2 X Modification APEN Required/Permit Exempt Final Approval Transfer of Ownership APEN Exempt/Permit Exempt Section 3 — Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes 1 No If you answered "no" to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? 03/31/2017 Section 4 — Source Description AIRS Point Equipment Description 014 One (1) Zeeco hot oil heater, Model: GLSF14, Serial Number: J131132 with a total design heat input rate of 43.64 MMBtu/hr. This heater is fueled by natural gas. This heater is equipped with low NOx burners. Is this a portable source? Yes X No Is this location in a non -attainment area for any criteria pollutant? Yes X / No If "yes", for what pollutant? PM,o CO J Ozone Is this location in an attainment maintenance area for any criteria pollutant? Yes X No If "yes", for what pollutant? (Note: These pollutants are subject to minor source RACT per Regulation 3, Part B, Section III.D.2) PMio CO No Ozone Is this source located in the 8 -hour ozone non - attainment region? (Note: If "yes" the provisions of Regulation 7, Sections XII and XVI may apply) Yes X Page 1 Section 5 — Emission Estimate Information AIRS Point Emission Factor Source 014 Emissions from the hot oil heater are based on manufacturer's guaranteed emission factors for PM, NOx, CO and VOC. SO2 emissions and HAP emissions are based on AP -42 Table 1.4-3 Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit tPTE1 AIRS Point Process Consumption/Throughput/Production 014 Combustion of natural gas through the hot oil heater shall not exceed 375 MMSCF per year or 31.3 MMSCF per month. (Based an natural as heat value of 1020 blu/scf) Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 014 Combustion of natural gas through the hot oil heater shall not exceed 375 MMSCF per year or 31.3 MMSCF per month. (Based on natural gas heat value of 1020 btu/scf) Does this source use a control device? X Yes No AIRS Point Process Control Device Description Pollutant % Reduction Granted 014 01 None (LowNOx burner considered process) N/A 0.0 Section 6 — Emission Summary (tons per year) Facility, PTE Before Emissions Controls: Point (process) TSP PMK() PM2.5 SO2 NOx VOC CO Single Total HAP HAPs 014 --- 2.48 2.48 0.11 12.62 3.63 7.84 0.34 (n- 0.35 hexane Controlled point source emission rate: Point (process) TSP PMio PM2.5 SO2 NOx VOC CO Single HAP Total HAPs 014 -r_ 2.48 2.48 0 11 112.62 3.63 7.84 0.34 (n- hexane) 0.35 Section 7 — Non -Criteria I Hazardous Air Pollutants Controlled Emission Rate i (Iblyr) AIRS Point Pollutant Uncontrolled Are the CAS # BIN Emission Rate emissions (lb/yr) reportable? 014 n -Hexane 110543 C 675 YES 675 Note: Regulation 3, Part A, Section II.B.3.b APEN emission reporting requirements for non -criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8 —Testing Requirements Will testing be required to show compliance with any emission rate or regulatory standard? I Yes X 4 No If "yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 014 0l N/A None Page 2 Section 9 - Source Classification Is this a new previously un-permitted source? X Yes 1 No What is this facility classification? cation? True Minor Synthetic Minor Major Classification relates to what programs? X Title V X PSD NA NSR X MACT Is this a modification to an existing permit? X Yes No If "yes" what kind of modification? x Minor Synthetic Minor . Major Section 10 — Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If "yes", for which pollutants? Why? VOC, HAPs For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? Yes X No For Reg. 3, Part B, III.C.1.c.ii (subject to MACT)? X Yes No For Reg. 3, Part B, lII.C.1.d (synthetic minor emission limits)? Yes X No Section 11 — Modeling Is modeling required to demonstrate compliance with National Ambient Air Quality Standards (NAAQS)? If "yes", for which pollutants? Why? Yes X No Section 12 — Aerometric Information Retrieval System Coding Information Point Process Process Description Emission Factor Pollutant / CAS # Fugitive (YIN) Emission Factor Source Control (/o) 014 01 43.64 MMBtu/hr Hot Oil Heater 13.26 Ib/MMSCF fuel input PMio No Manufacturer Estimate 0.0 13.26 Ib/MMSCF fuel input PM2 a No Manufacturer Estimate 0.0 0.6 lb/MMSCF fuel input SO2 No AP -42 Table 1.4-2 0.0 67'32 Ib/MMSCF fuel input NOx No Manufacturer Estimate 0.0 41.82 lb/MMSCF fuel input CO No Manufacturer Estimate 0 0 19.38 lb/MMSCF fuel input VOC No Manufacturer Estimate 0.0 1.8 Ib/MMSCF fuel input n -Hexane No AP -42 Table 1.4-3 0.0 SCC 10300602— External Combustion Boiler: Commercial/Institutional: Natural Gas: 10 - 100 MMBtu/hr Notes Important Conversion Factors: • Fuel heating value of 1020 Btu/SCF Page 3 Section 13 — Miscellaneous Application Notes AIRS Point 014 43.64 MMBtu/hr Hot Oil Heater MODIFICATION NOTES: Inclusion of MACT DDDDD requirements into permit. Permit limits not affected. Page 4 Colorado Air Permitting Project Project Details Review Engineer: Package #: Received Date: Review Start Date: Section 01- Facility Information Timothy Sharp 351975 5/9/2015 1/1/2017 Company Name - County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/location: Type of Facility: What industry segment? Is this facility located in a NAAQS non -attainment area? If yes, for what pollutant? D arbors Monoxide (Co) particulate Metter (PM) Dzore (Nos & vocl Whking Dii and Gas Corporation 123 9AD0 Redtail Gas Plant NE/4 quadrant of Section 21, Township 10N, Range 58W, in Weld County, Colorado Natural Gas Processing Plant Oil & Natural Gas Production & Processing 'Weld Quadrant Section Township Range N E/4 21 ION 55 No Section 02 - Emissions Units In Permit Application AIRs Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance t Self Cart Required? Action Engineering Remarks 015 EG Dehydrator DEHY-1 Yes 13WE30OE 3 No Permit Modification Update throughput/limi is & add MACT HH to permit Section 03 - Description of Project Section 04 - Public Comment Requirements Is Public Comment Required? No If yes, why? Section 05 - Ambient Air Impact Analysis Requirements Was a quantitative modeling analysis required? No If yes, for what pollutants? If yes, attach a copy of Technic& Services Unit modeling results summary. Colorado Air Permitting Project Section 06 - acuity wide Stationary Source Classification Is this stationary source a true minor? No Is this stationary source a synthetic minor? No If yes, indicate programs and which pollutants: 5O2 NOx CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration (P5D) ❑ ❑ ❑ ❑ ❑ ❑ Title V Operating Permits (OP) ❑ ❑ ❑ ❑ II CI ❑ ❑ Non -Attainment New Source Review (NANSR) O ❑ Is this stationary source a major source? res If yes, explain what programs and which pollutants here: 5O2 NOx CO VOC PM2.5 PM1D TSP HAPs Prevention of Significant Deterioration (PSD) ❑ 0 0 0 O ❑ Title V Operating Permits (OP) ❑ ❑ ❑ 0 ❑ 000 Non -Attainment New Source Review (NANSR) O ❑ Glycol Dehydrator Emissions Inventory !action 11 .Ldmlepgnl lea Mlerm loon u..IlFr elks ID: Plats JS? Point S.dlo„ d2 Inolomi. IL,.rlltlon Dehydrator IMormetlon Dehydrator Type: Make: Model: Serial Number: Design Capacity: Reclrntlatlnn Pump information Number of -Pumps Pump Type Make: Model: Dgslgn/Mag Recirculation Rate: Dehydrator Equipment Flash Tank Reboiler Burner Stripping Gas Dehydrator Equipment Deacrlptlan LO, n t `3115kl!!l!1 el+L r+Issaeua ina,...... 2.0.;.111•.0.1.: idea.M n :nay.. rd... • Yd MMsrf/day As iers/m!nu:e flash tank, and rebutter burner Ores (ll Ethylene Glycol IEGI natural gee dehydration unit 'Rieke: Aloe, Model: SAHEB -20B *mars), Serial Number: 20129990. 12} with a design rapaniey n135 MMsct per den. This emission unit is equipped with 2(Make: Beer, Model: Cat-Sil Duplex Pump! electric ddven glycol pump with a design <Pee.. ol6 gallons per minute Ter Is de -hydra lion and is equipped with a 01111 m,liesh rank, end rebniler burner. Emissions ham the still vent are rooted to an air-ceafnd condenser, and then to the Endwad tiara. Ae a secondary control Etnlaslon Control Device Description: device, still vent emissions are ro uladio the . Ernestons from theflesh tank are routed direr. to the closed -loop system, ie;rin n 0l - ere<•IsI I'g Peri d M,maalun for tm..rmynr !Atli...set Primer? Emissions • Dehydrator Sell Vent and Flash Tank If present) Requested Perm it Limit Throughput= 17,775,0 rrMscf per year Potentlef to Cell PTE/Throughput= 12,775 MMscf per year Secondary Emission- Combustion Devi:els) for Air Oallldlan Control Slid Vane Cenral Condenser sonde m.er •nnnlan'edvtBo-n Cann ad: Prlmery control devise: r„ ayconn:l q...ra ie ego+, Secondary control device: Secondary control device operation: Still Vent Gas Heeling Value: Mill Vine well. G.. ...t Rete: RIM tank Control Primary control device: Primary control device aperetlon, Seconders control deel®: Secondary control device operation: P1.0h Tank Ca} Potting Sahel le aF fine W..i. C.. Veit n.rn- 1'ii_k++T Isar. 1'7W hr/yr 9571 Control Efficiency% :envoi hhkimed. hr/yr 7rul id totli .nse,t-.:c(r avarrn 100% Control ERldenoy% R76P hr/yr rear t,.greep.e ?e i,tru! life.v nay'S hr/yr CP:'1n ur,n:Pe s0. Wet Gas Praaseaad: Still Vent Primary Control: 12,775.0 MMsci/yr Etll VentSecondary Control: 0.0 MMscf/yr Wavle Gee Combrrated: Sttii Vent Primary CuMrol: 0.0 MMscl/yr Still VentSdrandary Control: 0.0 MMari/yr Wet Gee Processed: Flesh Tank Prlmery Cvnlrel: 12,775,; MMcrl/yr Flash Tank Secondary Control: 0.0 MMsct/yr Wes, tins Combusted: Flash Tank Primary Control: 00 MMsct/yr Flash Ten Sea. adarq [antral: 0,h MMsrtlyr Glycol Dehydrator Emissions Inventory 5enten 44 - EI-11ea0Rt reeler, S MPIl10dn111.Y e Oehedletor Input Pmmeters Inlet Gas Pressure InletGas Temperature 0equast.0 Glycol Eleclrwlete Rate oCEI 'fhNI PeAl tml VCC C'eporn rose PWPl,tire no .an,,n LW :b• deeF e apm ',caner:0019-24N O elute) �cnn •+'� C colt Clod 11aii.1 ue.iey tiepIlut.e 09.051 en1 att+15 R e9 0.592 Loin n 001 a 4000 V 01: 1019 1.9045115 ?. ce1e95 3,0001 011.00x. -1 ;',.- 0101, rr eta I1 'flari nefuL t W A: Enneem soArer el mtsYncep R,Unes n Hbvan r. Lan✓ell Slrllar.n P,„ray _rnnlscr I UiW ! t0te0IA.'+1 IS ennoo eat. I I.t1r l .I_1.3 r.h to I n rair 0 MIL COIN Ens,eica rsreors 01.eol neleasourr i m).don .Fern. ganrce PellutnM JMnnlreled Coeurollad. Im/MMtell Ielo.moIJ 'Wet Gas ThreerhPuel LOI.r Gee iheouphpeq POC R 1' 1,511141 1 Lay ,.5011 0.1010111'1 ralunre 0.011191001 P. 9-001S SJ.' S 1h/lbner.s. 000100h37 to I.a:N,:l SS Reline .1_55.1644,51 &Onaen0111 n-PMI R. 46fe:bSli: a 34TMP 'I R Polka:erre 011,1 'W.nl Pri.nery ContraI evils. IMI.J.H I.5Sm SChin Uncee11e1.d LtlePercll.a )!hfMM5Iul rib/MM..li IWaa. Heel CombustedI Merle Gal CamblatadL 00010 r erten PM2.5 0.0000 1.00 4199!.-) t0 l 0.0400 Pollutant S51110. nt 3.c onders Co nbol Doyle. tnultltan (.001 'aunt. U11,411nel.d Ilx0Ma0Ned Ilt/MMhrel Ina MM.tirt (mlese. Hunt Camhuer.dl )west., UM Cambusbdl PM14 0.OOW PM20 - O,oao* 00. I 0 Pons Co I 0 9000 Pollutant IIset 'lank Prlm.ryControl Patin I rnlsa1On racer Suer,. Oncanr, oiled upsorel5 ol.el I Ib0Mr 1Etul E4/Melscrl IW.S14 Hess Cembl1,tadi I 'Whet. Ga. Combeafedl Prn1c 11, 1000 010:.1 [`.sl:.s hVa I e. DONS CO i %CVoi Pollutant Sloth Toni Seconds's fantod Sortie Emission florSoune. J0Strnlroll.e UnC0nlroll.d lly/mMned. plsfeaasrcq (Weer. H... I IWaab Gm. Camb...Wit Il Eumbu.ddl PMO9 0,0090 a PM2.5 ,� e 9 W00 Pone 00990 CO ! 001100 STs•Jis•r• Di_F _:vita} leL._mr1 Old operator request &bulle(1 Requested Meier'°SX 4a Criteria Pollutants potent. to Em. Uncontrolled IEor.OYeeel Actual Emissions Uncontrolled Contraled Irone/000rl Ilnnshe.A Requested Permit Limits Uncontrolled Controlled LMnsryeerl ltanch.arl PUMA PM15 N0s CO YOE 00 80 d0 r,.0 0.0 0.0 J.0 I R8 r,_0 0.4 00 a.o 0.p M0 0.0 e.0 51.9 d.4 .00 4.4 295 19.5 1.4 t't.i 14 Heim -duos Alr Pollutants Po lent lel to Emil Uncontrolled ft01.01. rl Actual Emblbns Uncontrolled Controlled Itons/eaarl titans/yearl :le Oo.runr PPIIIII111 TIM Uncontrolled Contrelled fbns/us.ri Cans/Pearl Re -queued Porno ..-ml. Uneeln1eiled Controlled Ilbhrt {Ib/yrl 9.nwn. Toluene ENrylberaen. %elm. n-Hesene 224TMP !.:4.44 I'n.40 l 41.01 .1.nr.0A 1. LE•01 4rl: 'lit 1.0E-0: r.1-1: i. IL -01 l,et-9; 1.0.-C: 11„ 1 Cat 01 1,11.05 1 OF-I}L 1.1E -0S 1.1•lli L]E'bl 1-9E 31 1, 11,1,01 0 155, 0,1 111 tO 1 It -Or eel f -e-0 .... 01.nh _ 1 if b-5 091,:,3 _ II 0.90400 0.01..14 0.11.10 9.GL+011 0,01 .fi/ 0 Ir Glycol Dehydrator Emissions Inventory 9n: to Ae,uudnn ., P.,!r0.0 4,Skrblron r, :rs l lOn XVI I op NegulaN ,..er I ICII XVI I I 7 N ryri ',et.. XII II ike,:l,+l:on d,oils ler4.1 itrI'.Ia1r0n S. a.n! P. it A{1;uIh yrl "I, I'ay.p•: Nt_�ul�lion0 XIIIf .L!A�l: u_Y all II11 Isar.e;ulAlorY.aPllerbmlr+.araelIaer Inn 1araued anraylisl rcil r.n.rw1,4 pueyanrpi If not ru nrtt rn neµ,lrrrrn y. .e cur,. svll.Ii_ al row <4..trP duvxt for er.lr Ji1WY{Ibr ,r .iyt I1 1111 0,+ee4leno l '..el�r0� 5411 0 ?rlullGan 7._orhu xn �+ n',DM ..re .ini,r. cani,hr n ee. Ynu ha, noirlror no Oar r,Iile ninny :o •n•i, ion ro•eq... ylle•n. .r tr You nn yr r,,11'.r rrwa, Ilnr rh I ra:mly •. nPr ..m,.er rn ,.n rt II II Ir !adlon 01 . Inn l.1 III 1eaetlir 4101 p 0,1.101rvllpe 1W 9lrem.M L W as Or. extended wet gas sample used In the GlyCalc model/Process model site -specific and collected within. year l applieetlon submittal? 0 no, the permit will contain an Initial Compliance" testing requirement to demonstrate cornpllan en wlOt emission 1101110 Dues the compsny requests control device effldency greater than 95% for a flare or combonito n device? Oyes, the permit will conlainand Inns! campllence lest condition to demonstrate the destruction e*Gciency of the combustion desks hoed on Inlet end outlet concentration sampling ✓ tilnn WI- rto Llmeainnarelr ilal., i.5non 09 •....mono SCC Coding end Sol kry,}s.Gln1 AIRS Path g 015 Process 0 SCC Coda 01 1.p1},G01rd GioGrdbllreamra: rinie.d cerAzi_ ynrnny urcenwled Pollutant Gaerua.s rector con, NI x units 01/10 0OIV/01 00% b/MMsoT PM25 9oPV/OI 00% b/MMsd Nen 0,000 00% b/MMset *0C 4 s 0050 0% b/MMY* CO 0000 00% b/MMsei Genuine 0.345 95057% b/MMsd Toluene 0012 96007% b/MMset Ethylbenaene 0001 95000% b/MMsd dykne 0070 96005% b/MMsei n-Hmxne 9000 500000% b/MMsd 224 TMP 0000 IOIV/01 b/MMscr Colorado Air Permitting Project Project Details Review Engineer: Timothy Sharp Package #: 351975 Received Date: 8/9/2015 Review Start Date: 1/1/2017 update sub'd 3/31/2017 Section 01- Facility Information Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Location: NE/4 quadrant of Section 21, Township 10N, Range 58W, in Weld County, Colorado Type of Facility: Natural Gas Processing Plant What industry segment? Oil & Natural Gas Production & Processing Is this facility located in a NAAQS non -attainment area? No If yes, for what pollutant? [carbon Monoxide (Co) inarticulate Matter (PM) atone (NOx & VOC) Whiting Oil and Gas Corporation 123 9A00 Redtail Gas Plant (Weld Quadrant NE/4 Section 21 Township 10N Range 58 Section 02 - Emissions Units In Permit Application AIRS Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cart Required? Action Engineering Remarks 016 EG Dehydrator DEHY-2 Yes 13WE300f 3 No Permit Modification Update throughput/limi is & add MACT HH to permit Section 03 - Description of Project Section 04 - Public Comment Requirements Is Public Comment Required? If yes, why? No Section 05 - Ambient Air Impact Analysis Requirements Was a quantitative modeling analysis required? No If yes, for what pollutants? Colorado Air Permitting Project If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? NC Is this stationary source a synthetic minor? Nc If yes, indicate programs and which pollutants: 5O2 NOx CO VOC PM2.5 PM10 T5P HAPs Prevention of Significant Deterioration {PSD) ❑ ❑ 0 0 0 ❑ Title V Operating Permits {OP) 0 0 DOD ❑ ❑ ❑ Non -Attainment New Source Review (NANSR) 0 0 Is this stationary source a major source? Yes If yes, explain what programs and which pollutants here: 5O2 NOx CO VOC PM2.5 PM1D TSP RAPS Prevention of Significant Deterioration (PSD) 0 ❑ 0 ❑ 0 ❑ Title V Operating Permits (OP) ❑ ❑ 0 p 7 0 0 0 Non -Attainment New Source Review INANSR) 0 ❑ Glycol Dehydrator Emissions Inventory sermon C L - aem ln:stnthe Inman etle-0 Irer: qty AA, , o=nly Gent Puin, y`lle..OS tgr0pmenl Ikmdprlon Cenh, D.hydntor informedon ❑ehydrater Type; Make: Model: Serial Number: Design Capacity: HecIralletlon Pump Itfen,ledon Number of Pumps Pomp Type Make: Model: Design/Men Recirculation Re ten Dehydrator Equipment Flash Tank Reboller Burner Strlppinr Gas Dehydrator Equipment Description teen . Cruet El.t Mt. 20134402-12 TD elrt'r_ Peer C C-Sli Cuplike hang L MMerj/day N•Inns/m nv ft n ,flesh tank, •on and rebailer burner Vn 8ne Ill Ethylene Glycol IEGI ne tarot gas dehydration lair (Make: plc=, Model:, Sena! Number: 2013-S402.t2i with a design rapacity of TO MMscf par 'ley This emissions unit b equipped DIM 2l Male: Beer, Model: CX.EH Dupl.y Pumtl elarlria drown 'glycol pump %NM a design careen, of le cellar par minute, This dehydration unit is equipped with a still rent, fresh lank, end Dbeliar bumar. Emiserone from the still vent are routed to nn Mr -cooled cnndens.r, and then to the Enclosed Flare. As a secondary control Emission Control Deli. Desedpdon: dollne, still centemission, are routed I, the Ern:mien, from the flesh tank are rooted directly en the rinsed -mop system. T.aup,, 0l -'tine,,, ni Ran rnrnrmeonnaor Omlulan. Eyi"myy P rimary Emiseb,s- Dehydrator Still Vent and Flesh Beek lit pr.n.nt) d.nnn Tnd Pa•r>,,:..+-r.l!Fr„uynor.'AMP PANIsof per year Potential to En,it(PTE)Throughput= 25,550 MMscf per year Secondary Eml.elnnn -Combustion Devlcelslfor PT Pollution Control Still Vent Control Condenser Condnnar ambr:parade:Nnrl tLlmtd. Printery control decker Primary control device operation: S.cendery control deMon, S econdary eon Vol devke operation: 5tEl Vent G. fleeting Velum Son/ant We're G. c Year Rel._ Flesh tank Control Prlmery control device: Primary control device operation: Secondary control device: Secondary control device operation: Pin 111 Twit Gm ttaeta i Value Mesh Yank West. Des Vent to,. Fao myi it ar. GIMP hr/yr 03% Control Efficiency% --nnuol rin e:, n.y'. hr/yr lht/scf ore d•iewtrsop„rt•m 100% Controlttlklency% 1766 ar/yr rl ul eltn{etr nr/yr 1016 Elu/scf sera ..-unn0i E•hc.nniu % Wet Gae Processed: Still Vent Primary Control: 25,550.0 MMsct/yr Still Vent Secondary Control: 0 0 MMsri/yr Wert. Gas Combua{ed: Still Vent Prmery Control: 0 0 MMsrf/yr Still Vent 5e condary Control: 0.0 Mfdscf/yr Wit Gm Y.«e.,p Flee Ten Primary Control: 25,5500 MMucf/yr Flash To nk Secondary Control: 0 0 MMscf/yr Waste Des cornblated: Flash Tank Primary Control: 0.0 MMscf/yr Flash Tankcecandayy enehot 0.0 MMscf/yr Glycol Dehydrator Emissions Inventory E. also W - Em tumor Fs. L+IA is Dehydrator Input Pommel,. Inlet Ga. Pressor. Inlet Gee Temperature Requested Glycol Recirculate Hate 1. 01:111 out Ilsig ;M deg gpm Conno! �1C, n-vT PeNOsnl I L're dfSe.kt IO.o.'I GanooEeu {xnrrl :01.5 rgnog I.OIRA rl A31 0.5'-^ 0.713 8.59: 0150 n 001,15 0.10155 0,0001 O.41,F2.,"? e1r.n4 Pnrz:nl tout R.04.91 ..al M]O5 n.an1 224:'!1 P h LOOM PN1k I'urfl.or Vox 11 ..m-onromo.Io.:hn C Or.L,,I V5rrur0 Y iir.0 ikeirolen+Lhyx; :dory 511,01 i lode 0.0000 EVA-dozen., 1.119021 4001 00-8,1 :.n FLun is 010-011 D. h0dnlor Oro h don r. dor toe He Pollutant tuuome 04.4 ianlmrl9d Rld/P4M1locil ILbsM10NH !Wit Gee throu.houtl IWet CO.. Ihni,hpull WIC 131 0 Oh R. M.N. n 500411/115 rLrfd'.Sc Tblurnl .t 06-00s 00o O.NO5141:4 Eth111b.nrue o.Onro15T1i 3.4:$54E PO 1TI.n. 0(101205711 a.rolrETSEP.R r -hours OO,sOROS Ms 1-`zillP CS :101 00.10 0 O Pndlumrd inl l 44 nt Pd wens Con I mil 11.01,1 Emission Fnetor Court. iseeennr,b.d Uncontrolled LIO/h5Malet {IBWMMerfl (Waste Heel Combust.dl {Warta G.. cambustedl PMIO n JfkO FM P.5 ot'a+n 1O. I OOOOO CO ± O.IhRO Pollut.m 5rnr Vent S.cnnd-..vCnnl, ul titre Em1114n 051401 :.ruin. tincvntr,Frd LIrtOml0Llel IIhfMMnlul { Ie1 MMr.1l (Wilt. Hilt I (Waste Gas C,mbustedl Combumd) MAIO 0.,1,1+51 FINIS 0,0 111 r1q: II 0,0001 CO I udOLv1 Pollutant Path 'enll, Ponta rd Control DST'S. Emission Fedor Source Unserhne.d Itnenr,l.ouad 1qt/Mrr4ihll r4+fhtlq,.11 [Wane heat Combusted) IW.400 Gas J Combustudl PM IV O 0000 prr2.I a 9.1971 t]x o. CO I 80010 Pollutant 11.,1, Teel 5..0 ad. ry fomlai Di.. ; m9.0 on incise One rt. OM 9.044 sdecRnrall.d I lbjhshrar,.l lit 00.1 'atoll (Wirt. Hilt Cambered' IMP. Gee Combu.t.dl 11010 0108011 _ 1110,0 5.cwtlO A,3a i O.U1WV fol. i 0A0W Srellm 05. [ml Worms le.eel.,r Old operator mggebt a hu11er? H.quealed Eulfer (%): Ha Criteria Po1101.5r Potential to Emit Uncontrolled flans/yawl Ronal Embslons Ilmmnhall.d Controlled [tans/wall Itonsfynnrt Requested Permit Limits Uncontrolled ConVellud Pronsiveert (tnnaheed PM10 PM2,5 Noe CO VOC 0,+1 0.1 .1.0 4.0 0.4 1.11 67 7,a 0.0 0,0 0.0 e..O n.O 1O ,15 0.0 OtO 0.0 5.0 CO. r). 7 19 7 0,0 14.1 9. n HataM0us Air Poll dnta POMILI9llo Emll Uncontrolled I tdoeh,..rf AstOal Emis51on5 Uncontrolled Controlled Imn:hearl annslyearl kr,.Nri P.m,' lolly Uncontrolled Controlled !tons/veal Ilona/veal l.,•.Ord Porlh.t [tolls Lncsrtrnt!ed Controlled { tilt., I Ilb/rri Toluene Ethylb.onn. 1Od.n. n -Helm 224 TOP Ld•CO '..51,00 1.71.01 1_4r.11O 19:.01 room 115 I. -LE -41 r,le.H I.00.05 1. IT 411 4P1.O1 0, I., 101.1,1 1011.0! i-IF-4: 1.01 -Or rr-Or r[ A n_3f.sl 1-01.24 -I :F.Ol 11,11 HI 15O'O7 1np1 - Orr.,, 0.11.01 I 70.01 r<le,q? !.00.01 II n a,n..na F OE5OO 0.09400 0.00.00 809.6 n b Glycol Dehydrator Emissions Inventory s.rflon Iw • n.eu 1e 01ry 5,11.m.ay eoalr.• 1110 shill' f. NI Is A. I Hecanlmn . 4.111011 0011 I1_0 Grp ' ten r i.4',t,. even : e prveu,.lron r. :ecivo. lW, Wel l:lPen 4.9.,r11.. `Ihf.r r111,Pr14n ?In], Pe -5 maths S.?arr0 MxCT 5ueoe4.4o 141 al c'I fie cam., 4 ,15- M14.7 5Lhhe1: HRN [See 1.pulero.% Apes eW Iltyworanh..i l4. d.I.11.d .n. Iy.1.S 110150111010. Thu intlrrN he wn, rnl denvtlrafar •I not w10:rot 101 R.LIJI.IIo::. t'.4 inn V.11 h.2. t1e11„a[orlr+m e. unreutell on ]_'.111.,1 94111 011111,..1Nure.ed11,,1 rte., 111,1 o•,.rilir,..,,arn rruml,o1 tOni If�l n a I.rl;a •IehV and 1.11,:.,1 r1 otou.r I.h. horrid 1ruliln,l 7;.7,41 11 �Ir 11.9 an I51ve 1.,1-r_ let, 1Ir AI lirl 141,hly It r.1l .001.11 10 01_Ill 1441 ire PirR.. f4aStl111111 ul5=. :.11111011 lost P -�1 Inrffn,l -1,061 And 1.40 LW. Semetl1.(5I feryflmfl5UNI.4nnie Was the artande-2 10100 seriph, seed In the GlyCale model/Process model site-speclfc and collected within ayeer of application ,,,-un.'11415 I} no, the permit will contain an "Inhlal Compliance" -testing requirement to demonstrate compliance with emission 11,5110 Does the company moll ell a central devke efficiency greeter than 95% Fare flare or sombusllon device? If yes, the permit will contain and inidaicomplfance test con dhlcn as demonstrate the destruction efficiency of the vonlbustle n device based on inlet and cutlet concentration sampling 7.4c1Wn 01-e..lnl.er an.r4�11. eIai :i MOM 09 -1a4.,.14fy 4t0 Sad, .hd rn,l,efon. i.rrun AIRS Point II P1000100 We Lads 010 01 -104415la."liyCol 90bsa1:5x1.1-Edtlpenoc r..t. .1ss0i-ld Unconeroiled Pollutant Emission. rector Control % Unite PMSD 0015/01 00}6 Ih1MMscf PM2.5 001V/01 0436 Ib/MMscf 000 0000 00% lb/Weise 521 15 95844% Ih/MMeet CO 0000 00% Ile/MMsc} Benzene 0302 9501 1% Ih/ulMscf Toluene 0 011 0500096 Ih/MMsd Ethelhenzene 0 001 95000% Ib/MMscf Xylene COBS 05000% Ils/MMscf n-Nexene 0 001 97500% lb/MMsef 224 TMP D. 0010/01 Ib/MMscl Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Whiting Oil and Gas Corporation Permit Number: 13WE3007 Source Location: NE 1/4 Section 21 T10N R58W, Weld County (Attainment) Equipment Description: Amine unit AIRS ID: 123/9AD0/017 Date: 08.09.2016 Review Engineer: Timothy Sharp Control Engineer: Stefanie Rucker Section 2 — Action Completed Grandfathered x Modification APEN Required/Permit Exempt X CP2 Transfer of Ownership APEN Exempt/Permit Exempt Section 3 — Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no" to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? 08/09/2016 Section 4 — Source Description AIRS Point Equipment Description 017 Methyldiethanolamine (MDEA) natural gas sweetening system for acid gas removal with a design capacity of 35 MMSCF per day (ALCO, serial number:2007-7722-02). This emissions unit is equipped with two (2) make, model: TBD, electric amine recirculation pump with a total design capacity of 201 gallons per minute. This system includes a natural gas/amine contactor, a flash tank, and a natural gas fired amine regeneration reboiler. Flash tank emissions are re-routed to a common fuel header that feeds the entire facility. The vent stream is controlled by a thermal oxidizer. Is this a portable source? Yes X No _ Is this location in a non -attainment area for any criteria pollutant? Yes X No If "yes", for what pollutant? PMia CO Ozone Is this location in an attainment maintenance area for any criteria pollutant? Yes PMio X No CO Ozone If "yes", for what pollutant? (Note: These pollutants are subject to minor source RACT per Regulation 3, Part B, Section III.D.2) Page 1 Is this source located in the 8 -hour ozone non - attainment region? (Note: If "yes" the provisions of Yes X No Regulation 7, Sections XII and XVII.C may apply) Section 5 — Emission Estimate Information AIRS Point Emission Factor Source 011 Some other Division -approved modeling program (VMG Sim) Did the applicant provide actual process data for the emission' inventory? X Yes No Basis for Potential to Emit (PTE) AIRS Point Process Consumption/Throughput/Production 017 16,425 mmscf per year, natural gas throughput, 201 gallons per minute lean amine circulation rate Basis for Actual Emissions Reported During this APEN Filinct(Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 017 12,775 mmscf per year, natural gas throughput, 167 gallons per minute lean amine circulation rate NA Basis for Permitted Emissions (Permit Limits] AIRS Point Process Consumption/ThroughputlProduction 017 12,775 mmscf per year, natural gas throughput, 167 gallons per minute lean amine circulation rate Does this source use a control device? X Yes ] No AIRS Point Process Control Device Description % Reduction Granted 017 01 Flash tank emissions are re-routed to fuel header 100 017 02 Thermal Oxidizer 95 Section 6 -- Emission Summary T (tons per year) Point NOX VOC CO Single HAP Total HAP PTE 017 --- 320.9 13.6 (Benzene) 34.9 Uncontrolled point source emission rate: 017 --- 320.9 13.6 (Benzene) 34.9 Controlled point source emission rate: 017 --- 10.0 0.7 (Benzene) 1.8 Section 7 — Non -Criteria / Hazardous Air Pollutants Pollutant CAS # BIN Uncontrolled Emission Rate (Ib/yr) Are the emissions reportable? Controlled Emission Rate Emission Benzene 71432 A 27,207 Yes 1,343 Toulene n -Hexane 110543 110543 C C 9,497 Yes 468 2,322 Yes 49 Note: Regulation 3, Part A, Section II.B.3.b APEN emission reporting requirements for non -criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8 —Testing Requirements Will testing be required to show compliance with any emission rate or regulatory standard? X Yes If "yes", complete the information listed below Page 2 AIRS Point Process Pollutant Regulatory Basis Test Method 017 01 VOC, HAPS Regulation No. 3, Part B., Section III.G.3 Stack Test Section 9 -- Source Classification is this a new previously un-permitted source? Yes X No What is this facility classification? True Minor Synthetie Minor X Major Classification relates to what programs? X Title V X PSD NA NSR X MACT Is this a modification to an existing permit? X Yes No If "yes" what kind of modification? x Minor Synthetic Minor Major Section 10 — Public Comment _ Does this permit require public comment per CAQCC Regulation 3? x Yes No If "yes", for which pollutants? Why? For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? Yes X No For Reg. 3, Part B, Fll.C.1.c.iii (subject to MACT)? X Yes No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? Yes X No I Section 11 — Modeling Is modeling required to demonstrate compliance with National Ambient Air Quality Standards (NAAQS)? Yes x No If "yes", for which pollutants? Why? AIRS Point Section 12 — Re ulato Review Regulation 1 - Particulate, Smoke, Carbon Monoxide and Sulfur Dioxide 017 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. Regulation 2 — Odor 017 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 3-APENs, Construction Permits, Operating Permits, PSD 017 Part A-APEN Requirements Criteria Pollutants: Applicant is required to file an APEN since emissions exceed 2 tons per year VOC 017 Part B — Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 5.0 TPY threshold (Reg. 3, Part B,, Section 11.D.3.a) Regulation 6 - New Source Performance Standards 017 NSPS LLL: Each sweetening (amine) unit and each sweetening unit followed by a sulfur recovery unit; manufacturer date after January 24, 1984. Applicant is not subject to NSPS LLL Page 3 017 NSPS OOOO: Each sweetening (amine) unit and each sweetening unit followed by a sulfur recovery unit; manufacturer date after August 23, 2011. Applicant is subject to NSPS 0000 This source will have a design capacity less than 2 long tons/day H2S in the acid gas based on the information submitted in the application. This source will be required by 60.5423(c) to keep for the life of the equipment an analysis demonstrating that the facility's design capacity is less than 2 LT/D of H2S expressed as sulfur. No other requirements apply. Regulation 7 — Voiatiie Organic Compounds 017 None Regulation 8 — Hazardous. Air Poiiutsnts 017 None Section 13 - Aerometric Information Retrieval System Coding Information Point Process Process Description Emission Factor Pollutant 1 CAS # Fugitiv e (YIN) Emission Factor Source Control (°/0) 017 01 Amine Unit (Flash Gas) 14.858 lbs/mmscf VOC No Process Simulator 100 0.02133 lbs/mmscf Benzene / 71432 No Process Simulator 100 0.00533 lbs/mmscf Toluene / 108883 No Process Simulator 100 0.048 lbs/mmscf n -Hexane / 110543 No Process Simulator 100 02 Amine Unit (Vent Gas) 24.2133 Ibs/mmscf VOC No Process Simulator 95 0.1066 lbs/mmscf Benzene / 71432 No Process Simulator 95 0.0533 Ibslmmscf Toluene / 108883 No Process Simulator 95 0.0586 lbs/mmscf n -Hexane / 110543 No Process Simulator 95 ScC 31000305 — Gas Sweetening; Amine process Emission factors include flash tank and still vent and that factors are based on natural gas processing of 16,425MMScf/yr. Page 4 Section 14 — Miscellaneous Application Notes AIRS Point 017 Amine Unit Uncontrolled emission factor calculations using 16,425 MMscf/yr Flash Gas Uncontrolled Emission Factors: VOC = (27.86 lb/hr)*(8760 hr/year)/( 16,425 MMSCF/yr) = 14.86 lb/mmscf Benzene =(0.04 lb/hr)*(8760 hr/year)/( 16,425 MMSCF/yr) = 0.021 lb/mmscf Toluene = (0.01 lb/hr)*(8760 hr/year)/( 16,425 MMSCF/yr) = 0.005 lb/mmscf n -hexane = (0.09 lb/hr)*(8760 hr/year)/( 16,425 MMSCF/yr) = 0.048 lb/mmscf Vent Gas Emission Factors: VOC = (45.4Ib/hr)*(8760 hr/year)/( 16,425 MMSCF/yr) = 24.213 lb/mmscf Benzene =(0.2 lb/hr)*(8760 hr/year)/( 16,425 MMSCF/yr) = 0.107 lb/mmscf Toluene = (0.1 lb/hr)*(8760 hr/year)/( 16,425 MMSCF/yr) = 0.053 lb/mmscf n -hexane = (0.11 Ib/hr)*(8760 hr/year)/( 16,425 MMSCF/yr) = 0.059 lb/mmscf Vent Gas Controlled Emission Factors using only vent gas stream: VOC = ((45.41b/hr)*(8760 hr/year)/( 16,425 MMSCF/yr) ) * (1-0.95) = 1.21 lb/mmscf Benzene =((0.2 lb/hr)*(8760 hr/year)/( 16,425 MMSCF/yr)) * (1-0.95) = 0.005 lb/mmscf Toluene = ((0.1 lb/hr)*(8760 hr/year)/( 16,425 MMSCF/yr) )*(1-0.95) = 0.003 lb/mmscf ri-hexane = ((0.11 lb/hr)*(8760 hr/year)/( 16,425 MMSCF/yr))* (1-0.95) = 0.003 lb/mmscf Page 5 STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 CONSTRUCTION PERMIT PERMIT NO: DATE ISSUED: ISSUED TO: 13WE3003 Issuance 2 Whiting Oil and Gas Corporation THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Redtail Gas Plant, located in the NE 1/4 of Section 21, Township ION, Range 58W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description FLR-1A 013 Process flare (Tornado, SL 16-72-16-0.375-12-316L and serial number: 14180) controlling emissions from routine operations including: purge gas, emissions from electric compressor and amine blowdowns, and plant blowdowns, as well as providing backup control to the thermal oxidizer associated with point 017 (AMINE -1) and the combustors associated with point 015 (DEHY-1) and point 016 (DEHY-2). The flare has a minimum combustion efficiency of 95%. The flare is not enclosed. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. This construction permit represents final permit approval and authority to operate this emissions source. Therefore, it is not necessary to self -certify. (Regulation 3, Part B, Section III,G.5). EMISSION LIMITATIONS AND RECORDS 2. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Monthly Limits: AIRS ID: 123/9AD0 Page 1 of 7 Wellhead Version 2012-1 Colorado Department of Public Health and Environment Air Pollution Control Division Facility Equipment ID AIRS point Pounds per Month Emission Type yp NOX VOC CO FLR-1A 013 1,274 3,602 5,232 Point (Note: Monthly limits are based on a 31 -day month.) The owner or operator shall calculate monthly emissions based on the calendar, month. Facility -wide emissions of each individual hazardous air pollutant shall be less than 1,359 lb/month. Facility -wide emissions of total hazardous air pollutants shall be less than 3,398 lb/month. Annual Limits: Facility Equipment ID AIRS point Tons per Year Emission Type YP NO. VOC CO FLR-1A 013 7.5 21.2 30.8 Point See "Notes to Permit Holder #4" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall be less than 9.0 tpy. Facility -wide emissions of total hazardous air pollutants shall be less than 24.0 tpy. During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 3 The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled FLR-1A 013 Continuous- Pilot flare VOC, HAPs AIRS ID: 123/9AD0 Page 2 of 7 Colorado Department of Public Health and Environment Air Pollution Control Division PROCESS LIMITATIONS AND RECORDS 4. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the throughput shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 Days) FLR-1A 013 Natural gas flaring 193.1 MMSCF/yr 16.4 MMSCF/mo The owner or operator shall calculate monthly process rates based on the calendar month. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 5. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 6. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.1. & 4.) 7. 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. (Reference: Regulation No, 1, Section II.A.5.) 8. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 9. The owner or operator shall continuously monitor the process flare with a thermocouple to ensure the continuous presence of a pilot flame. 10. The owner or operator shall continuously monitor and record the total gas volume routed to the process flare using a flow meter to demonstrate compliance with the throughput and emission limits contained in this permit. OPERATING & MAINTENANCE REQUIREMENTS 11. Upon startup of these points, the applicant shall follow the operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) ADDITIONAL REQUIREMENTS 12. All previous versions of this permit are cancelled upon issuance of this permit. AIRS ID: 123/9AD0 Page 3 of 7 Colorado Department of Public Health and Environment Air Pollution Control Division 13. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 14. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS 15. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 16. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III:G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 17. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. AIRS ID: 123/9AD0 Page 4 of 7 Colorado Department of Public Health and Environment Air Pollution Control Division 18. 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), G.R.S. 19. 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 inrtro. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 20. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (ADEN) 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. 21. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer Permit Histo Issuance Date Description Issuance 1 October 8, 2014 Issued to Whiting Oil and Gas Corporation Issuance 2 This Issuance Modification to permit limits. AIRS ID: 123/9AD0 Page 5 of 7 Colorado Department of Public Health and Environment Air Pollution Control Division Notes to Permit Holder: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part I1, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: http://www.cdphe state. c o. o s/req p iati o ns/ai r reg s/ 100102 aq cccc Ers m o n prov i sio n s re g. pdf . 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emission Rate (lb/yr) Are the emissions reportable? Controlled Emission Rate (Ib/yr) 013 n -hexane 110543 1,722 YES 86 Benzene 71432 552 YES 28 Toluene Xylene 108883 830 YES 42 1330207 293 YES 15 5) The emission levels contained in this permit are based on the following emission factors: CAS # Pollutant Gas Weight Fraction of Gas (lb/lb- mol) Emission Factors Uncontrolled Emission Factors Controlled Source NOx 0.068 Ib/MMBtu 0.068 lb/MMBtu AP -42 CO _ 0.31 lb/MMBtu 0.31 lb/MMBtu AP -42 VOC 1.66 4388 lb/mmscf 219.4 Ib/mmscf Engineering Calculation 110543 n -hexane 0.0034 8.92 lb/mmscf Engineering Calculation 71432 Benzene 0.0011 2.86Ib/mmscf Engineering Calculation 108883 Toluene 0.0016 4.3 lb/mmscf Engineering Calculation 1330207 Xylene 0.0006 1.52Ib/mmscf Engineering Calculation AIRS ID: 123/9AD0 Page 6 of 7 Colorado Department of Public Health and Environment Air Pollution Control Division Note: The uncontrolled VOC and HAP emissions for this point were calculated using the analysis of a gas sample collected from several wells. The controlled VOC emissions factors 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: Applicable Requirement Status i Operating Permit Major Source of: VOC Area Source of: HAPs PSD Synthetic Minor Source of: VOC MACT HH & DDDDD Major Source Requirements: Applicable The facility was previously a Major Source of HAPs, but is now an Area Source of HAPs 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http:Pec fr.a ieacccss.ouvl 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 AIRS ID: 123/9AD0 Page 7 of 7 STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 CONSTRUCTION PERMIT PERMIT NO: DATE ISSUED: ISSUED TO: 13WE3004 Issuance 2 Whiting Oil and Gas Corporation THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas production facility, known as the Redtail Gas Plant, located in the NE 1/4 of Section 21, Township 10N, Range 58W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description HTR-1A 014 One (1) Zeeco hot oil heater, Model: GLSF14, Serial Number: J131132, with a total design heat input rate of 43.64 MMBtu/hr. This heater is fueled by natural gas. This heater is equipped with low NOx burners. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. This construction permit represents final permit approval and authority to operate this emissions source. Therefore, it is not necessary to self -certify. (Regulation 3, Part B, Section III.G,5). EMISSION LIMITATIONS AND RECORDS 2. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Monthly Limits: Facility Equipment ID AIRS Point Pounds per Month Emission Type NOx VOC CO PM,o PM2.5 HTR-1A 014 2158 629 1342 425 425 Point AIRS ID: 123/9AD0 Page 1 of 8 Multi -Unit Version 2008-1 Colorado Department of Public Health and Environment Air Pollution Control Division (Note: Monthly limits are based on a 31 -day month.) The owner or operator shall calculate monthly emissions based on the calendar month. Facility -wide emissions of each individual hazardous air pollutant shall be less than 1,359 lb/month. Facility -wide emissions of total hazardous air pollutants shall be less than 3,398 lb/month. Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM,o PM2.5 NO, VOC CO HTR-1 A 014 2.5 2.5 12.7 3.7 7.9 Point 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 be less than 8.0 tpy. Facility -wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. PROCESS LIMITATIONS AND RECORDS 3. This source shall be limited to the following maximum consumption, processing and/or operational rates as listed below. Monthly records of the actual process rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 days) HTR-1A 014 Combustion of natural gas as a fuel 37531.85 MMscf/yr MscfJyr Mscf/month The owner or operator shall calculate monthly process rates based on the calendar month. AIRS ID: 123/9ADO Page 2 of 8 Colorado Department of Public Health and Environment Air Pollution Control Division During the first twelve (12) months of operation, compliance with both the monthly and annual throughput limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. 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 4. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III,E.) (State only enforceable) 5. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XlI.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) 6. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 7. This source is subject to the New Source Performance Standards requirements of Regulation No. 6, Part A Subpart Dc, Standards of Performance for Small Industrial - Commercial -institutional Steam Generating Units including, but not limited to, the following: a. The owner or operator of the facility shall record and maintain records of the amount of fuel combusted during each month (40 CFR Part 60.48c(g)). b. Monthly records of fuel combusted required under the previous condition shall be maintained by the owner or operator of the facility for a period of two years following the date of such record (40 CFR Part 60.48c(i)). In addition, the following requirements of Regulation No. 6, Part A, Subpart A, General Provisions, apply. c. At all times, including periods of start-up, shutdown, and malfunction, the facility and control equipment shall, to the extent practicable, be maintained and operated in a manner consistent with good air pollution control practices for minimizing emissions. Determination of whether or not acceptable operating and maintenance procedures are being used will be based on information available to the Division, which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. (Reference: Regulation No. 6, Part A. General Provisions from 40 CFR 60.11 d. No article, machine, equipment or process shall be used to conceal an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based AIRS ID: 123/9AD0 Page 3 of 8 Colorado Department of Public Health and Environment Air Pollution Control Division on the concentration of a pollutant in the gases discharged to the atmosphere. (§ 60.12) e. Written notification of construction and initial startup dates shall be submitted to the Division as required under § 60.7. f. Records of startups, shutdowns, and malfunctions shall be maintained, as required under § 60.7. 8. Particulate matter emissions shall be limited as per: Regulation 6, Part B, II.C.2. Specific Requirements for Process Heaters 9. See Subpart DDDDD—National Emission Standards for Hazardous Air Pollutants for Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters 40 C.F.R Part 63, Subpart DDDDD. Process heaters not already associated with glycol dehydrators regulated by 40 CFR § 63 Subpart HH are subject to Subpart DDDDD. Applicable requirements of Subpart DDDDD to HTR-1A are limited to work practice standards (i.e., annual tune-up), annual reporting, and maintenance of compliance records. As point 014 (HTR-1A) burns only natural gas, no fuel analysis is required OPERATING & MAINTENANCE REQUIREMENTS 1D. This source is not required to follow a Division -approved operating and maintenance plan. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 11, No initial testing required. Periodic Testing Requirements 12. No periodic testing required. ADDITIONAL REQUIREMENTS. 13. All previous versions of this permit are cancelled upon issuance of this permit. 14. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, l l.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or AIRS ID: 123/9AD0 Page 4 of 8 Colorado Department of Public Health and Environment Air Pollution Control Division For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 15. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS 16. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 17. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section I1I.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. 18. 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. 19. 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. 20. 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 iriitio. This AIRS ID: 123/9AD0 Page 5 of 8 Colorado Department of Public Health and Environment Air Pollution Control Division 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. 21. 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. 22. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer Permit Histo Issuance Date Description Issuance 1 October 8, 2014 Issued to Whiting Oil and Gas Corporation Issuance 2 This Issuance Modification to incorporate MACT DDDDD. AIRS ID: 123/9AD0 Page 6 of 8 Colorado Department of Public Health and Environment Air Pollution Control Division Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the 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: http:llwww.colorado,aovlcs/Saleilite?c=Document C&childpagename=CDPHE- Main%2FDocument C%2FCBONAddLinkView&cid=1251599389641 &oaoename,--CBON rapper 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emission Rate (Ib/yr) Are the emissions reportable? Controlled Emission Rate (lb/vr) 014 n -Hexane 110543 675 YES 675 5) The emission levels contained in this permit are based on the following emission factors: CAS # Pollutant Emission Factors Uncontrolled Ib/MMSCF Natural Gas Combusted Source PM,o 13.26 Manufacturer PM2.5 13.26 Manufacturer NOx 67.32 Manufacturer CO 41.82 Manufacturer VOC 19.38 Manufacturer 110543 n -Hexane 1.8 AP -42 Table 1.4-3 Fuel heat value 1020 btu/scf was used to convert emissions factors from lb/mmbtu to Ib/mmscf_ 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: AIRS ID: 123/9AD0 Page 7 of 8 Colorado Department of Public Health and Environment Air Pollution Control Division Applicable Requirement Status Operating Permit Major Source: VOC Area Source: HAPs PSD Synthetic Minor Source of: VOC MACT HH & DDDDD Major Source Requirements: Applicable The facility was previously a Major Source of.HAPs but is now an Area Source of HAPs 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: 1: ttp:Ilecfr.gpoaccess.covf 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 777Z — Subpart MMMMM MACT 63.8980 -End Subpart NNNNN — Subpart XXXXXX AIRS ID: 123/9AD0 Page 8 of 8 Permit number: Date issued: Issued to: COLORADO Air Pollution Control Division Department of Public Health b Environment CONSTRUCTION PERMIT 13WE3005 Issuance: 3 Whiting Oil and Gas Corporation Facility Name: Redtail Gas Plant Plant AIRS ID: 123/9AD0 Physical Location: NE1/4 SEC 21 T10N R58W County: Weld County General Description: Natural Gas Processing Plant Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description DENY -1 015 One (1) Ethylene Glycol (EG), natural gas dehydration unit (Alco, FAB38-20B, serial number: 2012-8390-12) with a design capacity of 35.0 MMscf per day. This emissions unit is equipped with two (2) Bear CX-5H Duplex electric -glycol pumps with a design capacity of 6 gal/min. This unit is equipped with a flash tank, reboiler and still vent. Emissions from the still vent are routed to an air-cooled condenser and then to an enclosed combustor. Emissions from the flash tank are routed /recycled to plant's inlet slug catcher. Emissions from the still vent and flash tank can be routed as a backup control to the plant flare, point 013 (FLR-1 A). This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. This construction permit represents final permit approval and authority to operate this emissions source. Therefore, it is not necessary to self -certify. (Regulation Number 3, Part B, Section III.G.5.) I. G. 5. ) COLORADO Air Pollution Control Division ©ettdwrxer4 d Relic k.a3La @ W-mvemnmene Page 1 of 11 EMISSION LIMI Month FT Facility Equipment ID AIRS Point Pounds per Month Emission Type 5O2 NOx VOC CO DEHY-1 015 --- --- 238 - Point (Note: Monthly limits are based on a 31 -day month.) Annual Limits: Facility Equipment 1D AIRS Point Tons per Year Emission Type PM2.5 NOx VOC CO DEHY-1 015 --- --- 1.4 --- Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 9.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 24.0 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 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. 2. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility potential emission limitations as indicated below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. (Reference: Regulation 3, Part C. II.E.) Total potential emissions from the facility, including all permitted emissions and potential to emit from all insignificant activities, shalt be less than: • 250 tons per year of VOC; and • 10 tons per year of any individual hazardous air pollutant (HAP); and • 25 tons per year of total hazardous air pollutants (HAP). COLORADO Air Pollution Control Division ,ncumx,lVttbli: n EtnhorvrK4u Page 2 of 11 3. Complipermit shall be demonstrated by running the VMG Sim, o anot.ier : r ` ion :eve m del a monthly basis using the most recent extended wet ^ .ly or: rati values, including: gas throughput, lean glycol recirculation rate, chiller temperature and pressure, condenser temperature, flash tank temperature and pressure, wet gas inlet temperature, and wet gas inlet pressure. Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into the model and be provided to the Division upon request. 4. The owner or operator shall operate and maintain the emission points in the table below with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. The owner or operator shall operate this dehydration unit so as to prevent any emissions directly to the atmosphere. (Regulation Number 3, Part B, Section I I I. E. ) Facility Equipment ID AIRS Point Control Device Pollutants Controlled i DENY -1 015 Still Vent- Primary: Enclosed Combustor Secondary: Point 013 (FLR-1A) VOC and HAP 5. The owner or operator shall operate and maintain the emission points in the table below as a closed loop system and shall recycle 100% of emissions as described in the table below. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Emissions Recycling Description Pollutants Recovered DENY -1 015 Flash Tank- Primary: Recycled to plant's inlet slug catcher Secondary: Point 013 (FLR-1A) VOC and HAP PROCESS LIMITATIONS AND RECORDS 6. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 days) DEHY-1 015 Natural Gas Throughput 12,775 MMscf/yr 1085 MMscf/month The owner or operator shall monitor monthly process rate based on the calendar month. The volume of gas processed shall be measured by gas meter or by assuming the maximum design rate of the dehydrator unit of 35.0 MMscf/d. Compliance with the annual throughput limits shalt 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. For purposes of demonstrating compliance with annual emissions limits during the first 12 months of this permit, permit holder shall calculate emissions for periods preceding issuance of this permit using VMG Sim. COLORADO .Air Pollution Control Division. Page 3 of 11 7. This u i sha, b-, li ed tie m i um l n glycol circulation rate of 6.0 gallons per minute. The le gly� �l c .ula, + .te a l be i corded daily in a log maintained on site and made avail ctio on request. Glycol recirculation rate shall be monitored by one of the following methods: assuming maximum design pump rate, using glycol flow meter(s), or recording strokes per minute and converting to circulation rate. This maximum glycol circulation rate shall not preclude compliance with the optimal glycol circulation rate, if applicable, (Lops) provisions under MACT HH, whichever is more stringent. (Reference: Regulation Number 3, Part B, II.A.4) 8. On a weekly basis, the owner or operator shall monitor and record operational values including: chiller temperature and pressure, flash tank temperature and pressure, wet gas inlet temperature and pressure. These records shall be maintained for a period of five years. 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 1II.E.) (State only enforceable) 10. 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 Number 1, Section II.A.5.) 11. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 12. The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2 General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. The combustion device 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. 13. The glycol dehydration unit covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.D.3. Beginning May 1, 2015, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas - processing plant subject to control requirements pursuant to Section XVII.D.4., shall reduce uncontrolled actual emissions of hydrocarbons by at least 95% on a rolling twelve-month basis through the use of a condenser and/or air pollution control equipment. 14. The glycol dehydration unit at this facility is subject to National Emissions Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities, Subpart HH. This facility shall be subject to applicable major source provisions of this regulation, as stated in 40 C.F.R Part 63, Subpart A and HH. (Regulation Number 8, Part E, Subpart A and HH) COLORADO Air Pollution Control Division l+wm7ryerA �a PubFE[<av,nmcnt Page 4 of 11 A "1-1 GTE MACT HH-iplic..., Requir en . Major Source arge D drators - Controlled with Flare §63.762 - Startups, Shutdowns, and Malfunctions §63.762 - The provisions set forth in this subpart shall apply at all times. §63.764 - General Standards §63.764(c)(1) - For each glycol dehydration unit process vent subject to this subpart, the owner or operator shall comply with the requirements specified in paragraphs (c)(1)(i) through (iii) of this section. 563.764(c)(1)(i) - The owner or operator shall comply with the control requirements for glycol dehydration unit process vents specified in 563.765 $63.764(c)(1)(ii) - The owner or operator shall comply with the monitoring requirements specified in §63.773 563.764(c)(1)(iii) - The owner or operator shall comply with the recordkeeping and reporting requirements specified in §63.774 and 563.775 §63.764(j) - At all times the owner or operator must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions, Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source. §63.765 - Glycol Dehydration Unit Process Vent Standards §63.765(b)(1) - For each glycol dehydration unit process vent, the owner or operator shalt control air emissions by paragraph (b)(1)(ii) of this section. $63.765(b)(1)(ii) - The owner or operator of a large glycol dehydration unit shall connect the process vent to a control device or combination of control devices through a closed -vent system and the outlet benzene emissions from the control device(s) shall be reduced to a level less than 0.90 megagrams per year as determined pursuant to the method specified in §63.772(b)(2)(i). The closed -vent system shalt be designed and operated in accordance with the requirements of § 63.771(c). The control device(s) shall be designed and operated in accordance with the requirements of 5 63.771(d), except that the performance levels specified in S 63.771(d)(1)(i) and (ii) do not apply. §63.765(b)(2) - One or more safety devices that vent directly to the atmosphere may be used on the air emission control equipment installed to comply with paragraphs (b)(1) of this section. §63.771 - Control Equipment Requirements §63.771(a) - This section applies to each cover, closed -vent system, and control device installed and operated by the owner or operator to control air emissions as required by the provisions of this subpart. Compliance with paragraph (c) of this section will be determined by review of records required by §63.774 and the reports required by §63.775, by review of performance test results, and by inspections. $63.771(c) - Closed -vent system requirements. All gases, vapors, and fumes emitted must be routed via a CVS to a control device complying with the relevant provisions of §63.771(d). The CVS shall be designed and operated with no detectable emissions. §63.771(d)(4)(i) - The control device used to comply with this subpart shall be operating at all times when gases, vapors, and fumes from the HAP emissions unit are vented to it. §63.772 - Test Methods, Compliance Procedures and Compliance Demonstration §63.772(b) - Determination of glycol dehydration unit flowrate, benzene emissions, or BTEX emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate, benzene emissions, or BTEX emissions. §63.772(b)(2)(i)- The owner or operator shall determine actual average Page 5 of 11 s using the model GRI-GLYCaIc TM, Version 3.0 or cedu .•s presented in the associated GRI- €c ical r rence Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI.95/0368.1); 563.773(c) - Cover and closed -vent system Inspection and monitoring requirements. 63.773(c)(1) - For each closed -vent system or cover required to comply with this section, the owner or operator shall comply with the requirements of paragraphs (c) (2) through (7) of this section. 563.773(c)(2) - Except as provided in paragraphs (c)(5) and (6) of this section, each closed -vent system shall be inspected according to the procedures and schedule specified in paragraphs (c)(2)(i) and (ii) of this section, each cover shall be inspected according to the procedures and schedule specified in paragraph (c)(2)(iii) of this section, and each bypass device shall be inspected according to the procedures of paragraph (c)(2)(iv) of this section. 563.773(c)(3) - In the event that a leak or defect is detected, the owner or operator shall repair the leak or defect as soon as practicable, except as provided in paragraph (c)(4) of this section. §63.773(c)(4) - Delay of repair of a closed -vent system or cover for which leaks or defects have been detected is allowed if the repair is technically infeasible without a shutdown, as defined in §63.761, or if the owner or operator determines that emissions resulting from immediate repair would be greater than the fugitive emissions likely to result from delay of repair. Repair of such equipment shall be complete by the end of the next shutdown. 563.773(c)(5) - Any parts of the closed -vent system or cover that are designated, as described in paragraphs (c)(5)(i) and (ii) of this section, as unsafe to inspect are exempt from the inspection requirements of paragraphs (c)(2)(i), (ii), and (iii) of this section if: 563.773(c)(5)(i) - The owner or operator determines that the equipment is unsafe to inspect because inspecting personnel would be exposed to an imminent or potential danger as a consequence of complying with paragraphs (c)(2)(i), (ii), or (iii) of this section; and §63.773(c)(5)(ii) - The owner or operator has a written plan that requires inspection of the equipment as frequently as practicable during safe -to - inspect times §63.773(c)(6) - Any parts of the closed -vent system or cover that are designated, as described in paragraphs (c)(6)(i) and (ii) of this section, as difficult to inspect are exempt from the inspection requirements of paragraphs (c)(2)(i), (ii), and (iii) of this section if: 563.773(c)(6)(i) - The owner or operator determines that the equipment cannot be inspected without elevating the inspecting personnel more than 2 meters above a support surface; and §63.773(c)(6)(ii) - The owner or operator has a written plan that requires inspection of the equipment at least once every 5 years. §63.773(c)(7) - Records shall be maintained as specified in 563.774(b)(5) through (8) 563.773(d)(1) - The owner or operator shall comply with the requirements specified in this subpart including but not limited to: $63.773(d)(1)(ii) - A site -specific monitoring plan must be prepared that addresses the monitoring system design, data collection, and the quality assurance and quality control elements outlined in paragraph (d) of this section and in 563.8(d), Each CPMS must be installed, calibrated, operated, and maintained in accordance with the procedures in your approved site - §63.773 - Inspection and Monitoring Requirements OLORADO r Palllitzun Cootiol DIV111771 Page 6 of 11 tz'tri 563.774 - Recordkeeping Requirements §63.774(b) - Except as specified in paragraphs (c), (d), and (f) of this section, each owner or operator of a facility subject to this subpart shall maintain the records specified in paragraphs (b)(1) through (11) of this section §63.774(c)(1) through (3) - maintain records to document the method used to achieve compliance, the method used for demonstrating compliance, and any information needed to demonstrate the same. 563.774(g) - Maintain records of the occurrence and duration of each malfunction of operation (i.e., process equipment) or the air pollution control equipment and monitoring equipment, maintain records of actions taken during periods of malfunctions to minimize emissions in accordance with §63.764(j). 563.775 - Reporting Requirements §63.775(a) - Comply with the reporting provisions in 40 CFR Part 63, Subpart A, as applicable in Table 2 of MACT Subpart HH. §63.775(b) - Each owner or operator of a major source subject to this subpart shall submit the information listed in paragraphs §63.775(b)(1) through 563.775(b)(6), except as provided in paragraphs §63.775(b)(7) and §63.775(b)(8). OPERATING a MAINTENANCE REQUIREMENTS 15. The owner or operator shall follow the most recent operating and maintenance (OftM) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the 0aM plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Periodic Testing Requirements 16. The owner or operator shall complete an extended wet gas analysis prior to the inlet of the dehydration unit on an annual basis per calendar year. Results of the wet gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit and be provided to the Division upon request. ADDITIONAL REQUIREMENTS 17. All previous versions of this permit are cancelled upon issuance of this permit. 18. 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 Page 7 of 11 the emissions ncrease 6y 50% or we (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. 19. This source is subject to the provisions of Regulation Number 3, Part C, Operating Permits (Title V of the 1990 Federal Clean Air Act Amendments). The provisions of this construction permit must be incorporated into the Operating Permit. The application for the modification to the Operating Permit is due within one year of the issuance of this permit. GENERAL TERMS AND CONDITIONS 20. 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. 21. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 22. 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. 23. 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. 24. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. COLORADO Air Pollution Cnntml niv9.si®n, pettoicl F'abkoCr.vorin ela Page 8 of 11 25. Sectio 25 1 7 (a), '.S. sires hat all sources required to file an Air Pollution Emissi n a ual fee to cover the costs of inspections and admit n. t or is t discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 26. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 October 8, 2014 Issued to Whiting Oil and Gas Corporation Issuance 2 May 16, 2016 Issued to Whiting Oil and Gas Corporation Modification to reflect replacement of thermal oxidizer with LEED enclosed combustor. No change in process/emission limits. Facility is Major for Title V applicability. Issuance 3 This Issuance Issued to modify process/emission limits and incorporate MACT HI -I language. Facility is Major for Title V applicability. COLORADO Air Pollution Control Division Page 9 of 11 Notes to Perm • -r - -""- tim this it hs ance: 1) The per : ier ' - r_' t. s fo e 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.coiorado.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. Facility Equipment ID AIRS Point Pollutant CAS # Uncontrolled Emissions (tpY) Controlled Emissions (tPy) DEHY-1 015 Benzene 71432 2,2E+00 1.1E-01 Toluene 108883 7,6E-02 3.7E-03 Ethylbenzene 100414 4.4E-03 2.2E-04 Xylenes 1330207 4.9E-01 2.4E-02 n -Hexane 110543 1.3E-03 0.0E+00 2,2,4- Trimethylpentane 540841 0.0E+00 0.0E+00 Methanol 67561 2.48E+01 1.24E+00 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 0.125 tons per year (tpy) 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 information provided in the application and the VMG Sim model. Controlled emissions from the still vent are based on an enclosed combustor control efficiency of 95.0%. Flash tank emissions are routed to the plant's inlet slug catcher or to FLR-1 A as backup and are therefore subject to 100% and 95% control, respectively. 6) In accordance with C.R.S. 75-7.114,1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the glycol dehydration unit and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(B) when applicable. COLORADO Air Pollution Control Division ;. *CEru`l.E w Pu66: ih2itith Page 10 of 11 8) This facilifel: Requirement Status Operating Permit Major Source of: VOC Area Source of: HAPsi PSD or NANSR Synthetic Minor Source of: VOC MACT HH a DDDDD Major Source Requirements: Applicable iThe facility was previously a Major Source of HAPs, but is now an Area Source of HAPs. 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal. Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ- Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX COLORADO Air %illation Contra' Divizian Page 11 of 11 Permit number: Date issued: Issued to: COLORADO Air Pollution Control Division Department of Public Health & Environment CONSTRUCTION PERMIT 13WE3006 Issuance: 3 DRAFT Whiting Oil and Gas Corporation Facility Name: Plant AIRS ID: Physical Location: County: General Description: Redtail Gas Plant 123/9AD0 NE1/4 SEC 21 T10N R58W Weld County Natural Gas Processing Plant Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description DENY -2 016 One (1) Ethylene Glycol. (EG), natural gas dehydration unit (Alco, serial number: 2013- 8482-12) with a design capacity of 70.0 MMscf per day. This emissions unit is equipped with two (2) Bear CX-5H Duplex electric -glycol pumps with a design capacity of 18 gal/min. This unit is equipped with a flash tank, reboiier and still vent. Emissions from the still vent are routed to an air-cooled condenser and then to an enclosed combustor. Emissions from the flash tank are routed /recycled to plant's inlet slug catcher. Emissions from the still vent and flash tank can be routed as a backup control to the plant flare, point 013 (FLR-1 A). This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C. R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. This construction permit represents final permit approval and authority to operate this emissions source. Therefore, it is not necessary to self -certify. (Regulation Number 3, Part B, Section III.G.5.) COLORADO Air Pollution Control Division Duu trurwof molt Page 1 of 12 EMISSION LIMITATIONS AND RECORDS ,i onth[y Limits:' Facility Equipment ID AIRS Point Pouhds"per Month Emission Type SO2 NOx VOC CO DEHY-2 016 --- •-- 170 --- Point (Note: Monthly limits are based on a 31 -day month.) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO„ VOC CO DEHY-2 016 --- --- 1.0 --- 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 9.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 24.0 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 criteria and hazardous air pollutants, shall be determined using VMG Sim or other Division -approved model 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. For purposes of demonstrating compliance with annual emissions limits during the first 12 months of this permit, permit holder shall calculate emissions for periods preceding issuance of this permit using VMG Sim. 2. The owner or operator shalt track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility potential emission limitations as indicated below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. (Reference: Regulation 3, Part C. II.E.) Total potential emissions from the facility, including all permitted emissions and potential to emit from all insignificant activities, shall be less than: • 250 tons per year of VOC; and • 10 tons per year of any individual hazardous air pollutant (HAP); and • 25 tons per year of total hazardous air pollutants (HAP). COLORADO Air Patin+ir rt Control Division Dv rtme_ ..t 1 ieeirt^.8 Environment Page 2 of 12 3. Compliance with„the emission. limits in. this permit shall be demonstrated by running the VMG Sim, or other.`bivisian-approved.madel; ania monthly basis using the most recent extended wet as analysis ai d recorded`operati❑nal values, including: gas throughput, lean glycol recirculation rate, ,chiller_temperature and Pressure, condenser temperature, flash tank temperature and pressure, let gas inlet temperature; aid wet gas`"inlct pressure. Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into the model and be provided to the Division upon request. 4. The owner or operator shall operate and maintain the emission points in the table below with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. The owner or operator shalt operate this dehydration unit so as to prevent any non -fugitive emissions directly to the atmosphere. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled DENY -2 016 Still Vent: Primary: Enclosed Combustor Secondary: Point 013 (FLR-1A) VOC and HAP 5. The owner or operator shall operate and maintain the emission points in the table below as a closed loop system and shall recycle 100% of emissions as described in the table below. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Emissions Recycling Description Pollutants Recovered DEHY-2 016 Flash Tank: Primary: Recycled to plant's inlet slug catcher Secondary: Point 013 (FLR-1A) VOC and HAP PROCESS LIMITATIONS AND RECORDS 6. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 days) DENY -2 016 Natural Gas Throughput 25,550 MMscf/yr 2170 MMscf/month The owner or operator sha i monitor monthly process rates based on the calendar month. The volume of gas processed shall be measured by gas meter or by assuming the maximum design rate of the dehydrator unit of 70.0 MMscf/d. 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. 7. This unit shall be limited to the maximum lean glycol circulation rate of 9.0 gallons per minute. The lean glycol recirculation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. Glycol recirculation rate shall be monitored by one of the following methods: assuming maximum design pump rate, using glycol flow COLORADO Air Pail ,rian Control Division Dpi or Vu6kc PEE:4th U ii<rvvunrhtu Page 3 of 12 � titt c-neterl , or recording strdkei per rniii.and cOpverting to circulation rate. This maximum .glycol ciiculati ii.,rate Ccies .not precl4cle compliance with the optimal. glycol circulation rate (Lgpt) provisions under MA;CT HEI,, whichever is more:stringent. (Reference: Regulation Number • 3, Part U, il_A.4) 8. On a weekly basis, the owner or operator shall monitor and record operational values including: chiller temperature and pressure, flash tank temperature and pressure, wet gas inlet temperature and pressure. These records shall be maintained for a period of five years. 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. 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 Number 1, Section II.A.5.) 11. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 12. The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2 General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. The combustion device 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. 13. The glycol dehydration unit covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XV1I.D.3. Beginning May 1, 2015, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas -processing plant subject to control requirements pursuant to Section XVII.D.4., shall reduce uncontrolled actual emissions of hydrocarbons by at least 95% on a rolling twelve-month basis through the use of a condenser and/or air pollution control equipment. 14. The glycol dehydration unit at this facility is subject to National Emissions Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities, Subpart HH. This facility shall be subject to applicable major source provisions of this regulation, as stated in 40 C.F.R Part 63, Subpart A and HH. (Regulation Number 8, Part E, Subpart A and HH) Page 4 of 12 MALT HH Applicable Requirements' gajor Source Large Dehydrators - Controlled with Flare 563.762 - Startups, . Shutdowns, and Malfunctions 563.762 - The provisions set Forth _ in this subpart shall apply at all times. 563.764 - General Standards §63.764(c)(1) - For each glycol dehydration unit process vent subject to this subpart, the owner or operator shall comply with the requirements specified in paragraphs (c)(1)(i) through (iii) of this section. 563.764(c)(1)(i) - The owner or operator shall comply with the control requirements for glycol dehydration unit process vents specified in 563.765 563.764(c)(1)(ii) - The owner or operator shall comply with the monitoring requirements specified in 563.773 563.764(c)(1)(iii) - The owner or operator shall comply with the recordkeeping and reporting requirements specified in 563.774 and 563.775 563.764(j) - At all times the owner or operator must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source. 563.765 - Glycol Dehydration Unit Process Vent Standards 563.765(b)(1) - For each glycol dehydration unit process vent, the owner or operator shall control air emissions by paragraph (b)(1)(ii) of this section. 563.765(b)(1)(ii) - The owner or operator of a large glycol. dehydration unit shall connect the process vent to a control device or combination of control devices through a closed -vent system and the outlet benzene emissions from the control device(s) shall be reduced to a level less than 0.90 megagrams per year as determined pursuant to the method specified in 563.772(b)(2)(i). The closed -vent system shall be designed and operated in accordance with the requirements of 5 63.771(c). The control device(s) shall be designed and operated in accordance with the requirements of 5 63.771(d), except that the performance levels specified in S 63.771(d)(1)(i) and (ii) do not apply. 563.765(b)(2) - One or more safety devices that vent directly to the atmosphere may be used on the air emission control equipment installed to comply with paragraphs (b)(1) of this section. 563.771 - Control Equipment Requirements 563.771(a) - This section applies to each cover, closed -vent system, and control device installed and operated by the owner or operator to control air emissions as required by the provisions of this subpart. Compliance with paragraph (c) of this section will be determined by review of records required by 563.774 and the reports required by 563.775, by review of performance test results, and by inspections. 563.771(c) - Closed -vent system requirements. All gases, vapors, and fumes emitted must be routed via a CVS to a control device complying with the relevant provisions of 563.771(d). The CVS shall be designed and operated with no detectable emissions. 563.771(d)(4)(i) - The control device used to comply with this subpart shall be operating at all times when gases, vapors, and fumes from the HAP emissions unit are vented to it. COLORADO Air Pollution Control Division b,.`Por?eneMOr PuhA.r1kKh ., E-�artaiu nt Page 5 of 12 563.772-- Test Methods, Compliance Procedures and Compliance Demonstration 563.712(hj,- DeterMination of glycol dehydration unit flowrate, benzene emisswn5. dr BTLX+bi,iissions. T procedures of this paragraph shall be used by at'owrker,or ope ato'r to determine glycol dehydration unit natural gas flowjate, benzene: missions, or BTEX emissions. 563.772(b)(3)(i)4 The owner or °Aerator shall determine actual average benzene or BTEX emissions using the model GRI-GLYCaic TM, Version 3.0 or higher, and the procedures presented in the associated GRI- GLYCaIc TM Technical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research Institute (GRl) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI-95/0368.1); io n Page 6 of 12 563.773(c - Cover. and closed -vent system inspection and monitoring requiremelryts. , 63.773(c)(1) - For each closed -vent system or cover required to comply with '..this ;section, the owner or operator shall comply with the requirements of - paragraphs .(c) (2) thrbugh (71 of this section. §63.773(c)(2) - Except as provided in paragraphs (c)(5) and (6) of this section, each closed -vent system shall be inspected according to the procedures and schedule specified in paragraphs (c)(2)(i) and (ii) of this section, each cover shall be inspected according to the procedures and schedule specified in paragraph (c)(2)(iii) of this section, and each bypass device shall be inspected according to the procedures of paragraph (c)(2)(iv) of this section. §63.773(c)(3) - In the event that a leak or defect is detected, the owner or operator shall repair the leak or defect as soon as practicable, except as provided in paragraph (c)(4) of this section. §63.773(c)(4) - Delay of repair of a closed -vent system or cover for which leaks or defects have been detected is allowed if the repair is technically infeasible without a shutdown, as defined in §63.761, or if the owner or operator determines that emissions resulting from immediate repair would be greater than the fugitive emissions likely to result from delay of repair. Repair of such equipment shall be complete by the end of the next shutdown. §63.773(c)(5) - Any parts of the closed -vent system or cover that are designated, as described in paragraphs (c)(5)(i) and (ii) of this section, as unsafe to inspect are exempt from the inspection requirements of paragraphs (c)(2)(i), (ii), and (iii) of this section if: §63.773 - Inspection §63.773(c)(5)(i) - The owner or operator determines that the equipment is and Monitoring unsafe to inspect because inspecting personnel would be exposed to an Requirements imminent or potential danger as a consequence of complying with paragraphs (c)(2)(i), (ii), or (iii) of this section; and §63.773(c)(5)(ii) - The owner or operator has a written plan that requires inspection of the equipment as frequently as practicable during safe -to - inspect times §63.773(c)(6) - Any parts of the closed -vent system or cover that are designated, as described in paragraphs (c)(6)(i) and (ii) of this section, as difficult to inspect are exempt from the inspection requirements of paragraphs (c)(2)(i), (ii), and (iii) of this section if: §63.773(c)(6)(i) - The owner or operator determines that the equipment cannot be inspected without elevating the inspecting personnel more than 2 meters above a support surface; and §63.773(c)(6)(ii) - The owner or operator has a written plan that requires inspection of the equipment at least once every 5 years. 563.773(c)(7) - Records shall be maintained as specified in §63.774(b)(5) through (8) §63.773(d)(1) - The owner or operator shall comply with the requirements specified in this subpart including but not limited to: $63.773(d)(1)(ii) - A site -specific monitoring plan must be prepared that addresses the monitoring system design, data collection, and the quality assurance and quality control elements outlined in paragraph (d) of this section and in §63.8(d). Each CPMS must be installed, calibrated, operated, and maintained in accordance with the procedures in your approved site - specific monitoring plan. COLORADO .fix Pollution Control Division Ucpt.t,trou,t a+ pobk. &Lritc rl,a- rsE Page 7 of 12 $63.7"74 -• -. 5,63774(1)- Except a .:ppecifiettan paragraphs (c), (d), and (f) of this section, each o rneror operatorof a facility subject to this subpart shall maintain the records speiified in paragraphs::(b)(1) through (11) of this section ',563:774(c)(i) thrargh (3) - maintain records to document the method used -ta kiiievetarn`p(farrffe, the rrnetlhdd used for demonstrating compliance, and Recordkeeping any information needed to demonstrate the same. Requirements 563.774(g) - Maintain records of the occurrence and duration of each malfunction of operation (i.e., process equipment) or the air pollution control equipment and monitoring equipment, maintain records of actions taken during periods of malfunctions to minimize emissions in accordance with 563.76A(j). 563.775(a) - Comply with the reporting provisions in 40 CFR Part 63, Subpart A, as applicable in Table 2 of MACT Subpart HH. 563.775 - Reporting §63.775(b) - Each owner or operator of a major source subject to this subpart Requirements shall submit the information listed in paragraphs 563.775(b)(1) through 563.775(b)(6), except as provided in paragraphs $63.775(b)(7) and 563.775(b)(8). OPERATING Et MAINTENANCE REQUIREMENTS 15. 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 Periodic Testing Requirements 16. The owner or operator shall complete an extended wet gas analysis prior to the inlet of the dehydration unit on an annual basis per calendar year. Results of the wet gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit and be provided to the Division upon request. ADDITIONAL REQUIREMENTS 17. All previous versions of this permit are cancelled upon issuance of this permit. 18. 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. COLORADO Air Paint ion Cox,t of Division Page 8 of 12 • Whenever, there is A change in the bwner ci operator of any facility, process, or activity; Or • • Whenever new control equipment is instatted, 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. 19. This source is subject to the provisions of Regulation Number 3, Part C, Operating Permits (Title V of the 1990 Federal Clean Air Act Amendments). The provisions of this construction permit must be incorporated into the Operating Permit. The application for the modification to the Operating Permit is due within one year of the issuance of this permit. GENERAL TERMS AND CONDITIONS 20. 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 11.8. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 21. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 22. 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. 23. 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. 24. 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. 25. 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. COLORADO Air Pollution Control Division Page 9 of 12 26. Violation, of the teems of a.. peir(nit or of,tfie orovisibns of the Colorado Air Pollution Prevention and Control Act or the re ulations of l:he. AQCC mby result in administrative, civil or criminal enforcement.;actipns under Sections. 25-7.115 (enforcement), -121 (injunctions), -122 (civil penalties), 12.1 (criminal peratiesj C.R.S. _ By: Timothy Sharp Permit Engineer P Issuance Date Description Issuance 1 October 8, 2014 Issued to Whiting Oil and Gas Corporation Issuance 2 May 16, 2016 Issued to Whiting Oil and Gas Corporation Modification to reflect replacement of thermal oxidizer with LEED enclosed combustor. No change in process/emission limits. Facility is Major for Title V applicability. Issuance 3 This Issuance Issued to modify process/emission limits and incorporate MACT HH language. Facility is Major for Title V applicability. COLORADO Air Poant.a n Contxesi Division %pper%r=u.rnt or Fuhr^. 83crth&t- arorunena Page 10 of 12 Notes to Permit Holder at.the time ofthis perniit.i suance:i 1) The permit holder is required to pay' fees for tl're processing time for this permit. An invoice for these fees will beissued 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. Facility Equipment ID AIRS Point Pollutant CAS # Uncontrolled Emissions (WY) Controlled Emissions (tPY) DEHY-2 016 Benzene 71432 3,9E+00 1.9E-01 Toluene 108883 1.4E-01 7.0E-03 Ethyibenzene 100414 8,8E-03 4.4E-04 Xylenes 1330207 8.4E-01 4.2E-02 n -Hexane 110543 8,8E-03 2.2E-04 2,2,4- Trimethylpentane 540841 0.0E+00 0.0E+00 Methanol 67561 9.7E+00 4.8E-01 Note: All non-criter'a reportable pollutants in the table above with uncontrolled emission rates above 0.125 tons per year (tpy) 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 information provided in the application and the VMG Sim model. Controlled emissions from the still vent are based on an enclosed combustor control efficiency of 95.0%. Flash tank emissions are routed to the plant's inlet slug catcher or to FLR-1A as backup and are therefore subject to 100% and 95% control, respectively. 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. Page 11 of 12 I i I r • � 7) Thit permit fulfills the requirement to holdl_a valid permit reflecting the glycol dehydration unit and associated ontrpl device per- the :Colorado Oil and Gas Conservation Commission rule 805b(2)(B) when applic ble. 8) This facility is classified as follows _ Applicable Requirement Status Operating Permit Major Source of: V0C Area Source of: HAPs1 PSD or NANSR Synthetic Minor Source of: V0C MACT HH EtDDDDD Major Source Requirements: Applicable 'The facility was previously a Major Source of HAPs, but is now an Area Source of HAPs. 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ- Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX COLORADO Air Pollution Control Division ik pont.nenr x Putac Haan ;s F„n,vvar elo Page 12 of 12 STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 CONSTRUCTION PERMIT PERMIT NO: 13WE3007 Issuance 2 DATE ISSUED: DRAFT ISSUED TO: Whiting Oil and Gas Corporation THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Redtail Gas Plant, located in the NE '/ of Section 21, Township 10N, Range 58W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Pont Description AMINE -1 017 Ucarsol 814 — DOW solvent, modeled as Methyldiethanolamine (MDEA)/Piperazine natural gas sweetening system for acid gas removal with a design capacity of 45 MMSCF per day (Alto, serial number: 2007-7722-02). This emissions unit is equipped with two (2) FMC M1630 -DX, electric amine recirculation pumps with a total design capacity of 201 gallons per minute. This system includes a natural gas/amine contactor, a flash tank, and an oil -heated amine regeneration reboiler. The oil heater forthe reboiler is covered under a separate point (AIRS Point 014). Flash tank emissions are recycled to the plant's inlet slug catcher. The still vent stream is controlled by a thermal oxidizer (TCE, , serial number: 13042). Emissions from the still vent and the flash tank can be routed as a backup control to the plant flare, FLR-1A. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. This construction permit represents final permit approval and authority to operate this emissions source. Therefore, it is not necessary to self -certify. (Regulation 3, Part B, Section III.G.5). AIRS ID: 123/9AD0 Page 1 of 8 Amine SM/M Version 2012-1 Colorado Department of Public Health and Environment Air Pollution Control Division EMISSION LIMITATIONS AND RECORDS 2, Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II,A.4) Monthly Limits: Facility Equipment ID AIRS Point Pounds per Month Emission Type Point SO2 NOx VOC CO AMINE -1 017 4,298 85 1,699 357 (Note: Monthly limits are based on a 31 -day month.) The owner or operator shall calculate monthly emissions based on the calendar month. Facility -wide emissions of each individual hazardous air pollutant shall be less than 1,359 lb/month. Facility -wide emissions of total hazardous air pollutants shall be less than 3,398 lb/month. Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type SO2 NOx VOC CO AMINE -1 017 25.3 0.5 10.0 2.1 Point 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 be less than 9.0 tpy. Facility -wide emissions of total hazardous air pollutants shall be less than 24.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 3. 100% of emissions that result from the flash tank associated with this amine unit shall be recycled to the plant inlet. Emisisons from the flash tank can be routed as a backup control to the plant flare(point 013: FLR-1 A). 4. This concentration of Ucarsol AP -814 solvent in the lean amine stream shall not exceed 55% by weight on a monthly average basis. The operator shall measure and record the solvent concentration in the lean amine stream each week and calculate and record a calendar monthly average solvent concentration to demonstrate compliance with this condition. AIRS ID: 123/9ADO Page 2 of 8 Colorado Department of Public Health and Environment Air Pollution Control Division 5. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled Amine -1 017 Primary: Thermal Oxidizer Secondary: Point 013 (FLR-1A) VOC and HAPs PROCESS LIMITATIONS AND RECORDS 6. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual natural gas processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment AIRS Point Process Parameter Annual Limit Monthly Limit (31 Y) AMINE -1 017 Natural gas throughput 16,425 MMscf/yr 1,395MMscf1 month The owner or operator shall calculate monthly process rates based on the calendar month. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 7. This unit shall be limited to the maximum lean amine recirculation pump rate of 201 gallons per minute. The lean amine recirculation rate shall be recorded weekly in a log maintained on site and made available to the Division for inspection upon request. A pump stroke correlation may be used to demonstrate compliance with this condition. (Reference: Regulation No. 3, Part B, II.A.4) STATE AND FEDERAL REGULATORY REQUIREMENTS 8. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 9. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any AIRS ID: 123/9ADO Page 3 of 8 Colorado Department of Public Health and Environment Air Pollution Control Division sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) 10. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 11 The amine unit addressed by AIRS point ID 017 is subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart OOOO, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution including, but not limited to, the following: • §60.5365 — Applicability and Designation of Affected Facilities o §60.5365(g)(3) - Facilities that have a design capacity less than 2 long tons per day (LT/D) of hydrogen sulfide (H2S) in the acid gas (expressed as sulfur) are required to comply with recordkeeping and reporting requirements specified in §60.5423(c) but are not required to comply with §§60.5405 through 60.5407 and §§60.5410(g) and 60.5415(g). • §60.5423 — Record keeping and reporting Requirements o §60.5423(c) - To certify that a facility is exempt from the control requirements of these standards, for each facility with a design capacity less that 2 LT/D of H2 S in the acid gas (expressed as sulfur) you must keep, for the life of the facility, an analysis demonstrating that the facility's design capacity is less than 2 LT/D of H2 S expressed as sulfur. OPERATING & MAINTENANCE REQUIREMENTS 12. The owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Periodic Testinq Requirements 13. The operator shall sample the inlet gas to the plant on an annual basis per calendar year to determine the concentration of hydrogen sulfide (H2S) in the gas stream. The sample results shall be monitored to demonstrate that this amine unit qualifies for the exemption from the Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution (§60.5365(g)(3)). ADDITIONAL REQUIREMENTS 14. A revised Air Pollutant Emission Notice (APEN) shall he filed. (Reference: Regulation No. 3, Part A, II.C) • Annually by April 301h 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 AIRS ID: 123/9AD0 Page 4 of 8 Colorado Department of Public Health and Environment Air Pollution Control Division 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. 15 Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS 16. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 17. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of ail 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. 18. 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. 19. 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. AIRS ID: 123/9AD0 Page 5 of 8 Colorado Department of Public Health and Environment Air Pollution Control Division 20. 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. 21. 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. 22. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer Permit Histo Issuance Date Description Issuance 1 October 8, 2014 Issued to Whiting Oil and Gas Corporation Issuance 2 This Issuance Modification to permit limits. AIRS 1D: 123/9AD0 Page 6 of 8 Colorado Department of Public Health and Environment Air Pollution Control Division Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation'of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the 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: http !/vo .coibrado.gov/csJSatellite' c=document C&childpatlenarne=CDPHE- Main°/02FDocument C%2FCBONAddLinkView&cid=1251599389641&�pagename-CBONWer 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emission Rate (Ib/yr) Are the emissions reportable? Controlled Emission Rate (Ib/yr) 017 Benzene 71432 27,207 YES 1,344 Toluene 108883 9,497 YES 469 n -Hexane 110543 2,322 YES 49 Xylene 1330207 1,390 YES 69 Ethylbenzene 100414 705 YES 35 Methanol 67561 162,568 YES 8,121 5) The emission levels contained in this permit are based on the following emission factors: CAS # Pollutant Emission Factors Uncontrolled Flash Gas Stream Ib/MMscf Natural Gas Throughput Emission Factors Uncontrolled Vent Gas Stream Ib/MMscf Natural Gas Throughput Emission Factors Controlled Vent Gas Stream Ib/MMscf Natural Gas Throughput Source VOC 14.858 24.2133 1.21 Simulation 110543 n -Hexane 0.082 0.0597 0.003 Simulation 71432 Benzene 0.02 1.636 0.0818 Simulation 108883 Toluene 0.008 0.571 0.0285 Simulation 1330207 Xylene 0.001 0.083 0.0042 Simulation 100414 Ethylbenzene 0.0005 0.042 0.0021 Simulation 67561 Methanol 0.01 9.888 0.4944 Simulation AIRS ID: 123/9AD0 Page 7 of 8 Colorado Department of Public Health and Environment Air Pollution Control Division Note: The controlled emissions factors are based on the thermal oxidizer control efficiency of 95% for the still vent stream. Flash tank emissions are routed to the plant's inlet slug catcher or to FLR-1 A as backup and are therefore subject to 100% and 95% control, respectively. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Requirement Status Operating Permit _ Major Source of: VOC Area Source of: HAPs1 PSD Synthetic Minor Source of: VOC NSPS LLL Not Applicable MACT HH Major Source Applicable 'The facility was previously a Major Source of HAPs, but is now an Area Source of HAPs. 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 DOD 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 AIRS ID: 123/9AD0 Page 8 of 8 General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD) website at www.colorado.gov/pacific/cdphe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 13WE3Q03 AIRS ID Number: 123 / 9AD0 r 013 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: Whiting Oil and Gas Corporation Site Name: Redtail Gas Plant Site Location: NE 1/4, Section 21, T10N, R58W Mailing Address: (Inc fuck Zip Ode) 1700 Broadway, Suite 2300 Portable Source Home Base: Denver, CO 80290 Site Location County: Weld NAICS or SIC Code: 1321 Permit Contact: Chenine Wozniak Phone Number: 303-802-8369 E -Mail Address: CDPHECorrespondence@whiling.com 1 Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2Permits, exmption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-200 - General APEN - Revision 7/2015 351970 1 l EV COLORADO Permit Number: 13WE3003 AIRS ID Number: 123 / 9ADo/ 013 [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit r❑ Change permit Limit ❑ Transfer of ownership3 ❑ Other (describe below) - OR • APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info a Notes: Authorize additional flaring 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Continuous -pilot Plant Flare Manufacturer: Tornado Model No.: SL 16 -72 -18 -x.375 -12-316L Serial No.: 14180 Company equipment Identification No. (optional): FLR-1A For existing sources, operation began on: 7/1/2015 For new, modified, or reconstructed sources the projected start-up date is: ❑� Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Seasonal use percentage: Dec -Feb: Mar -May: 07 ICC days/week weeks/year June -Aug: Sept -Nov: s11 Form APCD-200 - General APEN - Revision 7/2015 2 Ai COLORADO Permit Number: 1 3WE3003 AIRS ID Number: 1 23 /9AD0/ 013 [Leave blank unless APCD has already assigned a permit H and AIRS !D] Section 4 - Processing/Manufacturing Information £t Material Use (] Check box if this information is not applicable to source or process From what year is the actual annual amount? Description Design Process Rate (Specify Units) I Actual Annual Amount (Specify Units) Requested Annual Permit Limit' (5penfy Units) Material Consumption: Finished Product(s): Requested values will become permit limitations. Requested timit(s) should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.8251192, -103.865267 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack ID No. Discharge Weight Above Ground Level (Feet) Temp. i' F) Flow Rate (ACFM) Velocity (fusr) FLR-1A 160 >2000 21,859 260.93 Indicate the direction of the stack outlet: (check one) ❑r Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ✓❑ Circular ❑ Square/rectangle ❑ Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap 16 Interior stack width (inches): Interior stack depth (inches): Form APCD-200 - General APEN - Revision 7/2015 q eoLOpaoo 3 a.M� p�nmemciNr�¢ Permit Number: 13WE3003 AIRS ID Number: 1 23 / 9AD0/ 013 [Leave blank unless APCD has already assigned a permit Yr and AIRS ID] Section 6 - Combustion Equipment Et Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTU/hr) Actual Annual Fuel Use (Specify Units) Requested Annual Permit Limit4 (Specify Units) 3,000 61.2rMMscf/yr 193.1 MMscf/yr From what year is the actual annual fuel use data? Indicate the type of fuel used5: 2015 ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ■❑ Field Natural Gas Heating value: 1 ,145 BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash Content: ❑ Other (describe): Heating value (give units): Sulfur Content: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5 If fuel heating value is different than the listed assumed value, please provide this information in the "Other" field. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ® Yes ❑ No D state the overall control efficiency (% reduction); ••i--r----- ----"-- Pollutant -"- -- - - Control Equipment Description Overall Control Efficiency (% reduction in emissions) TSP (PM) PMio PM2.5 SOS NOx CO VOC Flare 95 Other: Form APCD-200 - General APElJ - Revision 7/2015 4 l A� COLORADO 41/111 roan jF�Jr Permit Number: 1 3WE3003 AIRS ID Number: 1 23 /9AD0/ 013 [Leave bLank urtLass APCO t1a, already dsslgved a permit y and AIRS ID] Section 7 (continued) , From what year is the following reported actual annual emissions data? Reque5Ied12D15 a clue Is Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant. TSP (PM) Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Lmit(s)4 'Uncontrolled-. (Tons/year) Controlled6-7 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) 40 ug/L (controlled) AP -42 0.086 0 de minimus PM10 40 pg/L (controlled) AP -42 0.086 0 de minimus PM2,5 40 . g1L (controlled) AP -42 0.086 0 de minimus 5Ox 20 ppm H2S Gas Analysis O052 0 de minimus NOx o ass lannlew (..w,-.4.4 AP -42 1.97 0 7.5 CO o 91 lb/hAMBIL (cono-noed? AP -42 10.72 0 30.8 VOC 43881b/MMscf Simulation 135.57 6.78 423.6 21.2 Other: 4Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) equal to or greater than 250 lbs/year? Yes I=INo If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number Chemical Name Overall Contra; Efficiency Uncontrolled Emission Factor (specify units) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled Actual Emissions (tbslyear} Controlled Actual Emissions' (tbstyear) 110-54-3 n -Hexane -2015 Actual 95% 6653 333 71-43-2 Benzene -2015 Actual 95% 103 5 108-68-3 Toluene -2015 Actual 95% 86 4 110-54-3 n -Hexane -Requested 95% 9.43 lb/MMscf Gas Analysis 1722 86 71-43-2 Benzene -Requested 95% 2.86 lb/MMscf i Gas Analysis 552 28 108-88-3 'Toluene -Requested 95% 4,30 lb/MMscf ' Gas Analysis 830 42 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. 5 I 4s COLOR A00 fcvnoimwe Permit Number: 1 3WE3003 AIRS ID Number: 123 /9AD0/ 013 Section 7 (continued) From what year is the following reported actual annual emissions data? Requested/2015 Actual Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant l Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled (Tons/year) TSP (PM) PM{Q Controlled" (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM2. 5 Sox NO, CO VOC Other: 4Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. ection - on- riteria o utant Emissions 17 ormation Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) equal to or greater than 250 lbs/year? ®Yes END If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: ..ncon roe ncon - Overall 1 Emission Factor CAS Chemical Name Control Emission Source j Actual Number Efficiency Factor (AP -42 Mfg etc) Emissions (specify units) (lbs/year) 1330-20-7 Xylene-2015 Actual 95% 0 ontrone Actual Emissions° (lbs/year) 0 1330-20-7 Xylene-Requested 95% 1.52 lb/MMscf Gas Analysis 293 15 °Annual emis5inn fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. 5 Ir, COLORADO Permit Number: 13WE3003 AIRS ID Number: 123 /9AD0/ 013 [Leave blank unless APCD has already assigned a permit r# and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. 8/5/2016 Signature of Legally Authorized Person (not a vendor or consultant) Date Chenine Wozniak Environmental Professional ill Name (please print) Title Check the appropriate box to request a copy of the: ❑ Engineer's Preliminary Analysis conducted r❑ Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, H.C. for revised APEN requirements. Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-S5-B 1 4300 Cherry Creek Drive South Denver, CO 80246.1530 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: www.colorado.gov /pacific / cd phe /air -permits ^1Iis' .9X e Form APCD-200 - General APEN - Revision 7/2015 6 i L314, COLORADO ., Iv Envurt' Boiler APEN - Form APCD-220 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. If your emission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.covlcdphe/aped. Do not complete this form for the following source categories: - Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by natural gas or liquid petroleum gas (LPG). Heaters or boilers with a design capacity less than or equal to 10 MMBtu/hour used solely for heating buildings for personal comfort that is fueled solely by natural gas or liquid petroleum gas (LPG). More information can be found in the APEN exempt/permit exempt checklist: hops: / lwww.Coloradokovldacifac ledphelapen-orair-perm+t-exemptions. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 13WE3004 AIRS ID Number: 123 / 9AD0 /014 [Leave blank unless APCD has already assigned a permit !! and AFRS ID] Section 1 - Administrative Information Company Name: Site Name: Site Location: Whiting Oil and Gas Corporation Redtail Gas Plant Site Location NE 1/4, Section 21, T10N, R58W County: Weld Mailing Address: (include Zip Code) 1700 Broadway, Suite 2300 NAICS or SIC Code: 1321 Denver, CO 80290 Permit Contact: Chenine Wozniak Phone Number: E -Mail Address2: CDPHECorrespondence@whiting.com 303-802-8369 36026'7 1Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Permit Number: 13WE3004 AIRS ID Number: 123 /9AD0 / 014 Section 2- Requested Action ❑ NEW permit OR newly -reported emission source -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' 2 Other (describe below) -OR - ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: Whiting is submltling this permit modification application to Incorporate MACT Subpart DDDDD requirements. No changes to currently permitted equipment, emissions, throughput, or operational parameters are requested. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: Natural gas -fired hot oil heater Manufacturer: Zeeco Model No.: GLSF 14 Serial No.: J131132 Company equipment Identification No. (optional): HTR-1 A For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: ❑r Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Seasonal use percentage: Dec -Feb: Mar -May: days/week weeks/year June -Aug: Sept -Nov: Are you reporting multiple identical boilers on this APEN? Eyes ❑✓ No ,lf-yes, please describe how the fuel usage will be measured for each boiler (i,e,, one meter for all boilers ,or separate meters for each unit): Form APCD-220 - Boiler- APEN - Revision 7/2016 2 I AV COLORADO iIRM.00LORADO Permit Number: 13WE3004 AIRS ID Number: 123 /9AD0/ 014 ❑✓ Upward ❑ Horizontal [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.8252074, -103.8626633 Operator Stack ID No. _Discharge Height Above Ground Level (Feet) Temp, (.F) Flow Rate Velocity (ACFM) (ft/sec) I HTR-1A 92 1,552 27,568 23 Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): ❑ Other (describe): ❑ Upward with obstructing raincap 60 Interior stack depth (inches): Section 5 - Fuel Consumption Information Design Input Rate• DActual (MMBTUIhr) Annual Fuel Use4 Requested Annual Permit Limits (Specify Units) (Specify Units) 43.64 19 MMscf/yr 375 MMscf/yr From what year is the actual annual fuel use data? 2016 Fuel consumption values entered above are for: ❑ Each Boiler ❑ All Boilers 0 N/A Indicate the type(s) of fuel used5: ❑r Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 STU/SCF) ❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content: ❑ Other (describe): Heating value (give units): 4If you are reporting multiple identical boilers on one APEN, be sure to clarify if the values in this section are on an individual boiler basis, or if the values represent total fuel usage for multiple boilers. 'Requested values will become permit limitations, Requested limit(s) should consider future process growth. elf fuel heating value is different than the listed assumed value, please provide this information in the "Other" field, Form APCD-220 - Boiler APEN - Revision 7/2016 3I A COLORADO Permit Number: 13W E3004 AIRS ID Number: 123 / 9ADOi 014 [Leave blank unless APCD has already assigned a permit +t and AIRS ID] Section 6- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ['Yes n No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description TSP (PM) PM 10 PM 2.5 Overall Control Efficiency (.% reduction in emissions) Sox NO, CO VOC Other: From what year is the following reported actual annual emissions data? 2016 Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary Fuel Type (natural gas, ' Pollutant #2 diesel, etc.) TSP (PM) PMto PM 2_5 SOx NO, Uncontrolled Emission Factor (Specify Units) 13,26 lb/MMscf 13.26 lb/MMscf. Emission Factor Source (AP -42, mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Controlled' Uncontrolled I Controlled {Tons/year) (Tons/year) (Tonslyear) (Tonslyear) Manf Specs 0.12 Manf Specs 0.12 67.32 Ib/MMscf Manf Specs 0.62 CO 41.82 Ib/MMscf VOC Manf Specs 0.39 19.38 Ib/MMscfu Manf Specs Other: 0.18 2.5 2.5 12.7 7.9 3.7 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 'Annual emission fees will be based on actual. controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 7/2016 4 I T COLORADO 'x= ,el. wrc7 Permit Number: 13WE3004 AIRS ID Number: 123 /9AD0/ 014 [Leave bLank unless APCD has already assigned a permit 4 and AIRS ID] ❑f Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria emissions table below: Secondary iEmission Fuel Type diesel, Pollutant waste oil etc.) Uncontrolled Emission Factor (Speci(ytlnitsl Factor Source OP -42, Mfg etc) ' Actual Annual Emissions Requested Annual Permit q s Emission Limit(s)5 - --- , Uncontrolled Controlled' (Tonslyearr . (Tuns/year) Uncontrolled (Tonslyear) — Controlled (Tons/year) 1 TSP (PM) PM1a PM2.5 Sox NOx CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels" emissions tables in this Section 6: Pollutant Actual Annual Emissions Requested Annual Permit Emission Lirnit(s)5 , Uncontrolled Controlled ' (Tonslyear) . (Tons/year) Uncontrolled (Torn/year) Controlled' (Torrslyeur) TSP (PM) PM1a PM2.5 SOx NO. CO VOC Other: 'Requested values will become permit (imitations. Requested limit(s) should consider future process growth. TAnnual emission fees will be based an actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 7/2016 51 COLD ADQ Um.macn1u r,Nr Permit Number: 13WE3004 AIRS 1D Number: 123 f9ADO/ 014 [Leave blank unless APCD has already assigned a permit 4 and AIRS ID] Section 7 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) equal to or greater than 250 lbs/year? E Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number 110-54-3 110-54-3 Chemical Name I Control Emission Factor Efficiency (specify amts) n -Hexane 2016 Actual n -Hexane 0 0 1.6 lb/MMsof 1.8 lb/MMscf Emission Factor Source - (AP -42, Mfg. etc) AP -42 AP -42 Uncontrolled Actual Emissions fibslyear� 675 34 Controlled Actual Emissions jfbslyear) 675 34 'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. 3/a / Signature of Legally Authorized Person (not a vendor or consultant) Date Chenine Wozniak Environmental Professional III Name (please print) Title Check the appropriate box if you want: ❑✓ Copy of the Preliminary Analysis conducted by the Division ❑a Draft permit prior to public notice E Draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) This notice is valid for five (5) years unless a significant change is made, such as an increased production, new equipment, change in fuel type, etc. A revised APEN shall be filed no less than 30 days prior to the expiration date of this APEN form. Sendthis form along with $152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303) 692.3175 or (303) 692-3148 APCD-SS-B 1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 ilitt.ps://www.coloradcl,P.ovicdphe.rapcci Telephone: (303) 692-3150 Form APCD-220 - Boiler APEN - Revision 7/2016 AVCQLOR•DO Overall I Uncontrolled I Glycol Dehydration Unit APEN - Form APCD-202 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colarado.Rovlcdphelaped. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, Il.C. for revised APEN requirements. Permit Number: 13WE3005 AIRS iD Number: 123 f 9AD0 / 015 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: DEHY-1 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name: Site Name: Site Location: Whiting Oil and Gas Corporation Redtail Gas Plant Site Location NE 1/4, Section 21, T10N, R58W County: Weld Mailing Address: (include xlp Cade) 1700 Broadway, Suite 2300 Denver, CO 80290 E -Mail Address2: CDPHECorrespondence@whiting.com NAICS or SIC Code: 1321 Permit Contact: Chenine Wozniak Phone Number: 303-802-8369 Please use the full, legal company name registered with the Colorado Secretary of State, This is the company name that will appear on all documents issued by the APCD. Any changes wilt require additional paperwork. 2 Permits, exemption letters, and any processing invoices wilt be issued by APCD via e-mail to the address provided. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017 360243 iIAV' COLORADO Permit Number: 13WE3005 MRS ID Number: -123 / 9AD0/ 015 Section 2- Requested Action ❑ NEW permit OR newly -reported emission source -OR- Q MODIFICATION to existing permit (check each box below that appffes) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' ❑r Other (describe below) OR - • APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info is Notes: Whiting is submitting this permit modification application to incorporate MACT Subpart HH requirements into the permit. a For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: E Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Ethylene Glycol dehydrator DEHY-1 4 /6 /2014 / Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Is this unit located at a stationary source that is considered a Major Source of (HAP) Emissiulis Form APCD-202-Gtycol Dehydration Unit APEN • Revision 02/2017 2 days/week Yes Yes ❑v E weeks/year No No CPLORADO 2 I u..,.ii x rn. �mImm Permit Number: 13WE3005 AIRS ID Number: 123 / 9AD0/ 015 [Leave blank unless APED has already assigned a permit p and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: Alto Model Number: FAB38-20B (Burners) Dehydrator Serial 2012-8390-12 Reboiler Rating: 5 MMBTU/hr Number: Ethylene Glycol ❑ DiEthylene Glycol ❑ TriEthylene Glycol Glycol Used: (EG) (DEG) (TEG) Glycol Pump Drive:❑ Electric ❑ Gas If Gas, injection pump ratio: Pump Make and Model: Bear CX-5H Duplex Pump # of pumps: Glycol Recirculation rate (gal/min): Lean Glycol Water Content: Max: 6.0 20-40 Wt.% Requested: 6.0 Acfm/gpm 2 Dehydrator Gas Throughput: Design Capacity: 35 MMSCF/day Requested: 12,775 MMSCF/year Actual: 0 MMSCF/year Inlet Gas: Pressure: 486 psig Temperature: 80 °F Water Content: Wet Gas: 477 lb/MMSCF ❑✓ Saturated Dry gas: 0.14 Flash Tank: Pressure: 79,7 psig Temperature: 60 °F Cold Separator: Pressure: 486 psig Temperature: _32 °F Stripping Gas: (check one) ❑ None El Flash Gas ❑ Dry Gas ❑ Nitrogen Flow Rate: scfm tb/MMSCF ❑ NA O NA Additional Required Information: ❑ ❑ Attach a Process Flow Diagram Attach GRI-GLYCaIc 4.0 Input Report Ft Aggregate Report (or equivalent simulation report/test results) Attach the extended gas analysis (including BTEX It n -Hexane, temperature, and pressure) COLORADO Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 3 1 [fib` Permit Number: 13W E3005 AIRS ID Number: '.123 /9ADC/ 015 [Leave blank unless APCD has already assigned a permit and AIRS ID] Section 5 - Stack Information Operator Stack ID No. Geographical Coordinates (Latitude/Longitude or UTIel) 40.825353, -103.8647116 l}ischarTe Height Above Ground Level (Peet) Temp. rn Flow Rate (ACFM) Velocity (ftlsec) Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-2O2 -Glycol Dehydration Unit APEN - Revision 02/2017 4 I V COLORADO as W.T.I.h Fn,imnirnl Permit Number: 13W E3005 AIRS ID Number: 123 /9AD0' 015 [Leave blank unless APCD has already assigned a permit a and AIRS ID] Section 6 - Control Device Information ❑ Condenser: Used for control of: Still vent vapors Type: Shell and Tube Maximum Temp 250 F Requested Control Efficiency Make/Model: HTRI/BEM shell & tube Average Temp 120 F see VMG VRU: Used for control of: Size: Make/Model: • Requested Control Efficiency % VRU Downtime or Bypassed % Combustion Device: Used for control of: Still vent vapors Rating: 0.63 MMBtu/hr 24001 Type: Combustor Make/Model: LEED 1L30-0006 / Requested Control Efficiency: 95 % Btu/scf MMBtu/hr 0 Manufacturer Guaranteed Control Efficiency 98 % Minimum Temperature: 200 Waste Gas Heat Content 1020 Constant Pilot Light: 0 Yes • No Pilot burner Rating 0.02 Closed Loop System: Used for control of: Flash tank vapors Description: Emissions from flash tank are re-routed to the inlet slug catcher for the facility. 0 System Downtime 0 io Other: Used for control of: Description: • Control Efficiency Requested Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 ` COLORADO 5 xwrhh rr71=. Permit Number: 1 3WE3005 AIRS ID Number: 123 / 9ADQ 015 Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes 0 No e describe the control eouipmerit AND state the overall control efficiency {% reduction); Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SO, NO, CO VOC Combustor for still vent vapors 95 HAPs Combustor for still vent vapors 95 Other: From what year is the following reported actual annual emissions data? 2016 Use the following table to report the criteria pollutant emissions from source: r Pollutant Uncontrolled ' Emission Factor Emission Factor Units Emission Factor source (AP -a2, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limits) Uncontrolled (Tonslyeor) Controlled' (Tons/year) Uncontrolled (Tonsiyearl Controlled , (Tonsiyear) PM SOX NO, 0.068 lb/MMBtu AP -42 0 0.1 CO 0.310 lb/MMBtu AP -42 0 0.2 VOC 4.621 Ib/MMscf Simulation 0 0 29.5 1.4 Benzene 0.345 lb/MMscf Simulation 0 0 2.2 De minimis Toluene Simulation 0 0 De minimis De minimis Ethylbenzene Simulation De minimis De minimis Xylenes 0.076 lb/MMscf Simulation 0.5 De minimis n -Hexane De minimis De minimis 2,2,4- Trimethylpentane Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. COLORAaO Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 Permit Number: 13WE3005 AIRS ID Number: 123 / 9ADO/ 015 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. L V2--ct ti Signature of Legally Authorized Person (not a vendor or consultant) Chenine Wozniak Date Environmental Professional Ill Name (please print) Title Check the appropriate box to request a copy of the: l] Draft permit prior to issuance liJ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, Co 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www,colorado.gov/cdphe/apcd Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 7 I f COLORADO "e..oIVmen, 13WE3005 Permit Number: Whiting Oil and Gas Corporation Company Name: Zip Code: CO O c� NE 1/4, Section 21, T10N, R58W Plant Location: CDPHECorrespondance@whiting.com E-mail Address: Controlled Actual Emissions (lbs/year) O N N N Uncontrolled Actual Emissions (lbs/year) O CO O Cr Li, j Emission Factor Source VMG Simulation VMG Simulation Emission Factor (Include Units) 1 3.883 lb/MMscf 0.047 Ib/MMscf I Control Equipment / Reduction (%) 0) 1O O)O) LO Chemical Name Methanol -2016 Actual a> in a) n Cr CD Cc O C CZ L Ill H2S-Requested Chemical Abstract Service (CAS) Number to 0 , In CO 6 o co co a) O O. O N .C O 7, 0) a) J O a, 0_ O z C cn Environmental Professional III Chenine Wozniak Title of Person Legally Authorized to Supply Data Name of Person Legally Authorized to Supply Data (Please print) ril 14. 2014 Form Revision Date: A Glycol Dehydration Unit APEN - Form APCD-202 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is fined out incorrectly or is missing information and requires re -submittal, This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-2O0) is available if the specialty APEN options will not satisfy your reporting needs. A List of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.aovlcdphefaacd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements, Permit Number: 13WE3006 AIRS ID Number: 123 if 9ADO / 016 [Leave blank unless APCD has already assigned a permit # and MRS ID] Company equipment Identification: DEHY-2 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Whiting Oil and Gas Corporation Site Name: Site Location: Redtail Gas Plant Site Location NE 1/4, Section 21, T1 ON, R58W County: Weld Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Denver, CO 80290 E -Mail Address'-: CDPHECorrespondence@whiting.com NAICS or SIC Code: 1321 Permit Contact: Chenine Wozniak Phone Number: 303-802-8369 Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork, 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 360271 COLOAA DD Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017 Permit Number: 13WE3006 AIRS ID Number: 123 f 9ADO/ 016 Section 2- Requested Action ❑ NEW permit OR newly -reported emission source -OR - ❑r MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name O Add point to existing permit ❑ Change permit Limit ❑ Transfer of ownership3 0 Other (describe below) OR - ▪ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ▪ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info & Notes: Whiting is submitting this permit modification application to incorporate MACT Subpart HH requirements into the permit. ;For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Ethylene Glycol dehydrator Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: DEHY-2 H Y-2 9 /17 12015 / / Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Is this unit located at a stationary source that is considered a Major Source of (HAP) Emissions t f� Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 days/week Yes Yes ❑ O weeks/year No No 2 I & COLORADO Permit Number: 13WE3006 AIRS ID Number: 123 19AD0/ 016 [Leave blank unless APCD has already assigned a permit a and AIRS ID) Section 4 - Dehydration Unit Equipment Information Manufacturer: Dehydrator Serial Number: Glycol Used: Alco 2013-8482-12 Ethylene Glycol (EG) Model Number: N/A (part of plant) Reboiler Rating: 0 Dil=thylene Glycol (DEG) Glycol Pump Drive: ICI Electric ❑ Gas If Gas, injection pump ratio: Pump Make and Model: Bear CX-5 Duplex Pump MMBTU/hr ❑ TriEthylene Glycol (TEG) # of pumps: Glycol Recirculation rate (gal/min): Lean Glycol Water Content: Max: 18.0 20-40 wt.% Requested: 9.0 Acfm/gpm 2 Dehydrator Gas Throughput: Design Capacity: 70 MMSCF/day Requested: 25,550 MMSCF/year Actual: 7,197 MMSCF/year Inlet Gas: Water Content: Flash Tank: Cold Separator: Pressure: Wet Gas: Pressure: Pressure: Stripping Gas: (check one) 489 459 79.7 489 psig lb/MMSCF psig psig ❑r None ❑ Flash Gas ❑ Dry Gas ❑ Nitrogen Flow Rate: scfm Temperature: 0 Saturated Temperature: Temperature: 108 °F Dry gas: 0.17 60 -32 lb/MMSCF °F ❑ NA 'F ❑ NA Additional Required Information: ❑� Attach a Process Flow Diagram ❑� Attach GRI-GLYCaLc 4.0 input Report Et Aggregate Report (or equivalent simulation report/test results) ▪ Attach the extended gas analysis (including BTEX Et n•Hexane, temperature, and pressure) Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO 3 I a„ r aR Permit Number: 13W E3006 AIRS ID Number: 123 /9AD0' 016 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.825994, -103.864541 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. (' F) Flow Rate (ACFM) Velocity at/sec) Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Downward ❑ Horizontal ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑ Circular interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 4' COLORADO Permit Number: 13WE3006 AIRS ID Number: 123 /9ADD' 016 [Leave blank unless APCD has already assigned a permit 4` and AIRS ID] Section 6 - Control Device Information �✓ Condenser: Used for control of: Type: Maximum Temp Still vent vapors Shell and Tube 250 F Requested Control Efficiency Make/Model: HTRI/BEM shell & tube Average Temp 120 F See VMG % ❑ VRU: Used for control of: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed m Combustion Device: Used for control of: Still vent vapors Rating: 0.86 Type: Combustor Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: 200 MMBtu/hr Make/Model: LEED 1 L30-0006124000 95 99 Waste Gas Heat Content Constant Pilot Light: Yes ❑ No Pilot burner Rating 1208 0.02 Btu/scf MMBtu /hr Closed ✓2 Loop System: Used for control of: Flash tank vapors Description: Emissions from flash tank are re-routed to the inlet slug catcher for the facility System Downtime 0 90' ❑ Other: Used for control of: Description: Control Efficiency Requested Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 5 A coLaeaaa Permit Number: 13WE3006 AIRS ID Number: 123 / 9ADO 016 [Leave blank unless APCD has already assigned a permit tl and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. is any emission control equipment or practice used to reduce emissions? 0 Yes ❑ No D state the overall control efficiency i% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency fI reduction in emissions) PM 50,E NO, CO VOC Combustor for still vent vapors 95 HAPs Combustor for still vent vapors 95 Other: From what year is the following reported actual annual emissions data? 2016 Use the following table to report the criteria pollutant emissions from source: Pollutant Uncontrolled i Emission , Factor Emission Factor Units Emission Factor Source (AF -42, . Mfg. etc) Actual Annual Emissions Requested'Annual Permit Emission •Limit(s)" • - ' Uncontrolled Controlled' (Tons/year) (Tonstyeut ' Uncontrolled (Tons/year) Controlled (Tons/year) PM 50,E NO, 0.068 r lb/MMBtu AP -42 0.03 0.7 2.7 CO 0.31 lb/MMBtu AP -42 0.14 VOC 1.539 lb/MMscf Simulation 54.0 2.7 19.7 1.0 Benzene 0.302 lb/MMscf Simulation 0.23 0.012 3-9 0.2 Toluene 0.011 lb/MMscf Simulation De minimis De minimis 0.5 De minimis Ethylbenzene Simulation De minimis De minimis De minimis De minimis Xylenes 0.066 lb/MMscf Simulation De minimis De minimis 0-9 De minimis n•Hexane Simulation 0.65 0.033 De minimis De minimis 2,2,4- Trimethylpentane Other: a Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 6I COLORADO Permit Number: 13WE3006 AIRS ID Number: 123 / 9ADO/ 016 [Leave blank unless APCD has already assigned a permit N and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Authorized Person (not a vendor or consultant) Chenine Wozniak Date Environmental Professional III Name (please print) Title Check the appropriate box to request a copy of the: ❑r Draft permit prior to issuance ❑r Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-55-B 1 44300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small 'Business Assistance Program (303) 692-3175 or (303) 692.3148 Or visit the APCD website at: https: //www.colorado. gov/cdphe/apcd Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 7I cxgrei man COLORADO NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: Company Name: Plant Location: Person to Contact: E-mail Address: Chemical Abstract Service (CAS) Number 67-56-1 7783-06-4 13WE3006 Whiting Oil and Gas Corporation NE 1/4, Section 21, T10N, R58W Chenine Wozniak CDPHECorrespondence@whiting.com Chemical Name Methanol -2016 Actual Methanol -Requested H2S-Requested Control Equipment Emission Factor I Reduction (%) (Include Units) 0.758 lb/MMscf 0.013 lb/MMscf AIRS ID Number: 123/ADO/016 County: Weld Phone Number: 303-802-8369 Zip Code: CO Fax Number: 720-644-3636 Emission Factor Source VMG Simulation Uncontrolled Actual Emissions (lbslyear) 19,356 VMG Simulation 334 Cal dar Year for which Actual Data Applies: Requested Emissions/2016 Actual Emissions Signature of Person Legally Authorized to Supply Data Chenine Wozniak Name of Person Legally Authorized to Supply Data (Please print) Controlled Actual Emissions (lbs/year) Date Environmental Professional III Title of Person Legally Authorized to Supply Data Form Revision Date: April 14, 2014 r;; AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Amine Sweetening Unit' - Permit Number: 9 3WE3007 Facility Equipment ID: AMINE -1 Section 01 — Administrative Information Company Name: Whiting Oil and Gas Corporation [Leave blank unless APCD has already assigned a permit # & AIRS ID] Emission Source AIRS ID: 123 / 9ADO / 017 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization ] Section 02 — Requested Action (Check applicable request boxes) ❑ Request for NEW permit or newly reported emission source N Request MODIFICATION to existing permit (check each box below that applies) ❑ Change process or equipment ❑ Change company name N Change permit limit ❑ Transfer of ownership ❑ Other ❑ Request to limit fIAPs with a Federally enforceable limit on PTE ❑ Request APEN update only (check the box below that applies) ❑ Revision to actual calendar year emissions for emission inventory Update 5 -Year APEN term without change to permit limits or previously Source Name: Redtail Gas Plant Source Location: NE ''/., Section 21, T14N,1158W 1700 Broadway, Suite 2300 Mailing Address: Denver, CO 80290 Person To Contact: Chenine Wozniak E-mail Address: CDPIIECorrespondance@Whiting.co m Section 03 — General Information For existing sources, operatiob began on: Normal Hours of Source Operation: NAICS, or SIC Code: 1321 County: Weld Elevation: 4,831 Feet ZIP Code: 80290 Phone Number: 303-802-8369 Fax Number: 720-644-3636 10 / 23 / ❑ reported emissions Addl. Info_ Amine Type: Ucarsol 814 —DOW solvent, modeled as MDEA/Piperazine & Notes: Analysis from plant inlet, process inlet from VMG Simulation 2015 For new or reconstructed sources, the projected startup date is: 24 hours/day 7 days/week 52 weeks/year General description of equipment and purpose: DEA sweetening unit for removal of carbon dioxide from product gas. 1► Will this equipment be operated in any NAAQS nonattainment area? (www.colorado.gov/cdphe/attainment) ll► Does this facility have a design capacity less than 2 long tons/day of HZS in the acid gas? Provide docu.,,en,tation. Section 04 — Amine Sweetening Unit Equipment Information / / Manufacturer: Alen Reboiler Rating: 10.6 MMBtu/hr Amine Type: Amine Pump Make & Model: Electric Model: N/A - Contactor Serial No.: 2007-7722-02 Absorber Column Stages: 20 stages ❑ MEA ❑ DEA ❑ TEA ❑ MDEA ❑ DGA # of Pumps: 2 Sweet Gas Throughput: Design Capacity: 45 MMSCF/day Requested': 16,425 Calendar year actual: 1,072 Inlet Gas: Pressure: 536 psig Temperature: 83 Rich Amine Feed: Pressure: 527 psia Temperature: 132 Lean Amine Stream: Pressure: —526 psia Temperature: —110 °F Flowrate: 201 wt N amine: 55% Mole loading H25: 0.003% Mole loading CO,: 1.34% Sour Gas Input: Pressure: 536 psia Temperature: 83 °F Flowrate: NGL Input: Pressure: psia Temperature: °F Flowrate: Flash Tank: Pressure: 74 psia Temperature: 90 °F ❑ None 'You will be charged an additional APEN fee if APEN is filled out incorrectly or information is missing and requires re -submittal :lteues:cd values will become Permit limitations MMSCF/yr• MMSCF/yr Flowrate: 190 gal/min gal/min 45 MMSCF/day °F OF gal/min Additional ' - IGn€ormation Required: E Attach a process flow diagram N. Attach the simulation model inputs & emission report • Attach composition reports for the rich amine feed, sour gas feed, NGL feed, & outlet stream (emissions) ® Attach the extended as anal •sis (including BTLX & n -Hexane, II S, CO,, 2,2,'1 Trimetltyipentanel ❑ Yes N No ❑ Don't know N Yes ❑ No ❑ Don't know Colorado Department of Public Health and Environment Air Pollution Control Division (APCD) This notice, is valid for five (5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel"type, etc). Mail this form along with a check for $152.90 to: Colorado Department of Public Health & Env- meat APCD-SS-RI 4300 Cherry Creek Drive South Denver, CO 80246-1530 .�,_9 l6, For guidance on how to complete this APEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms: www.colorado_gov/cdphe/oilgaspermits Application status: www.colorado.gov/cdnhe/permitstatus N Check box to request copy of draft permit prior to issuance. N Check box to request copy of draft permit prior to public notice. FORM APCD-206 351973 Page 1 of 2 2016-07 APCD-206 Amine Unit APEN - AMINE-l.doc Permit Number: 13WE3007 Section 05 — Stack Information (Combustion stacks must be listed here) Operator Stack ID No Stack Base Elevation (feet) Stack Discharge Height Above Ground Level (feet) Temp. (°F} Flow Rate (ACFM) Velocity (ft/sec) Moisture (%) i AIR POLLUTANT EMIASSR3t4tMCE �. ��, Application for Construction Permit — Amine Sweetening Unit' - ll Emission Source AIRS ID: 123 / 9ADO / 017 Section 06 —Stack (Source. if no combustion Location (Datum & either Lat/Long or UTM) Horizontal Datum (NAD27, NAD83, UTM Zone UTM Fasting or Longitude UTM Northing or • Latitude Method of Collection for Location Data (e.g map, WGS84) (12 or 13) (meters or degrees) (meters or degrees) GPS, GoogleEarth) NADS3 13 40.825873 -103.8635879 map Direction of stack outlet (check one): ❑ Vertical ❑ Vertical with obstructing raineap Exhaust Opening Shape & Size (check one): ❑ Circular: Inner Diameter (inches) Section 07 - Control Device Information ❑ VRU used for control of ❑ Horizontal ❑ Down ❑ Other: Length (inches) = ❑ Other (Describe): Width (inches) = Indicate if a control device controls the flash tank and/or regenerator emissions) ® Combustion Device used for control of: Vent Stream Size: Make/Model: Requested VOC & HAP Control Efficiency: Annual time that VRU is bypassed (emissions vented): ® Describe Any Other: All flash tank emissions are recirculated into the inlet slug catcher for the facility. Type: Thermal Oxidizer Make/Model/Serial #: SN:13042 VOC & HAP Control Efficiency: Requested: 95 Minimum temp. to achieve requested control: 1350 °F Waste gas heat content: Constant pilot light? ® Yes ❑ No Pilot burner rating: Rating: 0.27 MMBtu/hr % Manufacturer Guaranteed: 98 29 Btu/scf 0.075 MMBtu/hr Section 08— Eniissions luvenlory Information & Emission Control Information 2 Emission Factor Documentation attached Data year for actual calendar yr. emissions below & gas throughput above ( e.g. 2087): 11 2015 Pollutant Control Device Description Primary Secondary Control Efficiency (% Reduction) Emission Factor Actual Calendar Year Emissions2 Requested Permitted Emissions' Uncontrolled Basis Units VOC NOx CO SO2 142S Benzene Toluene Ethylbenzene Xylene n -Hexane Identify in Section 07 Uncontrolled Controlled (Tons/Year) (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) Estimation Method or Emission Factor Source 39.074 lb/MMscf 3.13 0.16 320.9 10.0 0.068 lb/MMBtu 1.6e-5 0.5 Simulation AP -42 0.310 lb/MMBtu 7.1e-5 2.1 AP -42 0.0053 lb/MMscf 25.3 Simulation L723 lb/M.Miscf 14.2 0.8 Simulation 1.656 lb/MMsef 0.73 0.037 13.6 0.7 Simulation 0.578 lb/MlMscf 0.47 0.024 4.8 0.3 Simulation 0.043 lb/MMscf 0.085 tb/MMscf 0.141 Please use the APCD Non -Criteria Re You v,.:II be charp d an additional APEN fee if APEN is filled out ncvrrectly or information is missing and requires re•sutrmival. 'Annual emission fees will be based on actual emissions reported here. If left blank, annual emission fees will be based on requested emissions. Sectiop 09 -Applicant Certification - I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. 8/5/2016 Signature of Person Legally Ati }rized to Supply Data , Date Name of Legally Authorized Person (Please print) Title 0.4 De minimis Simulation 0.7 De minimis Simulation lb/MMscf 0.09 0.005 1.2 De minimis Simulation ortable Air Pollutant Addendum form to report pollutants not listed above. _ Chenine Wozniak Environmental Professional III Page 2 of 2 2016-07 APCD-206 Amine_Unit-APEN - AMINE-1,doc Hello