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Home My WebLink About20183277.tiffCOLORADO Department of Public Health t Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150O St PO Box 758 Greeley, CO 80632 October 2, 2018 Dear Sir or Madam: r7,70 ' r* OCT 08 2018 On October 4, 2018, the Air Pollution Control Division wilt begin a 30 -day public notice period for Whiting Oil and Gas Corporation - Horsetail 07 East CPB. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer PLof R,e,v;ecv PLC'TPJ, I -U -CUT), lO( t5/ fig- PwceRiCHfjr,n/ctc) 1O/tl/t8' 2018-3277 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Whiting Oil and Gas Corporation - Horsetail 07 East CPB - Weld County Notice Period Begins: October 4, 2018 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Whiting Oil and Gas Corporation Facility: Horsetail 07 East CPB Well Production Facility NWSE SEC 7 T10N R57W Weld County The proposed project or activity is as follows: Applicant Proposes new well production facility 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 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 17WE1222 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: Christopher Kester Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us 1 COLORADO Colorado Air Permitting Project PRELIMINARY ANALYSIS-PROJECT SUMMARY Project Details Review Engineer. Christophr:er Kaster Package#: 3717S3�� . Received Date: 11/Z0J26i7 Review Start Date: 8(14/20IQ�� Section Ol-Facility Information CompanyNdmE: .Whiting.O4tand6asCorporation�� Quadrant Section Township Range CountyAIRSID: 123 �. , NWSE ?'.' SDN � 57 � PlantAIRSID: 9�77 - . �� Facility Name: Hors�tail07 EastCFB � � � '��. Physical _ __ __ _ _ Address/Location: NWSE quadrant of Section 7,Township 10N,Range 57W County: Weld County Type of Facility: €xplorafir�n-&?aaducEion Well�*ad ..__.. .. ...... . ..... ........ W hat industry segment?'�t?ik&.Nafura[Gas Broductipn&Pros�sing � is this facility located in a NAAQS non-attainment area� .:- Na�� If yes,for what pollutant? � ca�bon Mo�obde�co� � aabc�iate wane��PM� ❑ Ozone(NOx&VOCJ Section 02-Emissions Units In Permit Application - Emissions Self Cert Engineering AIRs Point q Emissions Source Type Equipment Name Permit ri Issuance# Action Control? Required? Remarks �>�QQ1 :.�ther�ExpEain) DUST-Ol Yes� 17WE1221.XA 1 -�-�hEa AP£N Exen'rpt-:.Fugltive Dust... P�Yrrt'sf-t�t?7a81-' flQ2 Petsduced fi�Uater Tank PW-0?through PW-06 Yes 27WE1222 1 YeS 35suant� � � � Perm3Ein��i�6 � ...-.OD3 �rudetJ€lFan& TK-0lthro�ghTK-10 Yes 17WE1Z23 1 � --�Y�s 3ssuance � Feemit inri₹at .'. 004 -�eparatcrr Vsnting SEP-Q1 through SEP-Q8 Yes 17WE1224 1 :� `Fes lssuanie �.. Rerrnit Inlgial , 006 Natura3GasR9C� ENG-01 YEs 17WEI22E 1 V�S #s5uance , Perr�itln€tial I :: COS Na₹ura!Gas RICE � ENG-02 `fes 17WE1Z25 1 �� Y�� Issuance ��. _ Rerm3t inrtral �007 SegaratorVeating � SE?-18throughSEP-?0 Yes 17WE1237 1 :--Yss issuanc� -' Sedion 03-Description of Project New majar E&P facility in the attatnmen2 area �� Section 04-Public Comment Requirements � Is Public Comment Required? Yes If yes,why? Greakae tita�Sd tons per year in an kttainment Area �� Section OS-Ambient Air Impatt Analysis Requirement Was a quantitative modeling analysis required? :No If yes,for what pollutants? If yes,attach a copy of Technical Services Unit modeling rewlts summary. Section 06-Facility-Wide Stationary Source Classification Is this stationary source a true minor? �. Na '�. Is this stationary source a synthetic minor? ' Yes ' If yes,indicate programs and which pollutants: sOz Nox co voc PM2.5 Prvllo rsP HAPs Prevention of Significant Deterioration(PSD) a e e e e e o O Title V Operating Permits(OP) Colorado Air Permitting Project Non-Attainment New Source Review(NANSR) � � Is this stationary source a major source? �`��'��,� If yes,explain what programs and which pollutants here sO2 Nox co Voc PM2.5 PM10 TSP HAPs Prevention of Significant Deterioretion(PSD) Title V Operating Permits(OP) e � ✓ � � Non-Attainment New Source Review(NANSR) - v 006 Fugitive Emissions from Haul Road for Crude Oil and Produced Water Loadout E=k(s/12)^a*(W/3)^b AP-42 13.2.2, Equation 1a E=emission factor(Ib/VMT(VMT=Vehicle Miles Travelled)) k=constant from table 1322-2 s=surface material silt content(%) a=constant from table 13.2.2-2 W=mean vehicle weight(tons) b=constant from tabie 13.22-2 Constants W(tons) Pollutant k a b W,Empty W,Loaded W,Avg s* % E Ib/VMT TSP(PM) . 4.9 0.7 0.45 �� - 28.�5 5 7.28 PM-10 1.5 0.9 0.45 i=.' =.'2.5 ?8.25 5 1.87 PM-2.5 0.15 0.9 0.45 1^- �25 28.25 5 0.19 �CDOT 2011 Standar Specifcation Book Table 703-3 Class 6 Aggregate Base Course Total Estimated VMT: 35� miles/yr Emissions Summary Table Pollutant E�1b/VMT) Uncontrolled Emissions Control Factor** Controlled Emissions TSP(PM) 7.28 1.31 tpy 21.9% 1.02 tpy PM-10 1.87 0.34 tpy 21.9% 0.26 tpy PM-2.5 0.19 0.03 toy 21.9% 0.03 toy '*Natural mitigation from precipitation per EPA AP-42 Volume 1 Fifth Edition-November 2006 Table 13.2.2-2 Equation 2;number of days with natural preciptiation from figure AP-42 Figure 13.2.2-1 Requlation 1 -ParticWate.'Smoke,Garbon Monoxide and Suifur Dioxide 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 si�y consecutive minutes. (Reference: Regulation No. 1,Section II.A.1. &4.) Requlation 3-APENs.Gonstructioo Permits.Oqerafinq'Permits'PSD Criteria Pollutants: For criteria pollutants,Air Pollutant Emission Notices are required for:each individual emission point in an attainment area with uncontroiled actual emissions of two tons per year or more of any individuai criteria poilutant(pollutants are not summed)for which the area is attainment. SCC 31088801:Fugitive Haul Road Emissions This source is below APEN reporting thresholds and is APEN exempt. Produced Water Storage Tank(s)tmissions Inventory 002 Produced Water 7ank PacilityAlRsID: �� -�-9� - ��? -� � Counry Plant Point � Section 02-Eouioment Descriotion Details ......__ ...._. .. ._._........ ......... ......... ..._... .......... ._..... _..._. DetalledEmissionsUnR Sfx�fi}Aq0t�41a6ovagroundfixedranf¢Ead�cedxsraterstoregetaatss Description: _ �� _ . _, . Emissian Cantrol Device ,�.'�� I, '. f 3 enclased cum6ustor . I '�- Descriptiort: , ' ' �: _ . . . ,,,,, ,„,_ n.. . ... ........ . ......:• �.. - Requested Overall VOC&HAP Control - Efficiency%: '�. 95 Sec[ion 03-Processine Rate Intormation for Emissions Estimates Primary Emissions-Storage Tank(s) . ...... ...._._ .......___... Actual Produced WaterThroughput= � 4,380,0��-Barrels(bbl)per year Actual Produced Water Throughput While Emissions Controls Operating= ' A,3S0,000� Requested Permit limit Throughput= 4,380,60D'�Barrels(bbl�per year Requested MonthlyThroughput= 3R000 8arrels(bbl)per month �� Potential to Emit(PTE)Produced Water - Throughput= ['� 4,38Q�606!Barreis(bbl)per year � - Secandary Emissions-Combustion Device(s) Heat content of waste gas= 1��BN/scF 1037 Volume of waste gas emitted per BBL of liqu�ds produced= _ I.8!sd/bbl � Actuai heat content of waste gas routed to mmbustion device= 8,948 MMBTU per year Requestedheatmntentofwastegasroutedtommbustiondevice= � 9,943MMBTUperyear Potential to Emit(PTE)heat content of waste gas routed to com6ustion device= 5,948 MMBTU per year Section 04-Emissians Fac[ors&Methodoloeies � �%5 � Willthisstoragetankemitflashemissions� � Emission Factors Produted WaterTank Uncontrolled Controlled (Ib/b61) (Ib/bbl) EmissionFanor5ource Pallutant (Produced (aroduced Water Water Throughput) Throughput) voe a�aas9a- o.002zoo �e s� ,,.c,--:s.�;.c,uae5�3sr„ Benzene Q:COC�3� 0.000023 5.[YS�t+�fc.':f.{3eic�vdesfi�:>t+; 7oluene 6:�0q?i-",. 0.000011 S a s+e^.�:.G_F trnr3c�iea9�� Ethylbenzene 6:DOe317 0.000001 S,eS�rwinc��:E.(in.iades`3Qa'h;'� Xylene C.�OG�'3a O.OOOOU2 S�t,.SRep�fc°.F(7nciud'k5�� n-Hexane D,03�59 0000138 �Le'Sp�d"��.�t�n,�y��, ,ti,�. " 224 TMP l?.0001fl2 0.000005 � ,,'„��„��.{�nYfiil'�5{ia573� ,�;`"�.. Conirol Device Uncontrolied Uncontrolled Pollutant (�b/MMBtu) (Ib/bbl) EmissionFactor5ource (Produced (waste heat water � rombusted) Throughput) PM10 0.0000 ��`�s �% PM2.5 '- 00000 � Y - - '�� i a' v ✓5. af-'"c'�„'� . NOz Q.a6S0 0.0001 -F" - �b,�3��af��' CO 0.310v' . 0.0006 --�-A�Chap�'�T�,', ��C3Y£5��t2�� Section OS-Emissians Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Conirolled Controlled (tons/year) (tons/year) (tons/year� (tons/year) (tons/year� (Ibs/monih) VOC 96.3 96.3 4.8 96.3 4.8 81S PM10 0.0 0.0 0.0 0.0 0.0 0 PM2.5 0.0 0.0 0.0 0.0 0.0 0 NOx 0.3 0.3 0.3 0.3 0.3 52 CO 1.4 1.4 1.4 1.4' 1.4 236 Potential to Emit Actual Emissions Requested Permit Limits HazardousAirPollutants Uncontrolled Umm�trolled Conirolled Un<ontrolled Controlled (Ibs/year) �1bs/year) (Ihs/year) (Ibs/year)- (Ibs/year) Benzene 2027 2027 101 2027 10b Toluene 935 935 47 935 47 Ethylbenzene 74 74 4 74 4 Xylene 148 148 7 148 7 n-Hexane 12086 12086 604 12086 604 224TMP 4M15 445 22 445 22 SeRion 06-ReeulatOry SummaN AnaIV5i5 Regulation 3,Parts A,B Source require5 a permit Regulation 7,Sec[ion XVII.B,C.1,G3 Storage tani<is subject to Regulation 7,Section XVII,B,C1&C.3 Regulation 7,Sec[ian XVII.C.2 Storage tanlc is subject to Regulation 7,Section XVII.C.2 Regulation 6,Part A,NSPS Subpart 0000 Stora e Tank is noi subjett to NSPS 0000 � �See regulatory applicability worksheet for detailed analysis) 4 of 26 i:\Oil&Gas Puhlic Notice\17WE1222\17WE1222.CP1.PA.xlsm Produced Water Storage Tank(s)Emissions Inventory Section 07-Initial and Periodic Samnline and Testina Requirements Does the company use a site specific emissions factor to estimate emissions? i� v� If yes and if there are flash emissions,are the emissions factors based on a pressu z d 1 q id wat r sample drewn � � x£� ��? � at the faciliTy being permitted and analyzed usmgflash li6eration analys�s?This sample should be mnsidered � '" : y a <:, representative which generally means site speafic and collected within one year of the applicaLon received date r� ,' ��e `p„ However,if the facJity has not been modi{��(e.g.,no new wells 6rought on-line�,then it may be appropriate to �; ��;� . �� , use an older site specific sample. Y�fesmy�,�;, If no,the permit will contain an"Initial Compliance"testing requirement to develap a site specific emissions factor.See PS Memo 14-03,Questions 5�9 and 5.12 for additional guidance on testing. Does ihe company request a control device efficiency greater than 95%for a flare or com6usiion device? _��r�y_�� If yes,the permit will contain and initial comp�iance test condition to demonstrate the destruction efflciency of the combustion device 6ased on inlet a�d outlet concentration sampling Section08-TeChniCalAnal sisNote5 . _.__ ..._.. ......... .. 61ash IiberaTion performed Ana y�is on�parate sheet. Section 09-Inventory SfC Codine and Emissions Factors Uncontrolled Emissions - AIRS Point# Process ii SCC Code Pollutant Factor Control% Units 002 Ol 4-04-003-75 Fixed RoofTank,Produced Water,working+6reathing+flashing losses PM10 0.00 0 16/1,000 gallons liquid throughput PM2.5 0.0� 0 Ib/1,000 gallons liquid throughput N0x 0.00 0 16/1,000 gallans liquid throughput V0C 1.0 95 16/1,000 gallans liquid throughput C0 0.02 0 Ib/1,000 gallons liquid throughput � Benzene 0.01 95 16/1,000 gallons liquid throughput � Toluene 0.01 95 Ib/1,000 gallons liquid ihroughput Ethylbenzene 0.00 95 Ib/1,000 gallons liquid throughput Xylene 0.00 � 95 Ib/1,000 gallons liquid throughput n-Hexane 0.07 95 ib/1,000 gallonsliquidihroughput 224 nv1P 0.00 95 16/1,000 gallons liquid throughput 5 of 26 I:\0il&Gas Public Notice\17WE1222\17WE1222.CP1.PA.xlsm Separator Venting Emissions Inventory 004 Separator Venting FacilltyAlRsID: �3 .. ,�, ; 9F771 ., � .. .- �9t32'��. . „ County Plant Point Section OZ-Eaui oment Descrip[ion Details F4ssh fi6erailonianaiysis£br the psoduced water tank vte specifie flasFring emissio�facKors. : Detailed Emissions Unit Descriptiore . , . , . , . Enclosed cambustac Emission Control Device Descriptian: Req�ested Overall VOC&HAP Cont�ol Efficienry%: 95��. Limited Process Parameter Liquid throughput Seccion 03-Processine Rate Information for Emissions Estimates Primary Emissions-Separeror ____. ......... AaualThroughput=' .:4;3$O,tl00:!Bamels(661�peryear RequestedPermitLimitThroughput= 4,380,UOO::Barrels(bbl�peryear RequestedMonthlyThroughput= 372000 Barrels�6hl)permonih Potential to Emit(PTE)Throughput= 4,390,000 Bartels(661)per year Secondary Emissions-Comhustion Device(s)for Air Pollution Control Separator Gas Heating Value: 1135�.:Btu/scf 1037 Volume of was[e gas emi[ted per BBL of liquidsthroughput _ 1.S'�,,scF/661 Section 04-Emissions Factors&Methodoloeies Description MW 29.1771��16/Ib-mol DisplacementEquation Ex=Q°MW`Xx/C � Weight% Helium ��0:000a CO2 � ��.��12.6450� N2 � ?1��.1179 methane 2Z234-1�� ethane 7?.2575 propane 15.8995 isobutane 14M129 n-butane � G:Z1fJ0' isopeMane 1�.0533�. n-pentane � L�}Lp3��. cyclopentane O.iM1S3��. n-Hexane 1 39:t3��. cyclohexane . 0?a30 Otherhexanes � i�7929 heptanes �0?471' methylcycbhexane 0.1478'. 224-TMP 0.6734 Benzene 0�.3339�. � Taluene �� 0,1541�� Ethylhenzene 0 01�2�. Xylenes 0.014�F C8+Heavies . 0.2628�. Total luo_0000 VOC Wt% 31.7J54 Emission Factors Separetor Venting Uncontrolled Controlled Pollutant Qb/bbl) (Ib/hbl) EmissionFactor5ource (Liquid Throughput) (Liquid Throughput) VOC 0.0440 0.0022 Benzene 0.0005 a.00ao Toluene �.0002 0.0000 Ethylbenzene o.0000 O.OODO Xylene 0.0000 0.0000 n-Hexane 0.0028 0.0001 224TNIP 0.0001 0.�000 � Primary Conirol Device uncantrolled Uncontrolled Pollutant (Ib/MMetu) Ib/6h1 EmissionFactorSource (Waste Heat Combusted) (GasThroughput) PM10 � a.000 PM2.5 0.000 SOz �� 0.000 NOx -.�.0.�680 0.000 CO �� 0�:3100 0.001 6 of 26 I:\Oil&Gas Pu61ic Notice\17WE1222\17WE1222.CP1.PA.xlsm Separator Venting Emissions Inventory Section OS-Emissi ns Inventory Potential to Emit ARual Emissions Reques[ed Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolied Conirolled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (Ibs/month) PM10 0.00 �.00 0.00 0.00 0.00 0 PM2.5 a.oa 0.00 0.00 0.00 0.00 0 SOx 0.00 0.00 0.00 0.00 0.00 0 NOx 030 0.30 030 0.30 0.30 52 VOC 96.34 96.34 4.82 96.34 4.82 818 ' CO 1.27 1.27 1.27 1.27 1.27 215 Potential to Emit Actual Emissions Requested Permit Limits . Hazardous Air Pollutants Umm�trolled Uncontrolled Conirolled Uncontrolled Controlled . (16s/year� (Ibs/year� (I6s/year) (Ibs/year) �1bs/year� Benzene 2027 Zo27 101 2027 107 Toluene 935 935 47 935 47 Ethylbenzene 74 74 4 74 4 %ylene 148 148 7 148 7 n-Hexane 12086 12066 604 12086 604 - 224TMP 445 445 2Z 445 22 7 of 26 I:\Oil&Gas Pu61ic Notice\17WE1222\17WE1222.CP1.PA.xlsm Produced Water Storage Tank Regulatory Analysis Worksheet Please note thae NSPS K6 might 6e might be applica6le for certain tanks at water management and injection facilities.If the tanks you are reviewing are at one of these facilities,please review NSPS Kb. CalortdoRe uletlon3iartsAandB-APENandPermltFe en4 Source is in the Attainment Area ATfA1NMEM - 1. A�euncontrolledactualemssons?romanycrRenapollLLant5fromthsindivdualsourcegreate�Nan2iPV(Regulation3,PartA,Sec[ionll.D.l.a�? fes... =:-'�`SouceReq f 2. Is[he opera[o�cla m ng less:han 1°h crude oil and is ihe tank loca[ed ai a non commerc al fac I'ry for process ng ail and gas wastewa[eR(RegulaHon 3,Part B,Section II.D.S.M) No ��Go to next� - 3. Are[otal(ac i ty�n on[rolled VOC emissions g�eater thai 5 TPY,NOx greate�than 10 TPY or CO em ss ons greate�[han SO TPY(RegulaGon 3,Part B,Section II.D.3)7 Yes -:Sourte Req Source requires a pertnit ' NON-ATfAINMEM 1. Areumm�holledemissionsfromanycriteriapallutantrfromthisindividualsourcegreaterthanlTPY�Regulation3,PartA,5ec[ionll.D.l.a�7 � 2. Is the ope2[or daiming less than 1%crvde oil and Is the�nk located at a non-rommerclal facility for processing oil and gas wartewater?(Pegulation 3,Part B,Section II.D.S.M) 3. Are total tacility unconholled VOC emissions grea[er tha�2 TPY,NOx greate�than 5 TPV or CO emissions greater than 10 TPY(Regulation 3,Part 8,Section II.D.2�? You have indicated that source is in che Anainmenc Area Colorado Reeulatlan 7 Sec[ionXVII 1. Is[histanklocatedatatransmission/storagefacility7 No Continue-' 2. Is Ihis produced wate�sto�age[ank'lacated at an oil and gas explars[ion and produRion opera[ion,well productlon facilily�,nahral gas comp�esso�station3 or naNral gas p�ocessing plan[? Yes Continue-' 3. Is this produced water storage tank a fixed roof srorage tank7 1'es �'i Go to the n 4. Areunconholledactualemssons°ofthsstoragetankequalmorgreaierthan6tonsperyearVOC? YCs' �-:'�..Sourceiss� Storzge ta�k is subjx<[to ftegulation 7,Sect�n XV II,B,C.1&C.3 Sectlon XVII.B—6eneral Provisions(o�Air Pallution Control Equipmen[and Preventlon of Emissions Sec[ion XVII.C.1-Emissions Control and Moniforing Provisions Sec[lon%VII.C.3-RecoNkeep ng Requ7ement5 �---� 5. �oes the produced water storage tank conta n only"stab I zed"lipuids?If no,thc fallawing addiHonal provisions appty. �rvu..._::,,,_��Source is n 5[ g t k- b" t R g I t' ]5 ct XYii C� � Sectlon XVII.C.2-Capture and Monitoring for Storage Taiks ntted with Air Pollution Control Equipment 40 CFR Part 60 Sub rt 0000 Standards ot Partormance br[rude Oil and Natural Gas Productian Tartsmisslon and Distnbution 1. Is chis praduced wa[er storage vessel loca[ed at a facilityin the anshore oil and natural gas produc[ion segment,natural gas processing segment or natural gas ttansmission and starage segment of the indus[ry7 Ves Continue-' 2. Was this praduced water sio2ge vessel wnstructed,remnstructed,or modifed(see defn[ions 40 CFR,60.2)between August 23,2011 and September 18,20157 3. Are patentlal VOC em ssions'hom the ndiv dual smrage vessel greater than or equal to 6 tons per year? No "..Storage Tar 4. Oaes ihis produced water staage vessel meei the def n'tion of'stoage vessel"�per 6'J.54307 Storage Tanlc is r.ot subieci co NSPS 0000 Subpert A,Gene�al Provisians per§E0.5425 Tahle 3 4��5395-Emissions Control S[andards for VOC 4�.5413-Testing and Ptocedures � §60.5395(g)-Noti{ication,Reporting and Recordkeeping Requiremen[s - §60.5416�c�-Cover and Closed Vent Sys[em Moni[oring Requirementz §60.541]-Control Device Monitoring Requiremenis �Note:If a rtorage vessel is previausly detarmined to be subject to NSPS 0000 due ta emissions abave 6 tons per yeer VOC on ihe applicabilky de[e�minetlon date.It should remain subjecl ta NSPS 0000 per 60.5365�e�(2� even if poten[lal VOC emissions drop below 6 tons peryeer� RAR Review RAR revlew Is required'rf Regula6an]does no[apply AND Hthe tank is In the nan-attainment area.If the tank maets bath critena,ihen review RACT requirements. Disclaimer This document assisls operators with datarmining applicability olcertain requirements of the Clean Ai�Act,ils implementing regWations,and Ai�Quality Control Commission regulations.This documenf is nof a iule orregulation,antl fhe anatysis it contains may nof apply fo a particularsituatlon based upon fhe individual facts and urcumsfances.This documenf does not change or substitufe for any law, regula[ion,or any otherlegally binding requirement and is nof legalty en(orceable.In the evenf o(any conflict between the langua7e o�this document and fhe language ot ihe Clean AirAcf„its implementing regulafions,and AirQualiryControl Commission regulalions,Ihe language offhe staWle orregulation will confrol. The use of non-mandatory language such as'recommend,"'may," "should,"and°can,"is in(ended m descnbe APCD inferprefafions and recommendations.Manda[ory terminology such as"must"and"required"are infended fo descnbe controlling requirements unCer the ferms o�ffie Clean Ai�Act and AirQuality Control Commission regulafions,but fhis document does no(es(ablish legalty binding requiiemenfs in and ofitself Crude Oi)Storage Tank(s)Emissions Inventory 003 Crude Oil Tank FacilityAlRsID: �'Z� ` 9F� �-: �Q' � County Plant Point Section 02-Eouioment Deuriotion Detaiis DetaledEmissionsUnit Ten(10)4061i6[abovegroundfixedroof'i¢udeoiEstorageLartks DescnPt on: .. . .. .. .. . .. .. . . .. . . Em ssion Conirol Devire � � � - _ - , , _ , � ,_ ; , enc(dsed Combasew �. � DescnPt on: ., . _ ... .. .. .. . .., , .. . .. . Requested Overall VOC&HAP Control Efficiency%: �SS � ______.__ .._....._.I Section 03-Processin¢Rate Information for Emissions Estimates Primary Emissions-5[orage Tank(s) Ac[uaI Throughput= �� 1�,642;560��.Barrels(bbl)per year Ac[uaI Crude 0iI Throughput While Emissions Controls Operating= Requested Permit LimitThroughput= 1,6q2��;500��.Barrels(bbl)per year Requested Monthly Throughput= 139500 Barrels(b61)per month PotentialtoEmit�PTE)Throughput= , 1��,6A2,SOp��.Barrels(661)peryear Semndary Emissions-Combustion Device(s) Heat mnrent of waste gas= 2516�'�.Btu/scf 2315 Volume of waste gas emitted per BBL of liqu�ds produred= ' ll Ssl scf/bbl Actualheatcontentofwastegasroutedto<ombustiondevlce= 47,855 MMBNperyear , Requested heat mntent of waste gas routed to com6ustion device= 47,855 MMBTU per year Potential to Emii(PTE)heat content of waste gas routed to combustion device= . 47,855 MMBTll per year Sec[ion 04-Emissions Factors&Methodoloeies � . fi WillthisstoragetankemltFlashemssons? s � _ EmissionFactors CrudeOilTank Uncontrolled Controlled Pollutant (Ib/6bl) (16/661) .Emission Fac[or5ource (CrudeOil (CrudeOil . Throughput) Throughpu[) VRTOperetiona1�25%� VRTBypass(75h) VRTOperation VOC i.09A725 0.054736 0.12880 0.00644 1.41670 0.07084 52889 Benzene 0.00235Q 0.000118 0.00070 0.00004 0.00290 0.00015 287 Toluene O;C¢i50U �� 0.000075 0.00030 0.00002 0.00190 0.00010 123 Ethylbenzene . 0.600233�� 0.�00012 0.00003 0.000002 0.00030 0.00002 12 Xylene O:QOOA75 �� 0.000024 0.00010 0.00001 0.00060 0.00003 41 n-Heuane OOZ147,5 0.001074 0.00460 0.00023 0.02710 0.00136 1889 224TMP O.d0215Q 0.000308 0.00020 0.00001 0.00280 0.00014 82 Conirol Device Uncontrolled Uncontrolled Pollu[ant Qb/MMBtu) (16/661) EmissionFactor5ource (wasteheat (CrudeOil ombusted) Throughput) PM30 0.900D PM2S � 0.0000 NOx 0:068�3�.�. 0.0020 t4Y A2L�„:a 12:�r au-Er+a]F`a f�,3a? [O 031➢Il�. 0.0083 .SP�s-"'� w�{7.,e.351n��z..t„hlfla;`e;�f�;" � SecCion05-Emissi nslnventory . Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Umits � Criteria Pollutants Uncontrolled Uncontrolled Conirolled Unrontrolled Conirolled Controlled (tons/year) �tons/year� (tons/year� (tons/year� (tons/year) (16s/month� VOC 899,0 899,0 45.0 899.0 45.0 7636 PM10 0.0 0.0 0.0 0.0 0.0 0 PM2.5 0.0 0.0 0.0 �.0 0.0 0 NOx 1.6 1.6 1.6 1.6 1.6 276 CO G.S 6.8 6.8 G.8 6.8 1159 Potential to Emit Actual Emissions Requested Permit Limits HazardousAirPollutants Un<ontrolled Uncontrolled Controlled Unrontrolled Controlled (Ihs/year) �Ibs/year� (Ibs/year� Qhs/year) �1bs/year� Benzene 3860 3860 193 3860 193 Toluene 2454 2464 123 2464 123 Ethyl6enzene 382 382 19 382 19 Xylene 780 780 39 780 39 n-Hexane 35273 35273 1764 35273 1764 224 TMP 3531 3531 177 3531 177 Section06-Re ulato Summa Ana s . Regulation 3,Parts A,B Source requires a permii Regulation 7,Sec[ion XVII.B,Cl,C.3 Storage tank is supjec[to Regulation 7,SeRion XVII,B,C.S&C.3 Regulation7,5ectionXVII.C.2 SLoragetankissu6jecttoRegulation7,5ecCionXVi7,C2 Regulation 6,Part A,NSPS Subpart Kb S[orage Tank is not su6ject to NSPS Kb Regulation 6,Part A,NSPS Su6part 0000 Srorage Tank is not subjett to NSPS 0000 Regulation 8,Part E,MACTSubpart HH Storage Tank is no[su6ject₹o MACT HH (See regulatory applicability worksheetfor detailed analysis) 9 of 26 I:\Oil&Gas Public Notice\17 W E1222\17W E1222.CP1.PA.xism Crude Oil Storage Tank(s)Emissions Inventory Section 07-Initial and Periodic Samvlin¢and Testinz Requirements � �,_s, Does the company use ihe state default emissions factors to estimate emiss ons? �r5�;� If yes,are the uncontrolled actual or requested emissions esnmated to be greater ihan or equal to 20 tons VOC per year? :,,;;�',,�„��,;,k,,,,,,---; If yes,the permit wiil con[ain an"Initial Compliance"testing requirement to develop a sire specifc emissions factor based on guidelines in PS Memo 1403 Doesihecompanyuseasitespenficemissionsfactortoestimateemissions? �; �,,,,,;� � If yes and if ihere are Flash em svons,are the emissions facmrs 6ased on a pressunzed liquid sample of<rude oil drawn at the facility being permitted? Yas , _ . If no,the permit will contain an"Initial Complian<e"testing requirementto develop a site specific emissions tac[or based an Suidelines in PS Memo 14-U3. � � y f Does ihe company request a mntrol device efficiencygreater than 95%for a flare or mm6ustion device? iSD �,��;�,�,,,�,,,y,,,,,,��; ,�,'�'��,,,��p�,�„ i If yes,the permit will mntain and initial mmpliance test mndition to demonsirate the desiruction efficiency of the com6ustion device hased on inlet and ouHet concentration sampling Secnonos-T hnialAnalvssN t ........ � Section 09-Inventory SCC Codinc and Emiuions Factors � � Uncontrolled Emissions AIRSPoint# Pro<ess# SQCode Pollutant Factor Control% 003 Ol ,+�-0�-ODSnT2��LaaF�aak C�ud�eyA ,,.,,.,rs.9s�reai#-��g.ik3ad �ses. r,.. ;�'� 1».w,,ti;i,,,,w:t PM10 0.00 0 PM2.5 0.00 0 NOx 0.05 0 VOC 26.1 95 CO 0.20 0 Benzene 0.06 95 Toluene 0.04 95 Ethylbenzene 0.01 95 Xylene 0.01 95 n-Hexane 0.51 95 . 224 TMP 0.05 95 10 of 26 I:\Oil&Gas Public Notice\17WE1222\17WE1222.CP1.PA.xlsm Crude Oil Storage Tank(s)Emissions Inventory F,6,4Z,50t# ial(25%) VRT Bypass(75%) 2644 1745197 87260 14 3572 179 6 2341 117 1 370 18 2 739 37 94 33384 1b69 4 3449 172 11 of 26 I:\Qil&Gas Puhlic Notice\17WE1222\17WE1222.CP1.PA.xlsm Crude Oil Storage Tank(s)Emissions Inventory Units Ib/1,000 gallons crude oil throughput I6/1,000 gallons aude oil throughput Ib/1,000 gallons crude oil throughput I6/1,000 gallons crude oil ihroughput Ib/1,000 gallons crude oil throughput Ib/1,�00 gallons crude oil throughput Ib/1,000 gallons crude oil throughput ' Ib/1,000 gallons crude oil throughput Ib/1,�00 gallons crude oil throughput Ib/1,000 gallons cmde oil throughput Ib/1,000 gallons crude oil throughput 12 of 26 � I:\Oil&Gas Puhlic Notire\17WE1222\17WE1222.CPS.PAxlsm Crude OiI 5torage Tank Regulatory Anatysis Worksheet Colo2doRe ulatlan3Per[sAandB-APENendPermitRe ulrements Source is in the attainment area AlTA1NMEM 1. Areu coniralledactualemissionsfromanycrite�iapallu[anSsfromihisindividual5ourcegreaterthan2TPV(Regulatlon3,PartA,5ec[ionll.D.1.a�? ��:�`�SourceReq 2. Is the ronsLr�cHon date pnorto 4/14/2�14 and nat madified aker 4/19/14(See PS Memo 1403 for additional guidance on grandfather applicahiliry)7 Ncs '��60[o next� 2a.If answer to a2 is yes,is the crude ail thraughput less Ihan 40,000 gallons peryeaR "�� 3. Aremtalfacilityumm�trolledVOCemissiansgreaterthan5TPY,NOxgreaterthanlOTPVorCOemissionsgreaterihanlOTPY(RegulaHan3,PartB,5ectionll.D.3�? ��SourceReq Source requires a permi[ NON-ATTAINMEM 1. Areuncantrolledemissionsfromanyc�ite�iapollutantsf�om[hisindividualsourcegreaterfhanlTPY(Regulatlon3,PartA,5ectionll.D.l.a�? 2. Is the cans[ructfan date prior to 4/14/2014 and not modified afte�4/14/14(See PS Mema 14-03 far additional guidance on g�andfa[her applicabillty�7 2a.If answerm N2 is yes,is the cr�de oil ihroughpu[less ihan 40,000 gallons per year7 3. Are[o[al facility uncontrolled VOC emissions from the greate�than 2 TPV,NOx greate�than 5 TPV or CO emissions greate�than 30 TPY(Regulation 3,Part B,Sectian II.D.2)? You hede indicated that source is in the Attainment Nea Coloado fteeulatlon].Section%VII 1. Is[hisdnkbcatedatafransmission/s[oragefaciliry7 Na Contlnue-' 2. I5 this«ude oil sto2ge[ank'lomted at an oil and gas exploration and produc[ion operation,well production faciliry�,naNral gas mmpressor ffation'or na[ural gas processing plant7 Yes Con[inue-' 3. Is this crude oil storage tank a fxed roof storage tank7 Yes;. ;'Go to ihe n . 4. Areuncontrolledactualem'ssons'ofthssto2getankequalioorgrea[erthan6tonsperyearVOC? Yes .?'�;HSourceisst Stoage tank is subject to 4eguietion 7,Seciion](VII,B,C.1&C.3 ' Sec[lon%VII.B—General Provisions for Air Pallution Cont�al Equipment and Preventlon of Emissions Sectlon%VII.C.1-Emissions Control and Monitoring ProNslons SecUon%VII.C.3 Recordkeep ng Aequ rements ''� ''-' 5. Does the crude o I smrage tank ronta n anly"stab Ilzed I'quids?If no,the tollowing addlLonal provlsions apply. __ �Source is s� _ Storage tank is subiect to�Tegulation],SeRion XVII.C.? � SeRion XVII.C.2-Capt�re�and Monitoring io�Storage Tanks fitted with Air Pollufion Control Equipment 40 CFR Part 60 Subpart Kb Standards of Performence for Volat le 02an�c�qwd Stars¢e Vessels 1 Is the nd v dual storage v ssel capac ry greater than or eq�al to]5 cub c meters(m3)[^9]2 BBLs�7 - �Siorage Tar 2. Does[he sto2ge v sel meet the follow ng exemp[on n 60111h(d)�4�? � a.Ooes the vessel has a design capacity less ihan or equal to 1,589.874 m'["10,000 BBL�used tor peVoleum`o ondensate stared,processed,or treated priorto custody iransfer�as defined in 60.11167 3. Was ihis condensate storage tank constructed,reronstr�cted,or modified(see deflnitlons 40 CFR,60.2)aker luly 23,19897 4. �oestheiankmeetthedefinitianof'staragevesseli3in60.111b7 5. Ooes che smrage vessel store a"volatile arganic liquid�VO��i°as deiined in 6�.11367 6. �oes the stoage v sel me=[any one of Ne fallowing additional exemptions: a.I5 the 5[orage vessel a pressure vessel des gned ta operate'n excess of 204 9 kPa[`29 J ps�and w thout em ss ans to the atmosphere(60110b�d�(2��7,or 1 b.The des'gn capac ty s greater Ihan or equal fo 151 m'f^950 BOL�and stores a I qu d w ih a max mum t�ue vapo�p�ess�res less than 3 5 kPa(60 110b(b��;ar �—I c.The des gn capac ry s grea[er[han or eq�al to]5 M3 f`4]2 9BL�bu[less fhan 151 m�["950 B6L�and stores a Ilqu d w N a max mum t�ue vapo�O�ess�re°less Nan 15.0 kPa�60.330b(b�)7 � Stoage Tank is not subject to NSPS Kb SubpertA,General Provisions §60.112b-Emissions Control Standards for VOC §60.133b-Testing and Procedures §60.135b-Reporting and Recordkeeping Requirements ' §60.116b-MonitoringofOpeations 40[FR.Part 60.Suboert 0000,Standards of Perfortnence for Crude Oil and Natural Ges Vrvductlan.Trs�missian and Oistribution 1. Is[his crude oil storage vessel lacated at a tacility In the anshare oil and nahral gas productian segment,natu2l gas processing segment or na[ural gas Iransmission and s[o2ge segment of the indusiry7 '!?s Continue-' 2. Was[his crude oil storage vessel conshuRed,recans[�ucted,or mod'rfied(see definitians 40 CFR,60.2)between August 23,2011 and Septembe�18,3015? 3. Are po[en[ial VOC emissions'from the individual storage vessel greater[han or equal ta 6 tons peryea�? . 4. Does this crude a'I starage vessel meet the def n Hon of'starage vessel''per 60.54307 � 5tarage Tank is not subject to NSP5 OooO Subpert A,Geneal Provisions per§60.5425 Table 3 §60.5395-Emissians Conhol Standards for VOC 4�.`y113-Testing and Procedures §5U.5395(g)-NoUfication,Reporting and Recordkeeping Requirements §60.541G(c�-Cover and Closed Vent System Monitoring Requirements §60.541]-Conirol Oevice Manitaring Requirements � [Note:ltastoragevesselispreviauslyde[erminedtobesubjeRtoN5P50000duetoemissionsabave62onsperyearVO[ontheappliabilkydeterminatlandate,kshe�idremainsub�ecttoN5P50000per60.5365�e)(2) even'rf po[ential VOC emissians drop below 6 tons per year] 40 CFR.Pert 63,Subpert MACT HH.011 and Ges Vroductlon FecIIIHes 2. Is the storage Wnk located at an oil and natu2l gas production faciliry that meets elther of the fallowing criterla: YesOContinue-' a.A facilily that processes,upgrades or stores hydrocar6an liQuids�(63.760(a��2));OR b.A faciliry that processes,upgades or stores natwal gas prior to[he point at which natural gas en[ers[he na[ural gas[ansmission aid storage saurce ca[egory or is delivered to a(inal end user3(63.J60�a)@))7 1. Is the kank loca[ed a[a facility that is majar�for HAPs7 .�'a � s��=�c Storage Tar 3. Ooes[he[ank meet[he defnitian af"sfaage vesseli°in 63.]61? 4. Ooes[he tank meet[he defnition of"smrage vessel with the po[entlal for flash emissions"s per 63.]61? 5. Is the[ank sublect to<ontral requ�remen[s under 40 CFR Part 60,Subpart Kb ar Subpart 00007 Stoage Tank is not subjeR to MACr HH Subpert A,General provisions per§63.]fi4(a�Table 2 §63.]66-Emissions Control5tandards §63.773-Monitoring §63.]]4-Rerordkeeping §63.]]5-fteporting RACT Revlew PAR review is requlred'rf RegulaHan]does no[appiy ANO'rfthe tank is in the nan-ettainment area.If the tank meets bo[h critena,then review RAR requlremeerts. Disclaimer This document assists operators wilh defermining applicability of certain requirements of the Clean AirAct,ils implemenfing regula(ions,and Air Quality Control Commission regulations.This documenf is nof a iule orregulah'on,and fhe anerysis it contains may nol apply to a particular situation based upon fhe intlivitlual facts and circumstances.This documant does not change or substitule for anylaw, regulafion,or any ofherlegally binding requiremenf and is nof legally en(orceable.In tha evenf oiany confiicf between fhe language ot fhls document and the langua9e o/the Gean AirAct„its � implemenfing regulations,antl Air qualiry Confrol Commission reguletions,the/anguage of the sfatute or regulation vnll rontrol. The use of non-mandamrylanguaga such as'recommend,""may," 'should,"and°can,"is intanded to descn6e APCD interpretations and racommendations.Mandafory ferminology such as"musY'and'required'a`e intended to desenDe confrolling raquirements under the terms o/fhe Ciean/UrAct and Air Quality Control Commission regula(ions,bu!this document does no(esta6lish fegalry 6inding requirements in antl ofitsel/ Separator Venting Emissions Inventory 004 Separator Venting FacilityAlRs ID: Y23 . 9F77 , „� 004 - � County Plant Point Section 02-Eouioment Descriotion Details Ftaringassociatedgar#rvm��-pF�esese(taretorsendj�}'3-phaseheatartreerers �-"--' "� �' Detailed Emissions UnR Description: .�� Bpen Piare during YRl3�osveUme �' �' ' Emission Control Device Description: , _ . ... . ...,:.:...: .: , ,,,.. , .: . '; Reques[ed Overail VOC&HAP Conirol Efficiency%: 9S�: � Umited Process Parameter (Ya;itc��6`as4�ertLed.:�� ,•��°'� -�_, Gasmeter 'le.,r., :.,>�,..aa�Y3:��Y,^��Yfj;t��;��nd�apqnal�� Section 03-Processine Rate Information for Emissions Estimates Primary Emissions-Separetor ActualThroughput- �� 209.S��MMscrperyear � RequestedPermitLimitthroughput 2�3�..S.MMscfperyear RequestedMonthlyThroughput= 18 MMscfpermonth PoteniialtoEmit(PTE)Throughput= 209 MMscfperyear Pracess ConVol(Recycling) Equipped with a VRU Y25 " Is VRU process equipment 'fes �w�rw�,��Umm�irolled and controlled emissions uszd m establish requesied permit Iimits are 6ased only on when ihe VRU is hypassed�i.e.waste gas volume ihat is routed to the flare) Secondary Emissions-Combustion Device(s)for Air Pollution Control SeparatorGas Heating Value: lA1&.;Btu/scf 1289 Volume of waste gas emit[ed per BBL of liquids throughput: sd/bbl Section 04-Emissions FaRors&Methodoloeies �e5c�ipti0n .. . . ,,; , . ,��. _: ' 6assample analyss from the com6 zedsepaamrs e sion sheem �, ,., '� " "�- ' "� MW �S,11Ib/Ib-mol DisplacementEquation Ex=Q3MW'Xx/C weight% Helium � � 0.0000�: CO2 4.494� N2 1.0707 methane 4?,5230. ethane � iu 6G31'�. pro ane � 13.7142�� isobutane � 23148'�. . � n-6utane 7�:aa22� - isopentane 1.6U32�� n-pentane � � Z.U743 � cyclopentane �1133� n-Hexane � 0.5113. cycbhexane 0.0671�� Otherhexanes � O.E669 heptanes 0:9&52 methylcyclohexane �� 4 1230' 224-TMP ��. D U159�: Benzene ��.U�.OaS7 Toluene 0.1097 Ethyl6enzene D.0413 Xylenes �O.OSQ2�� C8+Heavies 0�.3732�� Total 9.99fi6 VOC Wt% 3G.?�175 Emission Factors SeparatorVenting Uncontrolled Cantrolled EmissionFactor5ource Pollutan[ (Ib/MMscf) (Ib/MMscf) (GasThroughput) (6asThroughput) VOC 24015.164 1200.758 �: FxYettded�asarzEy�s � Benzene 30.278 1.514 ��. �xFe�ukrFgasarz�€gsa ��. Toluene 72.680 3.634 ��. Exttrafed,;as�a€�s�.,: .! Eihylbenzene 27.363 1.3fi8 ��. `ckEe[tdeilgatio�a€y5s '��. %ylene 33.259 1.663 �� rTild�dr.&5 ana€�}5 n-Hexane 33H.753 16.938 ��. �„(L844dCtf�d5a+ta[ys€i' '� 224TMP 10.534 0.527 -��. Exke�2des€� a.�€yst"� �'�. Primary Conirol Device ' . Uncontrolled Uncontrolled Pollutant (Ib/MM6tu) Ib/MMscf EmissionFactorSource (Waste Heat Combusted) (GasThroughput) PM10 � 0.000 PM2S � 0.000 SOx 0.000 NOx ��0.0680 96.288 ,�•24;:-�sfuix3,s�ki}i,s�nate��€�s{LFrk) CO ��.3106 399.590 P.P�-82.€f77E LdT3.S.S�t�ldUStSL-�F�#R:CK�£f�.}ir; 14 of 26 i:\Oil&Gas Pu61ic Notice\17WE1222\17WE1222.CPLPA.xlsm Separator Venting Emissions Inventcry Section 0S-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Cnteria Pollutants Uncontrolled Uncontrolled Controlled Umm�trolled Controlled Conirolled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) Qbs/month� PM10 0.00 0.00 0.00 0.00 0.00 0 - PM2.5 0.00 0.00 0.00 0.00 0.00 0 SOx 0.40 0.00 0.00 0.00 0.Q0 0 NOx 10.08 10.08 10.08 � 10.08 10.fl8 1713 VOC 2515.11 2515.11 125.76 2515.11 125.76 21361 CO 41.85 41.85 31.85 41.55 41.85 7109 Potential to Emit Actual Emissions Reques[ed Permit Limits HazardousAirPollutanis Uncontrolled Uncontrolled Controlled Umm�trolled Controlied � (Ibs/year) (Ihs/year) �Ibs/year) (Ihs/year) �I6s/year� . � 8enzene 6342 6342 317 6342 317 Toluene 15224 15229 761 15224 761 Ethylbenzene 5731 5731 287 5731 287 Xylene 6966 6966 348 6960 348 � . n-Hexane 70955 70955 3548 70?55 3548 224 TMP zza� zzo7 iio z2o� 110 Section 06-Reeulatory Summary Analvsis Regulation 3,Parts A,B Source requires a oermit Regulation 7,Section XVII.B,G Soorce is suhjecE to Regulation 7,Section XVII.8.2,G Re ulation 7,Section XV11.B.2.e The control device for this separator is subjectto Regulation 7,Section XVII.6.2.e (See regulatory applicability worksheet for detailed analysis) Section 07-Initial and Periodic Samoline and Testine Requirements Using Gas Throughput to Monitor Compliance �' a`�� i � Daes the mmpany use site specific emission fac[ors hased on a�as sample to estimate emissions? 't,,N&; _ This sample should represent the gas outlet of the equipment covered underthis AIRs ID,and should have 6een collected within one yeer of the application received date.However,if the facility has not 6een modified(e.g.,no new wells hrought on-IineJ,ihen it may 6e appropriate to use an older site-specifc sample. If no,the permR will mntain an"inttial Tes[ing Requiremeni"to<ollect a site-specifc gas sample from the equipment being permitted and conduct an emission factar analysisto demons[rate that the emission factors are lessthan or equal to the emissions factors estahlished with this application. Are fac�lity-wide permitted emissions of VOC greaterthan or equal to 90 tons per year? y�g; s � _6 If yes,the permit will contain: , . -An"Initial Testing Requirement"to collect a site-specific gas samplefrom the equipment 6eing permitted and conduci an emission factor analysis to demonstrate that the emission fac[ors are less than or equal to the emissions factors established with this application. - -A"Periodic Testing Requirement"to coilec[a site-specific gas sample from the equipment being permitted and conduct an emission factor analysista demonstrate that ihe emission factors are less than or equal to the emissions factors established with this application on an annual basis. Will the operator have a meter installed and operational upon s[artup of this point? . Yes ff nq the permit will contain a condition that requires the operatorto calculate gas throughput usingthe liquid throughput until ihe meter is installed and operational(not to exceed 180 daysJ.This condition will usethe"Volume of was[e gas emitted per BBL of Iiquids throughput"(sd/bbl)value in section 03. Does the company request a cantrol device effciency greater than 95%for a flare orcombustion device? „�� „r��F�� It yes,the permit wiil contain and initial compliance test condition to demonstrate the destruction effciency of the combus[ion device based� on inlet and outlet concentration sampling You nave indicated above that tfie monitored precess parameter is natural gas vented.The following questions do not require an answer. 15 of 26 I:\Oil&Gas Public Notice\17WE1222\llWE1222.CP?.PA.xlsm Separator Venting Emissions Inventory Sevtion OS-Technical Analvsis Notes - � i,.;� i, :"", { 3 � ��- � 3,: ,,,"33 „ ,,,s , ,,, . . . ,f. .. , ;,,, „ ,. �„� ., . - .. �,..,.. � :�� -�, , .� ._a .,,,,, � � . . . ,,,,,,,: Section 09-Inventory SCC Codin¢and Emissions Factors Umm�tralled Em ssions AIRS Point# Process# SGC Code Pollutant Factor Control Y Units 004 Ol 3-i0-00'i-&0 rlares PM10 0.00 0 Ib/MMSCF PM2.5 0.00 0 Ib/MMSCF SOx 0.00 b I6/MMSCF ' NOx 96.29 0 Ib/MMSCF VOC 24015.16 95 IbfMM5CF - CO 399.59 0 IbfMM5Ci - Benzene 30.25 95 Ib/N7MSCF Toluene 72.68 95 Ib/MMSCF Ethylbenzene 2736 95 16/MMSCF %ylene 33.26 95 Ib/MMSCF n-Hexane 338.75 95 IbfMM_CP 224 iMP 10.53 95 Ib/MIYi5CF - _ � 16 of 26 I:\Oil&Gas Po61ic Notice\37WE1222\17WE1222.CP1.PA.xlsm Separator Venting Regulatory Malysis Worksheet ColomdoRe uleNon3ParesAandB-AGENandPermltRe Wremenss Source is in the Attainmeni Area A7TAINMEM 1. Areuncontrolledac[ualemssonsfromanyarterapollutan4fromths ndvdualsaurcegreater[han2TPY(Regulaton3,PartA Sectonll.D.l.a�? Y¢5": :S cefteq 2. Fretotalfaclityuncon[rolledVOCem-ssonsgreaterthan5TPY,YOxgreaterthanlOTPVorCOemissonsg�eate�thanlOTPV(Regulat�on3,Part05ecLonll.D.3�7 Y2S�; .:SourceReq Source requires a pemit NON-ATfA1NMEM � 1. Areuncontrolledemissiansfromanycriteriapollutantsfromthisindividualso�rcegreaterthanlTPY�Regulation3,PartA,5eRionll.D.l:a�7 2. A�e total facillry uncontrolled VOC emissions tram[he g�eater than 2 TPY,NOx g�eate�than 5 TPY or CO emissions greate�than 10 TPV�Regulation 3,Part B,5ection II.D.2)7 You hav indica:ed ihae sourte is in the Attainment Area Colondo ReeulaHon 7 Sectian XVII 1. Was the well newly consiructed,hydraulicalW trac[ured,or reromplered on or aRer August 1,2014? YM"S -Source is si Sourte is subjettto ftegulaiion],Section%VII.B.2,6 Sectlon XVII.B.2—General Provisions for Air Pollu[ion Control Epuipmen[and Preventian ot Emissions Secdon%VII.G-Emissiore Gontral AlLemeHve Emiuions Conhal IOotianal SecHonl a. Is this sepaator controlled by a back up or altemate mmbust�on devi ce(I.e,not the pnmary conVol devi ce�that is not en<losed? YEs,.i�z The control The control device for this seperator Is sublett to Regulation],Settian XVII.B.2.e SeRion XVII.8.2e—Altemative emissions control eq�ipment - Disclaimer This documenf assists operators with dete�nining applicability of certain requirements of the Clean Air Acl,its implemenfing regulations,and AirQuality Control Commission regulafions.This documenf is not a rule or regulation,and Ihe analysis il contains may not apply to a particular sf"tuallon basetl upon the individual facts antl circumstances.This tlocument tloes nof change or subsG'tute(or any law, regulation,or any otherlegally binding requi`emen[and is not legally en(orceable.ln!he even!ol any conflict between the language o/this documenl and the language ol fhe Clean AirAct„its implementing re9ulafions,andAi�QualityControlCommissionregulations,thelan9uageofthesta(uteorregulationwillcontrol. Tneuseofnon-mandaforylanguagesuchas'recommand,"'may,"'should,"and'can."is infended fo descnbe APCD inferprafafions and recommendations.Mandafory[ertninology such as'musY'and'required"are intended fo descnbe controlling requirements underthe teRns of fhe Clean Air Acf and AirQualityConfrol Commission iegulaGons,buf this documenl does not esfablish lagally 6inding requirements in and olitsell oos Engine Information En ine date of mf 4/19/2017 Manufacturer: Cater illar Model Numbec G3516J Serial Number: N6W00180 En ine Function Com ression Derating Mf 's Max.Rated Horse ower sea level: 1380 Horse ower used for calcuations: 1380 BSCF 100%LOad btU/h -hf: 7443 Site-Rated BSCF 100%load btu/h -hr: 7443 En ine T e 4SL6 Other Parameters As iration turbo-char ed Electrical Generator Max Site Rating(kw) 0 Max hrs/r of O eration 8760 Calculations Fuel Use Rate 100%Load �0069.94118 scf/hr ACTUAL Annual Fuel Consum tion 0 MMscf/ r nnua ue Consumption 88.213 MMscf/ r REQUESTED Annual Fuel Consum tion 88.213 MMscf/ r Fuel Heatin Value 1020 btu/scf Emission Control Information This engine shall be equipped with an oxidation catalyst and air-fuel ratio control Emissions Surnmary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolied Emissions Controlled Emissions NOx 0.900 /h -hr 0.900 /h -hr 12.0 t 12.0 t CO 2.430 /h -hr 1.000 /h -hr 32.3 t 13.3 t VOC 0.700 /h -hr 0.700 /h -hr 9.3 t 9.3 t Formaldeh de 0.430 /h -hr 0.290 /h -hr 11436 Ib/ r 7713 Ib/ r Acetaldeh de 0.008 Ib/MMBTU 0.008 Ib/MMBTU 752 Ib/ r 752 Ib/ r Acrolein 0.005 Ib/MMBTU 0.005 Ib/MMBTU 462 Ib/ r 462 Ib/ r Benzene 0.000 Ib/MMBTU 0.000 Ib/MMBTU 40 Ib/ r 40 Ib/ r 17W E1222.CP1.PA.xlsm Source Manufacturer Manufacturer Manufacturer AP-42 AP-42 AP-42 AP-42 17 W E1222.CP1.PA.xlsm 006 Engine Information En ine date of mf 4/19/2017 Manufacturer: Cater illar Model Number: G3516J Serial Number: N6W00189 En ine Function Com ression Defating �f 's Max.Rated Horse ower sea level: 1380 Horse ower used for calcuations: 1380 BSCF 100%Load btu/h -hr: 7443 Site-Rated BSCF 100%load btu/h -hr: 7443 En ine T e 4SL6 Other Parameters As iration turbo-char ed Electrical Generator Max Site Rating(kw) 0 Max hrs/r of 0 eration 8760 Caiculations Fuel Use Rate 100%Load 10069.94118 scf/hr ACTUAL Annual Fuel Consum tion 0 MMscf/ r nnua ue Consumption 88.213 MMscf/ r REQUESTED Annual Fuel Consum tion 88.213 MMscf/ r Fuel Heatin Value 1020 btu/scf Emission Control Information This engine shall be equipped with an pxidation catalyst and air-fuel ratio control Emissions Summary Table Pollutant Uncontrolled Emission Factor Controiled Emission Factor Uncontrolled Emissions Controlled Emissions NOx 0.900 /h -hr 0.900 /h -hr 12.0 t 12.0 t CO 2.430 /h -hr 1.000 /h -hr 32.3 t 13.3 t VOC 0.700 /h -hr 0.700 /h -hr 9.3 t 9.3 t Formaldeh de 0.430 /h -hr 0.290 /h -hr 11436 Ibl r 7713 Ib/ r Acetaldeh de 0.008 Ib/MMBTU 0.008 Ib/MMBTU 752 Ib! r 752 Ib/ r Acralein 0.005 Ib/MMBTU 0.005 Ib/MMBTU 462 Ib/ r 462 Ib/ r Benzene 0.000 Ib/MMBTU 0.000 Ib/MMBTU 40 Ib/ r 40 Ib/ r 17W E1222.CP1.PA.xlsm Source Manufacturer Manufacturer Manufacturer AP-42 AP�2 AP-42 AP-42 17W E1222.CP1.PA.xlsm Separator Venting Emissions Inventory 005 Separetor Venting FacilityAlRs ID: 1?3 , 9E77�� , 047# . County Plant Pomt� Section 02-Eouioment Description Details � _ _....... ........._ ....._. ____. _.... _.._.. ......... ...__. __._ ...._.._...... Vapor$ecoveryToy,vers- Detailed Emissions Unit Description: _ .. , ,,, , „ Open Flares dutEng.'vapoF�re�oeeEy-downtlme r ' ; Emission Control Device Description: - -'� � . �� " " .. .: - , . :._...,. --- -- Requested Overall VOC&HAP COMroI Efficiency%: 95 �� LimitedProcessParameter &�3�S�`�� y�,;i �_,,,, s,�;p,,,:' . Section 03-Processin¢Rate Information for Emissions Estimates Primary Emissions-Separator ActualThroughput= ��229,9S0,0'Barrels(661�peryear 1642500 ' Requested Permit Limii Throughput= '��.. 229,95tl.0��:Barreis(6h1)per year Reques[ed Monthly Throughput= 1953o MMscF per month Potential to Emit(PTE)Throughput= 229,95o Barrels(bbl)per year Pracess Control(Recycling) Equipped wRh a VRU ;+es � . Is VRU process equ pment ges "; .�Umm�trolled and mntrolled emissions used to establish requested permit limits are based only on when the VRU Is hypassed(i.e.waste gas volume that is routed to ihe flare) Secondary Emissions-Combustion Device(s)for Air PoltuNon Control Separator Gas Heating Value: 27.52,;Btu/s6 1977 Volume of waste gas emitted per BBL of liquidsthroughput: 3.3 6!,sd/661 Sec[ion 04-Emissions Factors&Methodolo¢ies Description MW ' �.��3&.8'�.16/Ib-mol DisplacementEquation Ex=Q'MW'Xx/C Weight% Helium OAO CO2 2.40 N2 0.36 methane �7?�.02 ethane �� 15:11� propane 28.53�. isobutane 3.Fr5 n-butane 15-17'�. - isopentane 3,9I1 n-pentane � .S125 � cydopeMane n-Hexane �3;40 cyclohexane Otherhexanes 4.51'�� heptanes '�2:71. methylcyclohexane 224-TMP - U 1& eenzene �� O��:Sfi Toluene 02?fi Ethylbenzene 0.03 Xylenes 0.05 ' C8+Heavies � 0�:72�� Total 100.00 VOC Wt% 70.11 Emission Factors Separetor Venting Uncantrolled Controlled Pollutant (16/6b1) (Ib/bbl) EmisslonFactor5aurce (LiquidThroughput) (LiquidThroughput) VOC 0.9761 0.0488 Benzene 0.0078 0.0004 Toluene 0.0036 0.0002 Ethylbenzene 0.0004 0.00002 %ylene 0.0007 0.0000 '�, n-Hexane o.0473 0.0024 �� '� '�. J w�y �. 224TMP 0.0022 �.0001 �'�� y� ,��F„��,. . �../ �' Primary Control Device Uncontralled Uncontrolled Pollutant (Ih/MMBtu� Ib/bbl EmissionFactarSource (Waste Heat . Comhusted) (GasThroughput) PM10 0.000 PM2.5 0.000 SOz �� 0.000 NOx �9.U686 0.002 .'-:�-�.�£[sA!)9ttr13"r,lCi��57:s�ay�a3Lt�kUu} ' 22 of 26 I:\Oil&Gas Public Notice\17WE1222\17WE1222.CP1.PA.xlsm Separator Venting Emissions Inventory co osioo o.00a �-4ai:hnpte,r�."�t��it'��fC�}t��1,�'�„. 23 of 26 I:\Oil&Gas Public Notice\77WE3222\37WE1222.CP1.PA.xlsm Separator Venting Emissions Inventory SeRion OS-Emissions Inventory Potential to Emit Actual Emissions Reques[ed Permit Limits Requested Monthly Limits Criteria Pollutants Unconirolled Uncontrolled Conirolled Umm�trolled Conirolled Conirolled (ions/year) �tons/year) (tons/year) (tons/year) �tons/year) Qbs/month) PM10 0.00 0.00 0.00 0.�0 0.00 0 PM2.5 0.00 0.00 0.00 0.00 0.00 Q . SOx 0.00 0.00 0.00 0.00 0.00 0 NOx 0.23 0.23 0.23 0.23 0.23 39 VOC � llLZ3 112.23 5.61 112.23 5.61 953 CO 0.96 0.96 0.9G 0.96 0.96 163 Potential to Emit Actual Emissions Requested Permit Limiis HazardousAirPollutanis Umm�trolled - Uncontrolled Conirolled Un<onirolled Controlled (Ibs/year) (Ibs/year) (Ibs/year) l�bs/year) (16s/year) Benzerte 1301 1807 90 1801 90 Tolu�en�e 822 322 dl 322 41 Ethylbenzene 9U 90 4 9a 4 Xylene 156 156 8 156 8 n-Hexan�e 10877 10877 544 10877 544 224 TMP 502 502 25 502 25 Section06-Re ulato Summa Anal is Regulation 3,Parts A,B Source requires a permit Regulation 7,SecYion%VII.B,G Source is subject to Regulation 7,Section XVII.8.2,G Regulatio�n 7,Seaion%VII.8.2.e 7he control device for this separator is=_ubje<t to Regulation 7,Section XVII.8.2e (See regulatory applica6ility worksbeet for detailed analysis� Section 07-Initial and Periodic 5amplin¢and Testin¢Requirements 4ou nave indicat�d a6ove che monitored nrocess parame[er is Liquid ThrougpuC.ing foliowing auescion does nat roqiiire�n ansvrer. y .1/ l l l ;( (' ( � P//r�/�l lfff�'' .f� lr"j/(r° ff9f�'f f/ l / r l ��,r� . � '�#°;��r�,.� , _r r��;r,,�.., '��,fi�� sf�f�C�lr��/f�f%`r�'ll.�%lf��✓,i/if�� /�1.Yf i f?'�.�.,.,','�%� ��%` %!flf/��,��. � ��`.� f f� ✓� r��jl�% :11�':r �l�'l�-✓D��,y-�,��i"��/��..r f,u'' . �,��'`✓'..�f�/ .�,r� l��i� f �.�s.�/ -�� ,"'Gy, � J ., T/ I� -� l� '� "`yy�� S r r-x'�%' ��.� � l' fi� ,;�� m/r� f �#la� v�se� . �efcx��,47� �'s��a��£�`'�tT.%a�3��r�� l f'�.�1 � .� r� �� ,,; � � ✓ r� ri;✓.;ri� ,✓i '. Ii//� �i / ��ii?f�l rr✓ �f' rl��.� �� f �i ..�f� �� .�-r��r ��a� �x�! �.� � c��r�- ��,1 r�,�r �� ,�— r /l�- %ee�e a/ � ��-� ��/ i/" / �� /O/ �/i/ ! � �i:��//� %///6� %i� ; j^^� e�s35 �fj-' �sr-�Ybax ,�-�ii�� "��y x �J-�'la/��`�r�l �r ��f,rl�l� i�� i1�f �f��i°� �✓If r: � j/�� ,.� .�r��. � �r�1� -�j��j�l. yri��,i% ,� J r � i f f / � 1' i l � � 'l ��, ,r�`ij///, 1��;%r rrlr��j.:f1 �%f�.�%/�i��i'f`�rf'�✓/ r/ !.f��f�is'i��fr:,"��°i ._:�� .�, � ;� � � �„ �,. �l�; �t��,f�;��.:ir� � fl il �/��f��i�' „i�'l '' � ,�fs�ji��' 1��'//r/rl ��fr �,fi�,�i/j l�l f%f"`�� /�� f�� rj�y r�� r�, Y��'Ffi� � � � /� �r�'./�,f n ar��s;'E //� /,rlf ,/ij�,, //� /i'-., -� /� ,..//,� ,i�i�if�ii,�.:.:"'ii��.:/// �/il� f �� /l l lr lGl -'lrr r��. �:� .lr �" �l l�r,/G" l ! /r�" � �l� t� r�� 4�� j �%%�� ,/ � /�� r�,�r�,��✓1� r�,.., ��i� ' �,� � , ��f 1�.�„��1,%��/yi;�' 1;,:�l'r�- r ;' ��1��r,W'��/�'� n�U �Jl�,�� , . � ;�� -��+� � ;� �� 11'��i�,;%1-,�. �i �/��i,�fi �;� ,,�� ll'. i�� r G �,;Ir ,.l c/� l�if r�� '�/t ��,� /as, l,ra, ,-'�r, � r�{� ��., � ,-fE �� d�- ,i�i liri fi tl, ✓/i:. /�f l;�i�i'�,��l,, �fi�,�fil ,��1�:?�1 /�y'j�„ � ,� <-/,l�Q--: �� r„ ,_ lrr,/�r��,r��y1� �i �r r„/�,.�r�r .�� l r� j,�rr� �� t/lr� � �r��o��x r % �aE�` a �"` ,ocss.i a uK rr ��c utu;a �v�' dt sr' a t,sf��s�2 .�rt�/ � / i ��ljJj��.✓f#�' ,,a'�.:.�iia`„i ��"ii� �or:�.,. �l�"`i�;:�,..,o�.'�.�i1,3�'�ql,�, i��',i? i��ai�� ,,.''�/��'if.�,. '�jl��,J/ i�..%%o,�l ,-.�i�j/� ��,;�r��atfiai�sxsar .#� tke � a�,aast��flttE,�-; i �� . %� ./�/ / rai -./� � O�/%�/ � i� , / / il� � �i / i .i l� /�, , �'�`�-�/�l r � �.� ✓��l�l /rrlf,. l /iy, �� -r� ir l � l �� , .,�,�. i;ll� /� /rf/ -a%/ ,�fi �l�.�; //, �r,//j ,./ ✓�//� % l:..iir��/� ' I�r'�/��r = Cl� il,��„�'�'/,, ,,,1„ �:'I��, �irf �.-.,��Il�'i,''1//,'�,��, i,r::°� %� ;�'�/%;r;,;��.,,%�%��,��1�%i�%�I�� '�.i�%�f.F:��.,l�ilrfl��'�%1�::.�,��.,., l /GtZ �/ ��;��es�,�,/� �r�� C��.�i:l-�i a �#t°�ri i��;�'",: �:�1 � sr� t��fsc��'�`�irris ��"��:i�% f�� ds4>rs� : i,,r�r�a� .�`,��`eH^xu�' � -ts �,..% ��c�crl �r .� ,� 1 .��,ir�r r��1� lllr � r�' ; ...��, <. .,� � �r r.�� , ., ��'�"" .,,... ,3"rr �� '�/ �o'/f��l %r�r 'Ti,r// �.�� y , �� J �}�i� : i l� ii s r .�1 �so J y�,/� ;�%��?�l�i%� rr �trra �iii�r7 �. lr�� ;%/' .;, i ;,,i� i �i /l/.;.,jf .��% /.�j i �i/" Q �/ / /� / i�/I / ��.�� r,, h,. /f ,.;,..��m�lrari.�� .�r,:��.., ,�rl�;�, ,lllr' ;.l.��/�!. �, �/r ,:�.�.�//�� .j��Rs,,,/�j � �.A��. ��5:��l ��/-.�r� ;�r1, ��j 'r�%,�rE/a. .awr.� /�+,�� lJ. Y� ,#X/O� ��rl�/�✓%•ffe�iti , �//1/��'✓ 'i�,tr��j � ��,r�'` . �:'�,I�'7 ` � '� � � j�'�%`l'�� I,� ,.11 ,�il�� -� �r"��;i% .� �ii ii i � a ::,i/% i � ii i� : rrir i iii // Hi ii a// �i/�,a .�fip/�� /� /r�!�j % ��r � %;�,�e+krn,Fi � +�i`Ero�c � '?�� ax,€s �4,�. �� ✓,�ik'"a� � fi',fiE y�w,�l,, � �i // / - i �i/ /� .. /�� / /"-.i / r� r^D�/ r � ��r�� j� .� ��3�a �3�s�s��A�� ".`.. �� l f�r l�!f�� .�fi'i..r I�'��l%�� .,:,,��n rY��s;��'.�, �r � � ,;-;i� „q„��/lrr,l,r ��.:��'� .�f l�yf l i�,.f��-1 h ��-�%i%�'y /l O /��%�� / ij,i''�f .:��i i �� .✓ /f l.i r .r,%Ji� � y�i l l,l,i D � �;1�j�� .,��f l,�r.'.��.,�,.�'✓l . � jli�.,� f��-� lr�f/�� .�lf /��.1 ��/ .:��,:�1//r,li !(-� ,/l,/� '.��/l.rr,�� f �� ..J. ��f � ��, #.' t� �b�'�� t..�rt� �tk� n�'`� a"�� S� e O �� / �/ O/' / �✓F�I / 1��. � � lll �s1 �fi � �li� �.ry � ��l�r y 6'� J/ r �f/ lf'�A�."��/� �////� i�/ f r // '�„��l r l, . ,, ��` ��, ri�� .rf'� �/,./��' ff� �'?` ��itcv,l��EtC,�sx� x�rk�1'ra �g.�'��:�a:t� Y � {�i�` dY.� � f �j/fi� / .� i , f�-, s. � :r'i !i's /O �. �.r�j, ✓r!/ r��j.;',,,�� J�i�r%i',. % �/fl �:/i�r ,.i �f/:�'�/�� o� ��c y?��&�ac�r �,�r,��` �j � �� 1� f '� �;/j r ,i� ih. �/�r �.: l,s'7f � i�✓:,�t� � :�f1J��,,,�.�� „�,,,�r,,:,,�l lc��l��r,<..�.��.,... �1,,,,��nt._ .,sn�.;,,�l�,�r,�`.,,,,,�rfl�j,,,,�s'.:�.� .,.. .,..&f��,,,,�.u�..,�,;�1.�C�C!�„�,1�,. .. ,.,.;�,..iif�� Using Liquid Throughput to Monitor Compliance Does the company use site specifc emission factors based on a pressunzed liouid sample(Sampled ups[ream of the � equipment covered under this AIRs ID)and pmcess simulation to estimate emissions? �B� ��:,e This sample should have heen milected within one year ofthe application received date.However,if the facility has not been modifed(e.g., no new wells 6rought on-linej,ihen it may be appropriate to use an older site-specifc sample. If no,ihe pertnit will mntain an"Initial Co�mpliance"tes[ing requirement to collect a site-specific liquid sample and ronduct an emissim fac[or analysis[o demonstrate that the emission factors are less than or equal to the emissionsfactors es[ablished with this application. Does the company request a mntrol device efficiency greaterthan 95%for a flare or com6us[ion device? ,„ ' _ ��-��: ,a„, .,,.,........ ......................... If yes,the permit will rontain and initial compliance test mndition to demonmate the des[ruction effciency ofthe com6us[ion devire 6ased on inlet and outlet concentration sampling 24 of 26 I:\Oil&Gas Public Notice\17WE1222\17WE1222.CPLPAxIsm Separator Venting Emissions Inventory Section OS-Technical Anal sis Notes Section 09-Inventory SCC Codin¢and Emissions Factors . Uncontrolled Emissions NRSPoin[# Process# SCCCode Pollumnt Fac[or Control% Units 007 Ol S-'10-0�1-29 Oil&Gas Production:Gas/liqui�separation , PM10 o.a0 0 16/700066t PM2.5 0.00 0 Ib/3o0o661 SOx 0.00 0 I6/10006b1 NOx 1.99 0 Ib/10006b1 VOC 976.15 95 Ib/1000661 CO 8.34 0 Ib/1000661 Benzene 7.83 95 Ib/10o0661 Toluene 3.58 95 Ib/1000661 Ethylbenzene 0.39 95 IbJ1�006b1 Xylene 0.68 95 Ib/IOOOb61 n-Hexane 47.30 95 16/1�00661 224 TMP 2.18 95 Ib/1000661 25 of 26 I:\Oil&Gas Public Notice\17WE1222\17WE1222.CP1.PA.xlsm Separetor venting Regulatory Malysis worksheet Colondo Re uleHan 3 ParFs A and e-APEN and Permi[Re Wremenss AITAINMENT�ource�s n the Attainment Area 1 Areunconcrolledactualemssons-romanycrterapollutantsframNandrvdualsourcegreaterihan2TPY(Regulaton3,PartA,5ec['on1I01.a�7 YES - -5 refteq 2. Are total fac'IiN unconholled VOC em ss ons greater than 5 PY,NOx greater than 10 TPV or CO em ssbns greater than 10 TPY(Regulahon 3,Part 0,Section II.D3)7 Yes� Source Req NON-ATiAINMEMrce requims a permit 1. Areuncon[rolledemi5sion5fromanycriteriapolluWnufromlhi5individualsourcegreaterthanlTPV�Regulation3,PartA,5ec[ionll.D.l.a�7 2. Are[o[al facillty un ont�olled V�C emissions from the g�eate�than 2 TPV,NOa greaterthan 5 TPY o�CO emissions greaier than 10 TPY(Regulation 3,Part B,Sec[ion II.D.2)? You have'nd'cated that seurce is in the Attainmenf Area Colorsda Re¢uletlon].Section%VII � ''' ' 1. WasShewellnewlyconshucted,hydra�licalWfrac[ured,orrerompletedanorafterAugust1,2014? _ ��5 urceiss Source'ssubjetttoPeg�lat'onJ Sect'on%VII82 G � SeRlon%VII.0.2—General Provisions(or Air Pollu[ion Conhol Equipmen[and Preven[ion of Emissions ' . SeRionXVII.G-EmissionsCanval AltemaHve EmissionsCon[ral(Optional5ec[lon� a. Is ih�s separator con[rolled by a back up or altemate combust on device(.e,not the pnmary control devi ce)that's nat=nclosed� _ 4e5'.i;: --7he control Thecaniroldev-ceforth�sse0erator'ssubjettto4egulalion7>e on%VII.B.2.e � Secclon XV11.8.2.e—Flternative emissions cantrol equipment Oisclaimer This documenf assists operators wifh defermining applicability of certain requiremenis of the Clean AirAct,its implementing regWations,and Air Quality Control Commission regulatiorts.This document is nof a ru/e orregulation,antl(he anatysis if contains may not appty to a particu/ar siivation based upon(he individual facts antl circumsfances.This documenf does not change orsubstitute for any law, regulafion,or any othe�legalry bintling requirement and is nof legally enlorceable.In!he event olany confiicf belween Ihe language oi Ihis tlocument and the language o(the Clean AirAct„its implemenfing regula(ions,andAtrQualiryConirolCommissioniegulations,thelanguageoffhesfatufeorregulafionwiilcontrol. iheuseofnon-mantlatorylanguagesuchas'recommend."may,""should,"and'can,"is infended ta descnbe APCD interprelafions andrecammenda(ions.Mandafary tersninology such as'musl"and'required"are intended fo descnbe controliing requirements underthe terms of the Clean Air Act and Air 4uality Control Commission regulations,buf fhis documenf does not establish legally binding requirements in and ofdself Permit number: Date issued: Issued to: COLORADO Air Pollution Control Division Department of Public Health & Environment CONSTRUCTION PERMIT 17WE1222 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Whiting Oil and Gas Corporation Horsetail 07 East CPB 123/9F77 NWSE SEC 7 T10N R57W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description PW 01 through PW- 06 002 Six (6) 400 barrel fixed roof storage vessels used to store produced water Enclosed Combustor This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) COLORADO Air Pollution Control Division Page 1 of 8 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO PW-01 through PW-06 002 --- --- 4.9 --- Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis. 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 are defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. COLORADO Air Pollution Control Division Page 2 of 8 8. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled PW-01 through PW- 06 002 Enclosed Combustor VOC and HAP PROCESS LIMITATIONS AND RECORDS 9. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit PW-01 through PW- 06 002 Produced Water throughput 4,380,000 barrels The owner or operator shall monitor monthly process rates based on the calendar month. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. 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) 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. This flare must be equipped with an operational auto -igniter. 13. The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons except where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to COLORADO Air Pollution Control Division Page 3 of 8 the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. 14. The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Section XVII.C.2. OPERATING a MAINTENANCE REQUIREMENTS 15. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 16. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements 17. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 18. A revised Air Pollutant Emission Notice (APEN) shalt be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO.) in ozone nonattainment areas emitting less than 100 tons of VOC or NO,t per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 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 application for the Operating Permit is COLORADO Air Pollution Control Division Page 4 of 8 due within one year of the earliest commencement of operation of any piece of equipment covered by this permit. 20. Federal regulatory program requirements (i.e. PSD, NANSR) shalt 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 Vet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS 21. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation 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. 22. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation 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. 23. 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. 24. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 25. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the 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. 26. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 27. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. COLORADO Aix Pollution Control Division Page 5 of 8 By: Christopher Kester Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation COLORADO Air Pollution Control Division Page 6 of 8 Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https: // www.colorado.gov/ pacific/ cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (Ib/yr) Controlled Emissions (Ib/yr) 002 Benzene 71432 2027 101 Toluene 108883 935 47 Ethylbenzene 100414 74 4 Xylenes 1330207 148 7 n -Hexane 110543 12086 604 2,2,4- Trimethylpentane 540841 445 22 Note; All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 002: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 0.043990 0.002200 Site Specific Flash Liberation Analysis 71432 Benzene 0.000463 0.000023 108883 Toluene 0.000214 0.000011 110543 n -Hexane 0.002759 0.000138 540841 2,2,4-Trimethylpentane 0.000102 0.000005 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to COLORADO Air Pollution Control Division Page 7 of 8 the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This facility is classified as follows: Applicable Requirement Status Permit Major Source of: t VOCOperating Synthetic Minor Source of: HAPs PSD Synthetic Minor Source of: V0C 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 Page 8 of 8 CDPHE Permit number: Date issued: Issued to: COLORADO Air Pollution Control Division Department of Public Health b Environment CONSTRUCTION PERMIT 17WE1223 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Whiting Oil and Gas Corporation Horsetail 07 East CPB 123/9F77 NWSE SEC 7 T10N R57W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description TK-01 through TK- 10 003 Ten (10) 400 bbl fixed roof storage vessels used to store crude oil Enclosed Combustor This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) COLORADO Air Pollution Control Division Page 1 of 9 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shalt complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4. ) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO, VOC CO TK-01 through TK-10 003 --- --- 45.0 6.8 Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis. 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 are defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. COLORADO Air Pollution Control Division Page 2 of 9 8. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled TK-01 through TK- 10 003 Enclosed Combustor VOC and HAP PROCESS LIMITATIONS AND RECORDS 9. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit TK 01 through TK- 10 003 Crude Oil throughput with Vapor Recovery Tower (point 005) bypassed 1,231,875 barrels Crude Oil throughput 1,642,500 barrels The owner or operator shall monitor monthly process rates based on the calendar month. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 10. The owner or operator shall continuously monitor and record VRT downtime. 11. The owner or operator must use monthly VRT downtime records, monthly condensate/crude oil throughput records, calculation methods detailed in the O&M Plan, and the emission factors established in the Notes to Permit Holder to demonstrate compliance with the process and emissions limits specified in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 12. 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) 13. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 14. The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2. General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. This flare must be equipped with an operational auto -igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; COLORADO Air Pollution Control Division Page 3 of 9 • 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. 15. The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons except where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. 16. The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Section XVII.C.2. OPERATING & MAINTENANCE REQUIREMENTS 17. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 18. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements 19. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 20. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30t'' 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 (V0C) and nitrogen oxides sources (N0x) 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 Pollution Control Division Page 4 of 9 • 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. 21. 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 application for the Operating Permit is due within one year of the earliest commencement of operation of any piece of equipment covered by this permit. 22. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS 23. 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. 24. 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. 25. 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. 26. 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. 27. 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 aril final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. COLORADO Air Pollution Control Division Page 5 of 9 28. 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. 29. 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: Christopher Kester Permit Engineer Permit Histo Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation COLORADO Air Pollution Control Division Page 6 of 9 Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 003 (process1 VRT Bypass) Benzene 71432 3,572 179 Toluene 108883 2,341 117 Ethylbenzene 100414 370 18 Xylenes 1330207 739 37 n -Hexane 110543 33,384 1,669 2,2,4- Trimethylpentane 540841 3,449 172 003 (process 2 - VRT Operational) Benzene 71432 287 14 Toluene 108883 123 6 Ethylbenzene 100414 12 1 Xylenes 1330207 41 2 n -Hexane 110543 1,889 94 2,2,4- Trimethylpentane 540841 82 4 Note: All non -criteria reportable pollutants in the table above with uncontrolled emiss on rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. COLORADO Air Pollution Control Division Page 7 of 9 5) The emission levels contained in this permit are based on the following emission factors: Point 003 (Process 1 - VRT Bypass 75%): CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 1.41670 0.07084 VMG Simulation with pressurized upstream liquids sample analysis as inputs 71432 Benzene 0.00290 0.00015 108883 Toluene 0.00190 0.00010 100414 Ethylbenzene 0.00030 0.00002 1330207 Xylene 0.00060 0.00003 110543 n -Hexane 0.02710 0.00136 540841 2,2,4-Trimethylpentane 0.00280 0.00014 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Point 003 (Process 2 - VRT Operational 25%): CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 0.12880 0.00644 VMG Simulation with pressurized upstream liquids sample analysis as inputs 71432 Benzene 0.00070 0.00004 108883 Toluene 0.00030 0.00002 100414 Ethylbenzene 0.00003 0.000002 1330207 Xylene 0.00010 0.00001 110543 n -Hexane 0.00460 0.00023 540841 2,2,4-Trimethylpentane 0.00020 0.00001 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Major Source of: VOC; Synthetic Minor Source of: HAPs PSD Synthetic Minor Source of: VOC 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/ COLORADO Air Pollution Control Division Page 8 of 9 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 COLORADO Air Pollution Control Division Page 9 of 9 Permit number: Date issued: Issued to: COLORADO Air Pollution Control Division Department of Public Health & Environment CONSTRUCTION PERMIT 17WE1224 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Whiting Oil and Gas Corporation Horsetail 07 East CPB 123/9F77 NWSE SEC 7 T10N R57W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description SEP-01 through SEP-08 004 Four (4) 2 -phase separators and Four (4) 3- phase heater treaters Open Flare This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to this specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) COLORADO Air Pollution Control Division Page 1 of 9 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. Upon issuance of this permit, the operator shall install a flow meter to monitor and record volumetric flow rate of natural gas vented from each separator covered by this permit. 5. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 6. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section I I.A.4. ) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO, VOC CO SEP-01 through SEP-08 004 --- 10.2 125.8 42.4 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 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 8. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis. 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 are defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. 9. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) COLORADO Air Pollution Control Division Page 2 of 9 Facility Equipment ID AIRS Point Control Device Pollutants Controlled SEP-01 through SEP-08 004 Emissions from the Separators are routed to an Open Flare VOC and HAP PROCESS LIMITATIONS AND RECORDS 10. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit SEP-01 through SEP-08 004 NEItural Gas Flaring 209 MMSCF Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 11. Upon issuance of the permit, the owner or operator shall continuously monitor and record the volumetric flow rate of natural gas flared from the separator(s) using the flow meter. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 12. 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) 13. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 14. The open flare covered by this permit has been approved as an alternative emissions control device under Regulation Number 7, Section XVII.B.2.e. The open flare must have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16, and be designed so that an observer can, by means of visual observation from the outside of the open flare, or by other convenient means approved by the Division, determine whether it is operating properly. This open flare must be equipped with an operational auto -igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 15. The separator covered by this permit is subject to Regulation 7, Section XVII.G. (State Only). On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the date of first production by air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. CDPIE COLORADO Air Pollution Control Division Page 3 of 9 OPERATING £t MAINTENANCE REQUIREMENTS 16. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING 17. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements 18. On an annual basis, the owner/operator shall complete a site specific extended gas analysis ("Analysis") of the natural gas vented from this emissions unit in order to verify the VOC content (weight fraction) of this emission stream. Results of the Analysis shall be used to calculate site - specific emission factors for the pollutants referenced in this permit (in units of lb/MMSCF gas vented) using Division approved methods. Results of the Analysis shall be used to demonstrate that the emissions factor established through the Analysis are less than or equal to, the emission factor submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this Analysis is greater than the emissions factor submitted with the permit application and established in the "Notes to Permit Holder" the operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). ADDITIONAL REQUIREMENTS 19. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO„) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. COLORADO Air Pollution Control Division Page 4 of 9 20. 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 application for the Operating Permit is due within one year of the earliest commencement of operation of any piece of equipment covered by this permit. 21. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS 22. 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. 23. If this permit specifically states that finial 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. 24. 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. 25. 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. 26. 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. 27. 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. 28. 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. COLORADO Mr Po€€ution Control Division Page 5 of 9 By: Christopher Kester Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation COLORADO Air Pollution Control Division Page 6 of 9 Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/agcc-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 (lb/yr) Controlled Emissions (lb/yr) SEP-01 through SEP- 08 004 Benzene 71432 6,342 317 Toluene 108883 15,224 761 Ethylbenzene 100414 5,731 287 Xylenes 1330207 6,966 348 n -Hexane 110543 70,955 3,548 2,2,4- Trimethylpentane 540841 2,207 110 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. COLORADO Air Pollution a Control Division E Page 7 of 9 5) The emission levels contained in this permit are based on the following emission factors: Point 004: CAS # Pollutant Uncontrolled Emission Factors (lb/MMSCF) Controlled Emission Factors (lb/MMSCF) Source NOx 96.288 96.288 AP -42 CO 399.590 399.590 AP -42 VOC 24, 015.164 1,200.758 Site Specific Gas Sample Analysis 71432 Benzene 30.278 1.514 108883 Toluene 72.680 3.634 100414 Ethylbenzene 27.363 1.368 1330207 Xylene 33.259 1.663 110543 n -Hexane 338.753 16.938 540841 2,2,4-Trimethylpentane 10.534 0.527 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Requirement Status Permit Major Source of: t VOCOperating Synthetic Minor Source of: HAPs PSD Synthetic Minor Source of: VOC 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY :COLORADO Air Pollution Control Division Page 8 of 9 MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX COLORADO Air Pollution Control Division Page 9 of 9 Permit number: Date issued: Issued to: COLORADO Air Pollution Control Division Department of Public Health Environment CONSTRUCTION PERMIT 17WE1225 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Whiting Oil and Gas Corporation Horsetail 07 East CPB 123/9F77 NWSE SEC 7 T10N R57W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description ENG-02 005 One (1) Caterpillar, G3516J, SN: N6W00180, natural gas -fired, turbo -charged aspirated, 4SLB reciprocating internal combustion engine, site rated at 1380 horsepower. This emission unit is used for natural gas compression. Oxidation Catalyst and air/fuel ratio controller This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G3516J engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment 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. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. COLORADO Air Pollution Control Division Page 1 of 11 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) ) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO, VOC CO ENG-02 005 --- 12.0 9.3 13.3 Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis. 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 are defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. COLORADO Air Pollution Control Division Page 2 of 11 8. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled ENG-02 005 Oxidation Catalyst and air/fuel ratio controller CO and formaldehyde PROCESS LIMITATIONS AND RECORDS 9. 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 ENG-02 005 Consumption of natural gas as a fuel 88.3 MMscf The owner or operator shall monitor monthly process rates based on the calendar month. Compliance with the annual throughput Limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. 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) 11. 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 XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. Et 4.) 12. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) OPERATING a MAINTENANCE REQUIREMENTS 13. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 14. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements COLORADO Air Pollution Control Division Page 3 of 11 15. This engine is subject to the periodic testing requirements of 40 C.F.R Part 63, Subpart ZZZZ. 16. This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 17. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 18. 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 application for the Operating Permit is due within one year of the earliest commencement of operation of any piece of equipment covered by this permit. 19. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS 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 COLORADO Air Pollution Control Division Page 4 of 11 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), induding 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. 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: Christopher Kester Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation COLORADO Air Pollution Control Division Page 5 of 11 Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-reps 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 005 Formaldehyde 50000 11,436 7,729 Acetaldehyde 75070 752 752 Acrolein 107028 462 462 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 005: CAS # Pollutant Uncontrolled Emission Factors g/hp-hr Controlled Emission Factors g/hp-hr Source NOx 0.9 0.9 Manufacturer Specifications CO 2.43 1.0 VOC 0.7 0.7 50000 Formaldehyde 0.43 0.29 75070 Acetaldehyde 0.00836 (lb/MMBtu) 0.00836 (lb/MMBtu) AP 42 107028 Acrolein 0.00514 (lb/MMBtu) 0.00514 (lb/MMBtu) 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 COLORADO Air Pollution Control Division Page 6 of 11 associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting - effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.govittn/atw/area/fr181a08.pdf 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Major Source of: VOC; Synthetic Minor Source of: HAPs PSD Synthetic Minor Source of: VOC 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 Page 7 of 11 ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 1. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 1.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with an engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 1.1.2 and make them available to the Division upon request. 1.1.1 The owner or operator may temporarily replace an existing engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 1.2. 1.1.2 The owner or operator may permanently replace the existing engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 1.2. COLORADO Air Pollution Control Division Page 8 of 11 An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at https://www.colorado:gov/pacific/cdphe/alternate-operating-scenario-aos-reporting- forms. This submittal shall be accompanied by a certification from the Responsible Official indicating that "based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 1.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: https://www.colorado.Rov/pacific/sites/default/files/AP Portable-Analyzer-Monitoring-Protocol.pdf Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd ® 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above -mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be COLORADO Air Pollution Control Division Page 9 of 11 considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 1.3 Applicable Regulations for Permanent Engine Replacements 1.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (5 60.331) and 40 CFR Part 72 (5 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 1.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State -Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non -selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 1.1.2. Emission Standards: Section XVII.E - State -only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: COLORADO Air Pollution Control Division Page 10 of 11 Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NOx CO VOC 100<Hp<500 January 1, 2008 January 1, 2011 2.0 1.0 4.0 2.0 1.0 0.7 500<Hp July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 1.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 1.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 1.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 1.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, 5 1.8 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 1.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 1.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 1.2. 1.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS-approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. COLORADO Air Pollution Control Division Page 11 of 11 Permit number: Date issued: Issued to: COL RAD Air Pollution Control Division Department of Public Health b Environment CONSTRUCTION PERMIT 17WE1226 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Whiting Oil and Gas Corporation Horsetail 07 East CPB 123/9F77 NWSE SEC 7 T10N R57W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description ENG-01 006 One (1) Caterpillar, G3516J, SN: N6W00189, natural gas -fired, turbo -charged aspirated, 4SLB reciprocating internal combustion engine, site rated at 1380 horsepower. This emission unit is used for natural gas compression. Oxidation Catalyst and air/fuel ratio controller This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G3516J engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment 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. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. COLORADO Ail- Pollution Control Division Page 1 of 11 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-setf- certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section I I.A.4. ) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO), VOC CO ENG-01 006 --- 12.0 9.3 13.3 Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis. 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 are defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. COLORADO Air Pollution Control Division Page 2 of 11 8. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled ENG-01 006 Oxidation Catalyst and air/fuel ratio controller CO and formaldehyde PROCESS LIMITATIONS AND RECORDS 9. 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 ENG-01 006 Consumption of natural gas as a fuel 88 .3 MMscf The owner or operator shall monitor monthly process rates based on the calendar month. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. 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) 11. 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 XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. Et 4.) 12. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) OPERATING a MAINTENANCE REQUIREMENTS 13. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEM) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 14. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements COLORADO Air Pollution Control Division Page 3 of 11 15. This engine is subject to the periodic testing requirements of 40 C.F.R Part 63, Subpart ZZZZ. 16. This engine is subject to the periodic testing requirements as specified in the operating and maintenance (OEM) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 17. 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 NOX per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 18. 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 application for the Operating Permit is due within one year of the earliest commencement of operation of any piece of equipment covered by this permit. 19. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS 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 COLORADO Air Pollution Control Division Page 4 of 11 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 perrrit 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), induding 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. 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: Christopher Kester Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation COLORADO Air Pollution Control Division Page 5 of 11 Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 006 Formaldehyde 50000 11,436 7,729 Acetaldehyde 75070 752 752 Acrolein 107028 462 462 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 006: CAS # Pollutant Uncontrolled Emission Factors g/hp-hr Controlled Emission Factors g/hp-hr Source N0x 0.9 0.9 Manufacturer Specifications CO 2.43 1.0 V0C 0.7 0.7 50000 Formaldehyde 0.43 0.29 75070 Acetaldehyde 0.00836 (lb/MMBtu) 0.00836 (lb/MMBtu) AP 42 107028 Acrolein 0.00514 (lb/MMBtu) 0.00514 (lb/MMBtu) 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 COLORADO Air Pollution Control Division Page 6 of 11 associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting - effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.govittn/atw/area/fr18ja0g.pdf 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Major Source of: VOC; Synthetic Minor Source of: HAPs PSD Synthetic Minor Source of: VOC 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 Mr Pollution Control Division Page 7 of 11 ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 1. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 1.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with an engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted.to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 1.1.2 and make them available to the Division upon request. 1.1.1 The owner or operator may temporarily replace an existing engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 1.2. 1.1.2 The owner or operator may permanently replace the existing engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 1.2. COLORADO Air Pollution Control Division Page 8 of 11 An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine hall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at https://www.colorado.gov/pacific/cdphe/alternate-operating-scenario-aos-reporting- forms. This submittal shall be accompanied by a certification from the Responsible Official indicating that "based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replarnment of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 1.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: https://www.colorado.gov/pacific/sites/default/files/AP Portable-Analyzer-Monitoring-Protocol.pdf Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd ® 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above -mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be COLORADO Air Pollution Control Division Page 9 of 11 considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 1.3 Applicable Regulations for Permanent Engine Replacements 1.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or S02 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ 5O2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (5 60.331) and 40 CFR Part 72 (5 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 1.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State -Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non -selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 1.1.2. Emission Standards: Section XVII.E - State -only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: COLORADO it Pollution Control Division Page 10 of 11 Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr N0x CO V0C 100<Hp<500 January 1, 2008 January 1, 2011 2.0 1.0 4.0 2.0 1.0 0.7 500≤Hp July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 1.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 1.1.2. Any testing required by the NSPS is in addition to that required by this A0S. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this A0S under Condition 1.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 1.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, 5 1.6 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 1.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this A0S. Note that the initial test required by the MACT can serve as the testing required by this A0S under Condition 1.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 1.2. 1.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The A0S is therefore essentially an advanced construction permit review. The A0S cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an A0S-approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. COLORADO Air Pollution Control Division Page 11 of 11 Permit number: Date issued: Issued to: COLORADO Air Pollution Control Division Department of Pubic Health 8 Environment CONSTRUCTION PERMIT 17WE1237 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Whiting Oil and Gas Corporation Horsetail 07 East CPB 123/9F77 NWSE SEC 7 T10N R57W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description SEP-18 through SEP- 20 007 Three (3) Vapor Recovery Towers (VRT) Open Flare This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to this specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/ pacific/cdphe/ other -air- permitting - notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shalt be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) COLORADO Air Pollution Control Division Page 1 of 8 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section I I .A.4. ) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO. VOC CO SEP-18 through SEP-20 007 --- --- 5.7 --- Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis. 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 are defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. COLORADO Air Pollution Control Division Page 2 of 8 8. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled SEP-18 through SEP- 20 007 Emissions from the VRTs are routed to an Open Flare during VRU or gas gathering downtime VOC and HAP PROCESS LIMITATIONS AND RECORDS 9. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit SEP-18 through SEP-20 007 Crude Oil Throughput during VRU or gas gathering system downtime 229,950 bbl/yr Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous 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. 10. The owner or operator shall continuously monitor and record VRU downtime. 11. The owner or operator must use monthly VRU downtime records, monthly condensate/crude oil throughput records, calculation methods detailed in the OitM Plan, and the emission factors established in the Notes to Permit Holder to demonstrate compliance with the process and emissions limits specified in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 12. 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) 13. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 14. The open flare covered by this permit has been approved as an alternative emissions control device under Regulation Number 7, Section XVII.B.2.e. The open flare must have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16, and be designed so that an observer can, by means of visual observation from the outside of the open flare, or by other convenient means approved by the Division, determine whether it is operating properly. This open flare must be equipped with an operational auto -igniter according to the following schedule: • • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. COLORADO Air Pollution Control Division Page 3 of 8 15. The separator covered by this permit is subject to Regulation 7, Section XVII.G. (State Only). On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the date of first production by air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. OPERATING a MAINTENANCE REQUIREMENTS 16. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 17. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements 18. On an annual basis, the owner or operator shall complete a site specific analysis ("Analysis") including a compositional analysis of the pre -flash pressurized hydrocarbon liquid routed to the equipment covered in this permit. The owner or operator may choose to perform a flash liberation analysis to estimate the post -flash composition and scf/bbl ratio per PS Memo 17-01, otherwise the testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of the Analysis shall be used demonstrate the emissions factors established through the Analysis are less than or equal to, the emissions factors submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this Analysis is greater than the emissions factors submitted with the permit application and established in the "Notes to Permit Holder" the operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). ADDITIONAL REQUIREMENTS 19. 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 Pollution Control Division Page 4 of 8 • 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. 20. 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 application for the Operating Permit is due within one year of the earliest commencement of operation of any piece of equipment covered by this permit. 21. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS 22. 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. 23. 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. 24. 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. 25. 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. 26. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. COLORADO Air Pollution Control Division Page 5 of 8 27. 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. 28. 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: Christopher Kester Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation COLORADO Air Pollution Control Division Page 6 of 8 Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Facility Equipment ID AIRS Point Pollutant CAS # Uncontrolled Emissions (Ib/yr) Controlled Emissions (Ib/yr) SEP-18 through SEP- 20 007 Benzene 71432 1801 90 Toluene 108883 822 41 Ethylbenzene 100414 90 4 Xylenes 1330207 156 8 n -Hexane 110543 10877 544 2,2,4- Trimethylpentane 540841 502 25 Note: All non-critera reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. COLORADO Air Pollution Control Diviscon Page 7 of 8 5) The emission levels contained in this permit are based on the following emission factors: Point 007: CAS # Pollutant Uncontrolled Emission Factors (lb/bbl) Controlled Emission Factors (lb/bbl) Source V0C 0.9761 0.0488 VMG Simulation with Pressurized upstream liquids sample analysis as inputs 71432 Benzene 0.0078 0.0004 108883 Toluene 0.0036 0.0002 110543 n -Hexane 0.0473 0.0024 540841 2,2,4-Trimethylpentane 0.0022 0.0001 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any 'questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Requirement Status Operating Permit Major Source of: V0C; Synthetic Minor Source of: HAPs PSD Synthetic Minor Source of: V0C 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX COLORADO Air Pollution Control Division Page 8 of 8 Produced Water Storage Tank(s) APEN - Form APCD-207 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store produced water associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, condensate storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Qov/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: tiV Z2� AIRS ID Number: \'L9 /19-TpCrZ. [Leave btank u Le has ariy assirada parmit _ A,r ; IDJ Section 1 - Administrative Information Company Name': Whiting Oil and Gas Corporation Site Name: Horsetail 07 East CPB Site Location: NWSE Section 7, T1 ON, R57W Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Site Location County: Weld NAICS or SIC Code: 1311 Denver, CO 80290 Permit Contact: Jacob Parker Phone Number: 303-357-4078 E -Mail Address2: CDPHECorrespondence@whifing.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Z 17 371750 1, AV COLORADO 42 Permit Number: AIRS ID Number: / / Section 2 - Requested Action Q NEW permit OR newly -reported emission source E Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP05 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Note blank APENs will not be accepted) Brr1or%t-PERMIT—AcTteps - ❑ APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 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: For existing sources, operation began on: (6) 400 bbl produced water tanks For new or reconstructed sources, the projected start-up date is: August 19, 2017 Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 (] Exploration Et Production (EEtP) site days/week 52 weeks/year ❑ Midstream or Downstream (non EEtP) site Will this equipment be operated in any NAAQS nonattainment area? • Yes • No Are Flash Emissions anticipated from these storage tanks? 151 Yes ■ No Are these storage tanks located at a commercial facility that accepts oil production wastewater for processing? Yes No • p Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? ■ Yes O No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No • • Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual• emissions ≥ 6 ton/yr (per storage tank)? Yes No p ®® COLORADO 43 Permit Number: AIRS ID Number: Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl /year) Requested Annual Permit Limit4 (bbl /year) Produced Water Throughput: 4,380,000 From what year is the actual annual amount? Tank design: Fixed roof ❑ Internal floating roof ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) PW-01 to PW-06 6 2,400 05/2017 08/2017 Wells Serviced by this Storage Tank or Tank Battery5 (E&P Sites Only) API Number Name of Well Newly Reported Well 8-- 05 123 42111 Horsetail --07G-0609 05 - 123 - 42114 Horsetail 07G-0610 GI 05 - 123 - 42117 Horsetail Federal 07G-0611 O 05 - 123 - 42116 Horsetail Federal 07G-0612 II 05 - 123 - 42109 Horsetail Federal 07G-0642 0 4 Requested values will become permit limitations. Requested Limit(s) should consider future growth. 5 The E£tP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report alt wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.85182/-103.79097 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) COMB -01 & COMB -02 25 >2000 15 0.04 Indicate the direction of the stack outlet: (check one) Upward 0 Horizontal ❑ Downward 0 Other (describe): Indicate the stack opening and size: (check one) 0 Circular ❑ Square/rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): 48 Interior stack width (inches): Interior stack depth (inches): 3I eY COLORADO 44 Permit Number: AIRS ID Number: Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor ❑ Recovery Unit (VRU): Size: Make/Model: Requested Control Efficiency: /0 VRU Downtime or Bypassed (emissions vented): % ❑ Combustion J Device: Pollutants Controlled: VOC and HAPs Rating: 6.6 MMBtu/hr Type: Enclosed Combustor Make/Model: Leed/L3O-001-00 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 % Minimum Temperature: N/A Waste Gas Heat Content: Constant Pilot Light: ❑r Yes ❑ No Pilot Burner Rating: 1,135 0.13 Btu/scf MMBtu/hr hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 -Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 8 psig Describe the separation process between the well and the storage tanks: A combined stream of liquids and natural gas is extracted from the wells and transferred to four (4) 2 -phase separators where gas is separated from liquids. The liquids are transferred to four (4) heater treaters that are each equippedwith a burner to facilitate further separation into streams of gas, crude oil, and produced water. The crude oil is transferred into two Vapor Recovery Towers and then transferred to storage tanks. The separated stream of produced water is transferred directly to storage tanks. 4 ®7 COLORADO 45 Permit Number: AIRS ID Number: Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (94 -reduction in emissions) V0C Enclosed Combustor 95 NOx CO HAPs Enclosed Combustor 95 Other: From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor° Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled Source Uncontrolled Controlled - Uncontrolled - Controlled Basis Units (AP -4?, Mfg. etc) Emissions (Tons/year) tmissions7 (Tons/year) Emissions (Tons/year) Emissions (Tons/year) VOC 0.044 ' lb/bbl Flash Analysis 96 4.8 — NOx 0.068 ' Ib/MMBtu AP -42 De Minimis CO 0.31 - Ib/MMBtu AP -42 De Minimis Non -Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor6 Actual Annual Emissions Chemical Name Abstract (CAS) ( ) Uncontrolled Basis Units Source (AP -42, Uncontrolled Emissions Controlled Emissions7 Number etc) Mfg. -Pounds/ ear (Pounds/year) ) (Pounds/year) Benzene 71432 0.00046 ' lb/bbl Flash Analysis Toluene 108883 0.00021 - lb/bbl Flash Analysis Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 0.00276 ' lb/bbl Flash Analysis 2,2,4- Trimethylpentane 540841 0.0001 - lb/bbl Flash Analysis 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 Attach produced water laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 7 Annual emissions fees wilt be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-207 D -20, "oduced". r c r './2017 5) AT' COLORADO x-Fu.v n.r E�c;�r 46 Permit Number: AIRS ID Number: / / Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP05 or GP08, I further certify that this source is and will be operated in full compliance with each copdition of the applicable General Permit. November 17, 2017 Sigrja ure of Legally Authorized Person (not a vendor or consultant) Date Jacob Parker Environmental Professional Name (print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd 6I COLORADO jar 47 E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Form' Company Name: Whiting Oil and Gas Corporation Source Name: Horsetail 07 East CPB Emissions Source AIRS ID2: 'L3 AW-4-7-/ 00 2 -- Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 41836 Horsetail 0711-0613 ►1 05 - 123 - 43043 Horsetail 07H-0615 ►� 05 - 123 - 41834 Horsetail 0711-0646 /1 05 - 123 - 41829 Horsetail 07H-0647 05 - 123 - 41832 Horsetail 0711-1813 /1 05 - 123 - 41841 Horsetail 07H-1814 /1 05 - 123 - 41831 Horsetail 07H-1815 ►1 05 - 123 - 41840 Horsetail 07H-1816 05 - 123 - 41839 Horsetail 07H-1846 /1 05 -123 - 41830 Horsetail 07H-1847 /1 05 -123 - 42110 Horsetail Federal 07G-0643 ►1 05L2342118 Horsetail 07C_1gO _® 05 -123 - 42126 Horsetail 07G-1810 /1 05 - 123 - 42115 Horsetail 07G-1811 �1 05 - 123 - 42121 Horsetail 07G-1812 /1 05 - 123 - 42112 Horsetail 07G-1844 ►1 - - - - /1 - - /1 - - ►� Footnotes: ' Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 AP_FormAPCD-212-EP-StorageTank-APEN-Addendum. docx &g. IRA silo )1 Crude Oil Storage Tank(s) APEN - Form APCD-210 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store crude oil associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. condensate storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/pacific/cdphe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: I1WCIZz1 AIRS ID Number: 1 Z.5 i c / (✓'O 3 [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Whiting Oil and Gas Corporation Horsetail 07 East CPB Site Location: NWSE Section 7, T1 ON, R57W Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Denver, CO 80290 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Ashley Brinkerhoff Phone Number: 303-390-1596 E -Mail Address2: CDPHECorrespondence@whiting.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. COLORADO Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 07,12017 MAltilvie4 45-4 I 'I y 9 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit ' and AIRS ID] Section 2 - Requested Action NEW permit OR newly -reported emission source ❑ Request coverage under traditional construction permit ❑ Request coverage under General Permit GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. OR - ▪ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) - OR - ▪ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - or permit exempt/grandfather ed source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 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: For existing sources, operation began on: (10) 400 bbl crude oil tanks For new or reconstructed sources, the projected start-up date is: August 19, 2017 Normal Hours of Source Operation: Storage tank(s) located at: 24 hours/day 7 days/week 52 ❑ Exploration Et Production (EaP) site weeks/year ❑ Midstream or Downstream (non E&P) site Will this equipment be operated in any NAAQS nonattainment area? • Yes • No Are Flash Emissions anticipated from these storage tanks? p Yes ■ No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No • p Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual• emissions ≥ 6 ton/yr (per storage tank)? Yes No p Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 07/2017 COLORADO 2j :. Publ D. xeprmac,rI Permit Number: AIRS ID Number: [Lea:;e bLank unless APCD has already assigned a permit A and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/year) Requested Annual Permit Limit4 (bbl/year) Crude Oil Throughput: 1,642,500 From what year is the actual annual amount? Average API gravity of sales oil: 34.3 degrees Tank design: Fixed roof ❑ Internal floating roof RVP of sales oil: 5.9 ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) TK-01 to TK-10 10 4,000 05/2017 08/2017 API Number Wells Serviced by this Storage Tank or Tank Battery5 (EftP Sites Ony) I Newly Reported Well Name of Well 05 - 123 - 42111 Horsetail 07G-0609 05 - 123 - 42114 Horsetail 07G-0610 05 - 123 - 42117 Horsetail Federal 07G-0611 05 - 123 - 42116 Horsetail Federal 07G-0612 05 - 123 - 42109 Horsetail Federal 07G-0642 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The EEtP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.85182/-103.79097 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) COMB -01 35 >2000 57.1 0.02 Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): ❑ Upward ❑ Horizontal Indicate the stack opening and size: (check one) E Circular ❑ Square/rectangle ❑ Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap 96 Interior stack width (inches): Interior stack depth (inches): Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 07/2017 ©© COLORADO 3 I m.c Heil Deportment Permit Number: AIRS ID Number: [Leave blankunless APCD has already assigned a permit ? and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor ❑ Recovery Unit (VRU): Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: % ❑ Combustion Device: Pollutants Controlled: VOC and HAPs Rating: 42.5 MMBtu/hr Type: Enclosed Combustor Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: N/A Make/Model: Crimson Energy/CE 1000 95 98 % Waste Gas Heat Content: 2,061 Btu/scf Constant Pilot Light: ❑✓ Yes ❑ No Pilot Burner Rating: 0.06 MMBtu/hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: % Section 7 -Gas/Liquids Separation Technology Information (EftP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 8 psig Describe the separation process between the well and the storage tanks: A combined stream of liquids and natural gas is extracted from the wells and transferred to four (4) 2 -phase separators where gas is separated from liquids. The liquids are transferred to four (4) heater treaters that are each equipped with a burner to facilitate further separation into streams of gas, crude oil, and produced water. The crude oil is transferred into three Vapor Recovery Towers and then transferred to storage tanks. The separated stream of produced water is transferred directly to storage tanks. Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 07/2017 4 I AVCOLORADO �` � , Permit Number: AIRS ID Number: [Leave blank unless APCD has already assiened a permit and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall Pollutant Description of Control Method(s) Overall Requested Control • Efficiency ., - (% reduction in emissions) VOC Enclosed Combustor 95 NOx CO HAPs Enclosed Combustor 95 Other: From what year is the following reported actual annual emissions data? Permitted Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Basis Units (AP -4L, Mfg. etc) Emissions (Tons/ ear y ) Emissions (Tons/year) missions (Tons/year) missions (Tons/year) VOC 1.4167 / 0.1288 lb/bbl Flash Analysis / VMG 899.0 e- 45.0 NOx 0.068 Ib/MMBtu AP -42 De Minimis CO 0.31 Ib/MMBtu AP -42 6.93 ' Non -Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor b Actual Annual Emissions Chemical Name Abstract (CAS) ( ) Uncontrolled Units Source (AP -42, Uncontrolled Emissions Controlled Emissions7 Number Basis Mfg. etc) (Pounds/year) (Pounds/year) Benzene 71432 0.0029 / 0.0007 lb/bbl Flash Analysis /VMG 3,838 - 192 Toluene 108883 0.0019 / 0.0003 lb/bbl Flash Analysis /VMG 2,515 - 126 Ethylbenzene 100414 0.0003 / 0.00003 lb/bbl Flash Analysis/VMG 333 t 17 ,- Xylene 1330207 0.0006 / 0.0001 lb/bbl Flash Analysls/VMG 719 / 36 n -Hexane 110543 0.0271 / 0.0046 lb/bbl FlashAnalysls/VMG 35,300 / 1,765 i 2,2,4- Trimethylpentane 540841 0.0028 / 0.0002 lb/bbl FlashAnatys,s/vMG 3,535 - 177 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 Attach crude oil laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 07/2017 AV COLORADO 5I mV �� Permit Number: AIRS ID Number: / / [Leave blank sinless APCD has already assigned a permit Al and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. Signature of Legally rson (not a vendor or consultant) Ashley Brinkerhoff May 30, 2018 Date Environmental Professional Name (print) Title Check the appropriate box to request a copy of the: ❑� Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-21O - Crude Oil Storage Tank(s) APEN - Revisiin 07/2017 �w COLORADO 6 VFiJ w.�imirs..o"�, E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Form' Company Name: Whiting Oil and Gas Corporation Source Name: Horsetail 07 East CPB Emissions Source AIRS ID2: / / Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 -123 - 41836 Horsetail 07H-0613 �1 05 - 123 - 43043 Horsetail 07H-0615 ►1 05 -123 - 41834 Horsetail 07H-0646 I1 05 - 123 - 41829 Horsetail 07H-0647 �I 05 - 123 - 41832 Horsetail 07H-1813 /1 05 - 123 - 41841 Horsetail 07H-1814 /1 05 - 123 - 41831 Horsetai107H-1815 ►1 05 - 123 - 41840 Horsetail 07H-1816 ►1 05 - 123 - 41839 Horsetail 0711-1846 /1 05 -123 - 41830 Horsetail 07H-1847 ►1 05 -123 - 42110 Horsetail Federal 07G-0643 ►1 05 - 123 - 42118 Hors-etait07G=1809 ►1 05 -123 - 42126 Horsetail 07G-1810 11 05 - 123 - 42115 Horsetail 07G-1811 .1 05 - 123 - 42121 Horsetail 07G-1812 ►1 05 - 123 - 42112 Horsetail 07G-1844 ►1 - - ❑ - - ❑ - - ❑ - - ❑ Footnotes: Attach this addendum to associated APEN foini when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 AP_FormAPCD-212-EP-StorageTank-APEN-Addendum. docx Receiva TN" Natural Gas Venting APEN - Form APCD-211 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including 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 Natural Gas Venting only. Natural Gas Venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source. 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.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Pr Permit Number: W E172! [Leave blank unless APCD has already assigned a permit and AIRS ID] Company equipment Identification: SEP-01 through SEP-08 [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: Horsetail 07 East CPB Site Location: NWSE Section 7, T1 ON, R57W Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Denver, CO 80290 E -Mail Address' CDPHECOrreSpOndence@whiting.COM Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Ashley Brinkerhoff Phone Number: 303-390-1596 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-211 - Natural Gas Venting APEN - Rev 03/2017 1 . COLORADO Den.nnuen1 of Pub. Heat. Envventeuem A Primlit•o4V Vi 1 131 Permit Number: AIRS ID Number: [Leave unless APCD has already assigned a permit = and AIRS ID] Section 2- Requested Action ❑r NEW permit OR newly -reported emission source - OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) OR- ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - 111 Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 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: and (4) 3 -phase heater treaters Flaring associated gas from (4) 2 -phase separators For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / / 08 / 19 / 2017 0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions days/week weeks/year ❑ Yes E No ❑ Yes ❑✓ No Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 �Y COLORADO 2 I Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit A' and AIRS ID] Section 4 - Process Equipment Information ❑✓ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: ❑ Other Description: Serial #: Capacity: Gal/min # of Pistons: Leak Rate: Scf/hr/pist Volume per event: MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: N Maximum Vent Rate: 341 667 SCF/hr Vent Gas Heating Value: 1 416 BTU/SCF Requested: 209.5 MMSCF/year Actual: MMSCF/year -OR- Requested: Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: Molecular Weight: VOC (mole %) 17.55 VOC (Weight %) 36.24 Benzene (mole %) 0.015 Benzene (Weight %) 0.046 Toluene (mole %) 0.030 Toluene (Weight %) 0.110 Ethylbenzene (mole %) 0.010 Ethylbenzene (Weight %) 0.041 Xylene' (mole %) 0.012 Xylene (Weight %) 0.050 n -Hexane (mole %) 0.149 n -Hexane (Weight %) 0.511 2,2,4-Trimethylpentane 2,2,4-Trimethylpentane (mote %) 0.004 (Weight %) 0.016 Additional Required Information: ❑✓ Attach a representative gas analysis (including BTEX 8 n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 3 I AVCOLORADO e = Permit Number: AIRS ID Number: / / !leave blank unless APCD has alieady assigned a permit 0 and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.85182/-103.79097 Operator. Stalk ID No .. Discharge3Height , . Above Ground Level :- (Feet) Temp {°F) "Flow Rate (ACFII0 Velocity eft/sec):: FLR-01 40 >2,000 5,694 271.9 Indicate the direction of the stack outlet: (check one) E Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): ❑ Upward with obstructing raincap 8 ❑ Other (describe): Section 6 - Control Device Information ❑✓ VRU: Pollutants Controlled: Size: Requested Control Efficiency VRU Downtime or Bypassed Make/Model: ❑ Combustion Device: Pollutants Controlled: VOC and HAPs Rating: 598 MMBtu/hr Type: Open Flare Make/Model: Flare Industries/SFVP-0824 Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency 98 Minimum Temperature: N/A Waste Gas Heat Content Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating 1,416 Btu/scf 0.13 MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested 0 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 4IAVCOLORADO Zn, , Permit Number: AIRS ID Number: 'Leave blank unless APCD has already assigned a permit h 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? ❑� Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SOx NO), VOC Gas is sent to gas gathering pipeline w/open flare as backup 95% CO HAPs Gas is sent to gas gathering pipeline w/open flare as backup 95% Other: From what year is the following reported actual annual emissions data. Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions , . Requested Annual Permit: ° a s - EmissionLimrt'-s) Uncontrolled (Tons/year) Controlled6 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM 0.0075 lb/MMBtu AP -42 De Minimis SOx 0.963 Ib/MMscf Gas Analysis De Minimis NO), 0.068 Ib/MMBtu AP -42 10.22 ' VOC 23984.91 Ib/MMscf Gas Analysis 2,512.5 — 125.6 - CO 0.31 lb/MMBtu AP -42 42.43 -- Benzene 30.26 lb/MMscf Gas Analysis 3.17 - 0.16 - Toluene 72.61 Ib/MMscf Gas Analysis 7.61 ..- 0.38 Ethylbenzene 27.42 lb/MMscf Gas Analysis 2.87 ' 0.14 .' Xylenes 33.3 Ib/MMscf Gas Analysis 3.49 - 0.17 i n -Hexane 338.45 lb/MMscf Gas Analysis 35.45 ' 1.77 - 2,2,4 Trimethylpentane 10.54 Ib/MMscf Gas Analysis 1.10 � 0.06 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 COLORADO 5 I �. sin ', Permit Number: AIRS ID Number: lLeave 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. Signature of Legally Ashley Brinkerhoff May 30, 2018 erson (not a vendor or consultant) Date Environmental Professional Name (please print) Title Check the appropriate box to request a copy of the: E 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) 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 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 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 COLORADO 6 I Department of D F • t1-7 g Reciprocating Internal Combustion Engine APEN - Form APCD-201 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 reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, 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.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 1 "Z. ZS-- AIRS ID Number: \23 /C1P-4"7/ 003 — [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Whiting Oil and Gas Corporation Site Name: Horsetail 07 East CPB Site Location: NWSE, Section 7, T1 ON, R57W Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Portable Source Home Base: Denver, CO 80290 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Ashley Brinkerhoff Phone Number: 303-390-1596 E -Mail Address2: CDPHECorrespondence@whiting.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 1 I AVCOLORADO tf,`e w o °t, kWa4•VALCA' t Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit t and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source ❑✓ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. - 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 ownership4 ❑ Other (describe below) - OR • APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ▪ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Ft Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for A0S permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. ENG-02 General description of equipment and purpose: Gas Lift Compressor Engine For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: / /www.colorado.gov/cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 September 12, 2017 ❑ Yes 0 No Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 days/week 52 weeks/year June -Aug: 25 Sept -Nov: 25 Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 2 ®® COLORADO Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: 0 Compression What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Caterpillar Engine Model: G3516J Serial Number': N6W00180 What is the maximum designed horsepower rating? 1,380 hp What is the engine displacement? 4.3 l/cyl What is the maximum manufacturer's site -rating? 1,380 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,443 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke 0 4 -Stroke Combustion: 0 Lean Burn ❑ Rich Burn Ignition Source: ❑ Spark ❑ Compression Aspiration: ❑ Natural ❑ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No If yes, what type of AFRC is in use? 0 OZ Sensor (mV) ❑NOX Sensor (ppm) ❑ Other: Is this engine equipped with a Low NOX design? ---Yes 0 No Engine Dates: What is the manufactured date of this engine? April 4, 2017 What date was this engine ordered? April 19, 2017 What is the date this engine was first located to Colorado? June 26, 2017 What is the date this engine was first placed in service/operation? September 12, 2017 What is the date this engine commenced construction? June 26, 2017 What is the date this engine was last reconstructed or modified? N/A Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 3 & '6EKpnmenl Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit r and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.85182/-103.79097 O�Serator ' Stack ID No. Discharge Height = -( Above Ground Level • (Feet) Temp; c) .Flow Rate (ACFMj„ Velonty (ft/sec), s: ENG 02 23.7 830 8,070 165.8 Indicate the direction of the Stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) �triar Interior stack diarnetef-(inches): ❑ Square/Rectangle ❑ Other (describe): 12 ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 1O0% Load (SCF/hour) Actual Annual Fuel Use (MMSCFI year) Requested Annual Permit Limit'. (MMSCF/ year) 10,070 88.21 From what year is the actual annual amount? Indicate the type of fuel used': ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑ Field Natural Gas Heating value: BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 ®y COLORADO Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM25 SOX NOX VOC CO SCO with AFRO 58.8% Other: Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? Permitted Criteria Pollutant Emissions Inventory • Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) - Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) - TSP (PM) 0.00991 Ib/MMBtu AP -42 De Minimis De Minimis PM 10 0.00991 Ib/MMBtu AP -42 De Minimis De Minimis PM2.5 0.00991 Ib/MMBtu AP -42 De Minimis De Minimis SOX 0.000588 Ib/MMBtu AP -42 De Minimis De Minimis NO 0.90 g/hp-hr NSPS JJJJ 12.0 - 12.0 -- VOC 0.70 g/hp-hr NSPS JJJJ 9.3 ' 9.3 -- CO 2.43 g/hp-hr Manf Spec 32 4 — 13.3 Does the emissions source have any uncontrolled actual emissions of non -criteria ❑✓ Yes pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑ No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Emission Factor Actual Annual Emissions' Uncontrolled Basis asis U nits Source (AP -42 Mf . etc) g Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0.43 g/hp-hr Manf Spec 11,460 ' 7,729 - Acetaldehyde 75070 0.00836 Ib/MMBtu AP -42 7531 753 Acrolein 107028 0.00514 Ib/MMBtu AP -42 463 463 Benzene 71432 Other: 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 5 IAW COLORADO _ rDiown6 Department m1.� Permit Number: AIRS ID Number: / / [Leave blank unless APED 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. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Legally Ashley Brinkerhoff May 30, 2018 son (not a vendor or consultant) Date Environmental Professional Name (please print) Title Check the appropriate box to request a copy of the: ❑� Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 6 L Y COLORADO xa.,nmrm of 4-.1.1c Reciprocating Internal Combustion Engine APEN - Form APCD-201 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 reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, 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.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 1 VvC I1 -71P AIRS ID Number: IZ3 /C/F"7:7-/ co [Leave blank unless APCD has already assigned a permit A and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Whiting Oil and Gas Corporation Horsetail 07 East CPB Site Location: NWSE, Section 7, T1 ON, R57W Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Portable Source Home Base: Denver, CO 80290 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Ashley Brinkerhoff Phone Number: 303-390-1596 E -Mail Address2: CDPHECorrespondence@whiting.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 MO4'?'urkDI 14 COLORADO 1 I AV Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit A and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: ❑✓ Compression What is the maximum number of hours this engine will be used for emergency back-up power? 0 Engine Make: Caterpillar - Engine Model: G3516J hours/year Serial Number6: N6W00189 What is the maximum designed horsepower rating? 1,380 ' hp What is the engine displacement? 4.3 l/cyl What is the maximum manufacturer's site -rating? 1,380 i hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,443 - BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke E 4 -Stroke Combustion: ❑✓ Lean Burn ❑ Rich Burn Ignition Source: ❑ Spark ❑ Compression Aspiration: ❑ Natural E Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ✓❑ Yes ❑ No If yes, what type of AFRC is in use? ❑✓ O2 Sensor (mV) ❑NOx Sensor (ppm) ❑ Other: Ic thic anoin peed wi.th_a_Low-NOx design? ❑ Yec ® No Engine Dates: What is the manufactured date of this engine? April 19, 2017 What date was this engine ordered? April 19, 2017 What is the date this engine was first located to Colorado? June 26, 2017 What is the date this engine was first placed in service/operation? September 11, 2017 What is the date this engine commenced construction? June 26, 2017 What is the date this engine was last reconstructed or modified? N/A Is this APEN reporting an AOS replacement engine? ❑ Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 3 AD. COLORADO Department „ni Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit b and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.85182/-103.79097 #� fi Operator- c Stack IDNO'" — Discharge Heigh Above Ground Level (Feet) Temp ( f �. 3 FC9W Rate x (ACFM) _ Yeloaty n-, (ft/sec) ENG-01 23.7 830 8,070 165.8 Indicate the direction of the Stack outlet: (check one) E] Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inc ❑ Square/Rectangle ❑ Other (describe): 12 ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate ® 100% Load = (SCF/hour), Actual Annual Fuel Use (MMSCF/year) _ it' Requested Annual Permit Lim• _� (MMSCF/ year) 10,070 88.21 From what year is the actual annual amount? Indicate the type of fuel used$: ❑✓ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑ Field Natural Gas Heating value: BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 4 IA® COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit A and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? O Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM25 SOX NOx VOC CO SCO with AFRO 58.8 Other: Use the following tables to report criteria and non -criteria pollutant emissions from source: {Use -the -data -reported in Section -6 -to -calculate -these emissions-) From what year is the following reported actual annual emissions data? Permitted Criteria Pollutant Emissions Inventory Emission Factor Actual Annual Emissions' Requested Annual Permit Pollutant Emission Limit(s) Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP -42, Mfg. etc) Emissions (Tons/year) Emissions (Tons/year) Emissions (Tons/year) Emissions (Tons/year) TSP (PM) 0.00991 Ib/MMBtu AP -42 De Minimis De Minimis PM10 0.00991 lb/MMBtu AP -42 De Minimis De Minimis PM2.5 0.00991 Ib/MMetu AP -42 De Minimis De Minimis SOX 0.000588 Ib/MMBtu AP -42 De Minimis De Minimis NO 0.90 ' g/hp-hr NSPS JJJJ 12.0 - 12.0 i VOC 0.70 ' g/hp-hr NSPS JJJJ 9.3 9.3 CO 2.43 . g/hp-hr Manf Spec 32.4 — 13.3 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 ❑ No If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name _ Chemical Abstract Service (CAS) Emission Factor Actual Annual Emissions9 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) - Controlled Emissions (Pounds/year) Formaldehyde 50000 0.43 - g/hp-hr Manf Spec 11,460 .- 7729 Acetaldehyde 75070 0.00836 - Ib/MMBtu AP -42 753 / 753 Acrolein 107028 0.00514 — Ib/MMBtu AP -42 463 ., 463 Benzene 71432 Other: 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 5 I®V COLORADO Permit Number: AIRS ID Number: [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. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Legally A Ashley Brinkerhoff May 30, 2018 son (not a vendor or consultant) Date Environmental Professional Name (please print) Title Check the appropriate box to request a copy of the: �✓ Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 6 IL COLORADO Department Ma, 6 wa y,.U, RUL.ccl Z Natural Gas Venting APEN - Form APCD-211 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including 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 Natural Gas Venting only. Natural Gas Venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source. 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.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. —Permit—Number: \ W E 12.--s-7 Ams4D- Nambqf: l �� / F�� / C _ _.s^!: unless APCD a read- si ed a permit and '.IRS ID' Company equipment Identification: SEP-18 through SEP-20 P Fluitio:-lent O to io ntity How this e uiprnent is referenced i.siitisin your oream?ation] Section 1 - Administrative Information Company Name': Whiting Oil and Gas Corporation Site Name: Horsetail 07 East CPB Site Location: NWSE, Section 7, T1 ON, R57W Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Denver, 20 80290 E -Mail Address' CDPHECorrespondence@whiting.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Ashley Brinkerhoff Phone Number: 303-390-1596 Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-205 Natural Gas Ventrn7 APEN - Rev 03/2017 Envoarmenn COLORADO Atlatattitte* \, 34146 Permit Number: AIRS ID Number: tn'.ank d.PCD Has already asst fined a permit = and AIRS ID] Section 2- Requested Action ❑✓ NEW permit OR newly -reported emission source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) - OR - E 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 Et Notes: ' For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Flaring flash gas from Vapor Recovery Towers For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / / 5 / 25 / 2018 ❑Q Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions Form APCD-205 -Natural Gas Vent'ino APEN - Rev 03/2017 days/week weeks/year ❑ Yes ❑ Yes ❑✓ No E No AV COLORADO 2 I mV u4c Permit Number: AIRS ID Number: / / a,rdess APCD h.,s alreacr _ssi_ded a permit and AIRS ID] Section 4 - Process Equipment Information ❑r Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: ❑ Other Description: Serial #: # of Pistons: Volume per event: Capacity: Leak Rate: Gal/min Scf/hr/pist MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy. Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: es No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: BTU/SCF Requested: MMSCF/year Actual: MMSCF/year -OR- Requested: 1,642500 , Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: Molecular Weight: VOC (mole %) 48.73 VOC (Weight %) 70.11 Benzene (mole %) 0.280 Benzene (Weight %) 0.562 Toluene (mole %) 0.108 Toluene (Weight %) 0.257 Ethylbenzene (mole %) 0.010 Ethylbenzene (Weight %) 0.028 Xylene (mole %) 0.018 Xylene (Weight %) 0.049 n -Hexane (mole %) 1.532 n -Hexane (Weight %) 3.397 2,2,4-Trimethylpentane (mole %) 0.053 2,2,4-Trimethylpentane (Weight %) 0.157 Additional Required Information: ❑ Attach a representative gas analysis (including BTEX a n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) Form APCD-205 -Natural Gas Ventin7 APEN - Rev 03/2017 COLORADO 3 I AV Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit'; and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.8563531-103.797294 Operator Stack ID NO Discharge. Height - - Above Ground Level - (Feet) Temp ('F3 Flow Rate � , (ACFM) . Velocity ;(ft/sec)' FLR-02 40 >2000 6 0.51 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) Circular Interior stack diameter (inches): ❑ Upward with obstructing raincap 6 ❑ Other (describe): Section 6 - Control Device Information ❑✓ VRU: Pollutants Controlled: VRT Gas (VOC and HAPs) Size: 60 -hp electric Requested Control Efficiency VRU Downtime or Bypassed Make/Model: 100 14 Jordan Technologies/J-SCG10-3.05-60-4803 ❑ Combustion Device: Pollutants Controlled: VRT Gas (VOC and HAPs) Rating: 148 MMBtu/hr Type: Open Flare Make/Model: Flare Industries/SFVP-0824 Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency 98 Minimum Temperature: NA Waste Gas Heat Content Constant Pilot Light: E] Yes ❑ No Pilot burner Rating 2,152 Btu/scf 0.13 MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested 0 Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 4 �COLORADO .°,=„ Permit Number: AIRS ID Number: l!_e.ave Plank 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? ❑✓ Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SOX NO), VOC Gas is sent to gas gathering pipeline w/ open flare as backup 95% CO HAPs Gas is sent to gas gathering pipeline w/ open flare as backup 95% Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)5' Uncontrolled (Tons/year) Controlled6 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM 0.0075 Ib/MMBtu Ib/MMBtu De Minimis SOX NO„ 0.068 Ib/MMBtu AP -42 De Minimis VOC 0.979 lb/bbl VMG 112.56 - 5.63 CO 0.310 lb/MMBtu AP -42 De Minimis Benzene 0.0079 lb/bbl VMG 0.90 - 0.05 Toluene 0.0036 lb/bbl VMG 0.41 , 0.02 — Ethylbenzene 0.0004 lb/bbl VMG 0.05 - 0.002 - Xylenes 0.0007 lb/bbl VMG 0.08 ./ 0.004 - n -Hexane 0.0474 lb/bbl VMG 5.45 . 0.273 - 2,2,4-0.0022 Trimethyipentane ylp lb/bbl VMG 0.25 - 0.013 — Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 5 I AVCOLORADO �w�n `"'°�` �� a Permit Number: AIRS ID Number: unless APCD has atreadv 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. May 9, 2018 Signature of Legally ut Ariz-. Person (not a vendor or consultant) Date Ashley Brinkerhoff Environmental Professional Name (please print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) 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 Form APCD-2O5 -Natural Gas Venting APEN - Fey 03/2017 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 COLORADO 6 I A Hello