The URL can be used to link to this page

Browse Search

Home My WebLink About20190807.tiffCOLORADO Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 0 St PO Box 758 Greeley, CO 80632 February 12, 2019 Dear Sir or Madam: RECEIVED FEB 19 2019 WELD COUNTY COMMISSIONERS On February 14, 2019, the Air Pollution Control Division will begin a 30 -day public notice period for Whiting Oil and Gas Corporation - Razor 25 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 >t 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 5., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer ice- Ub1►c Q .teja) CC.PLCTQ) NL(5 ) 2/251 19 PwcS'M (ER IcttiC:h) 2114119 2019-0807 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Whiting Oil and Gas Corporation - Razor 25 CPB - Weld County Notice Period Begins: February 14, 2019 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Whiting Oil and Gas Corporation Facility: Razor 25 CPB Central Production Battery SESW SEC 25 T10N R58W Weld County The proposed project or activity is as follows: Engine, venting >:t flaring activities. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 18WE0071 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. Comments may be submitted using the following options: • Use the web form at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. This page also includes guidance for public participation • Send an email to cdphe.commentsapcd@state.co.us • Send comments to our mailing address: Timothy Sharp Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 APO d Summary of Preliminary Analysis - NG RICE Company Name Whiting Oil and Gas Corporation Facility Name Razor 25 CPB Facility Location SESW SEC 25 T10N R58W Facility Equipment ID ENG-01 Permit No. AIRS Review Date Permit Engineer 18WE0071 123/9f951001 05/16/2018 Timothy Sharp Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Caterpillar, Model G3516J, Serial Number N6W00226, natural gas -fired, turbo -charged, 4SLB reciprocating internal combustion engine, site rated at 1380 horsepower. This engine shall be equipped with an oxidation catalyst and air -fuel ratio control. This emission unit is used for natural gas compression. Natural Gas Consumption Requested (mmscf/yr) 95.64 Requested (mmscf/m) 8.12 Fuel Heat Value (btu/scf) 1020 BSCF (Btu/hp-hr) 8070 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled NOx Manufacturer Manufacturer VOC Manufacturer Manufacturer CO Manufacturer Catalyst Manufacturer Formaldehyde Manufacturer Catalyst Manufacturer SOX 0 No Control TSP 0 No Control PM10 0 No Control PM2.5 0 No Control Other Pollutants Describe EF sources - HAPs etc. Describe EF sources - HAPs, etc. Point Summary of Criteria Emissions (t Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 13.3 13.3 13.3 0.0% VOC 9.3 9.3 9.3 0.0% CO 32.4 25.4 32.4 21.5% SOx 0.0 0.0 0.0 TSP 0.0 0.0 0.0 PM 10 0.0 0.0 0.0 PM2.5 0.0 0.0 0.0 Total HAPs* 0.0 0.0 6.5 28.9% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 11460 7730 11460 32.6% Acetaldehyde 816 816 816 0.0% Acrolein 501 501 501 0.0% n -Hexane * 108 0.0% Benzene * * 43 0.0% 1,1,2,2-Tetrachloroethar * * * #DIV/0! 1,1,2-Trichloroethane * * * #DIV/0! *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT ZZZZ New/Recon 4SLB over 500 HP located at a(n) Area Source Reg 7 XVII.E Standards (g/hp-hr) NOx: 1.0 CO: 2.0 VOC: 0.7 Reg 7 XVI.B (Ozone NAA requirements) applies? No MACT Z777 (area source) Is this engine subject to MACT 7777 area Yes source requirements? NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes 0 Summary of Preliminary Analysis - NG RICE Company Name Whiting Oil and Gas Corporation Facility Name Razor 25 CPB Facility Location SESW SEC 25 T10N R58W Facility Equipment ID ENG-02 Permit No. AIRS Review Date Permit Engineer 18WE0072 123/9f951002 05/16/2018 Timothy Sharp Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Caterpillar, Model G3516J, Serial Number N6W00216, natural gas -fired, turbo -charged, 4SLB reciprocating internal combustion engine, site rated at 1380 horsepower. This engine shall be equipped with an oxidation catalyst and air -fuel ratio control. This emission unit is used for natural gas compression. Natural Gas Consumption Hours of Operation Requested (mmscf/yr) 95.64 Requested (mmscf/m) 8.12 Fuel Heat Value (btu/scf) 1020 BSCF (Btu/hp-hr) 8070 Emission Factor Sources PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled NOx o 0 VOC o 0 CO o 0 Formaldehyde 0.00 0 SOX 0 No Control TSP 0 No Control PM10 0 No Control PM2.5 0 No Control Other Pollutants Describe EF sources - HAPs etc. Describe EF sources - HAPs, etc. Criteria Emissions (t ' Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 13.3 13.3 13.3 0.0% VOC 9.3 9.3 9.3 0.0% CO 32.4 25.4 32.4 21.5% SOx 0.0 0.0 0.0 TSP 0.0 0.0 0.0 PM10 0.0 0.0 0.0 PM2.5 0.0 0.0 0.0 Total HAPs* 0.0 0.0 5.7 32.6% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants Ib/yr) HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 11460 7730 11460 32.6% 1,1,2,2-Tetrachloroethar * * * #DIV/0! 1,1,2-Trichloroethane * * * #DIV/0! 1,3 -Butadiene * * * #DIV/0! 1,3-Dichloropropene * * * #DIV/0! 2-Methylnaphthalene * * * #DIV/0! 2,2,4-Trimethylpentane * * * #DIV/0! *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minim us Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT ZZZZ New/Recon 4SLB over 500 HP located at a(n) Area Source Reg 7 XVII.E Standards (g/hp-hr) NOx: 1.0 CO: 2.0 VOC: 0.7 Reg 7 XVI.B (Ozone NAA requirements) applies? No MACT ZZZZ (area source) Is this engine subject to MACT ZZZZ area - source requirements? Yes NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes 0 Colorado Air P�rmittir�g Project PRELIMINARY ANALYSIS-PROJECT SUMMARY Project Details Review Engineer. .fiEmathy Sh�rp Package#: 3737o8��: . Received Date: lJll/241S � - Review Start Date: .Sj15/Z013 � �� Section Ol-Facility Information CompanyName: WhitingE7iS&Ga5Carpa.=�#ttin ', Quadrant Section Township Range County AIRSID: I123 � � . SESW �25 . 1GN. , �. 58 PlantAIRSID: �9P95 ' FaciliYyName: ,fiazor25��,CPS _ ,,, . ,.�.^ .. ... .., , . . _ ,�_ ... Physical Address/Location: SESw qir�rant of Se�ion 25,lowr�ship i0N,aange SSw County: Weld County Type of Facility: ;��plartian&P�d�raet'iazi_1Ffe14 Pacl .: ......_ , �. .-. .- W hat industry segment?';Oii&tvaturaf Gas PsaBuct�an&fi�rac��zna _ _ Is this facility located in a NAAQS non-attainment area? � N4 ff yes,for what pollutant? �[ Carhon Monox de(C0) [] Particulate Matter(PM) ❑ o�one�Nox�va> Section 02-Emissions Units in Permit Appiication Emissions Self Cert Engineering AIRs Point# Emissions Source Type Equipment Name Permit# Issuance# ACYion Control? Required7 Remarks _ Fe�mlt l�iteat .flfS1. �..��is��tlC21C"idS��:lc�.�-:: . �ERl�a-01��.�.. Y2S �: 18UVE0Q71 3.�� Y�S t5SU�[tC2 �� ». �..�� :-„= � �F6YTni�IIt�1C4�I � � f1�62 � �aT�ura3Gas�IC�-� ENG-�Z. Y2s �� 1SWE047Z. 1 ----�es -� #ssuanes��.. � . .:, �_. . .. _ . . __. . . � .VRUJPipe3ir2- P�rmit initiai dowrntime� 043 Se�.��aiczrw�nTin�' s2parators Yes 18WE0073 1' Yes issu�rice ' 12% .. � .. . �. .. � � � VFiUJPipetine�..� -. � � £��xi£InittaE ��downYfine�3 - .._ �_ - ;� ' -- _ "GQ� .._: ._��a�atorVent�g. � crudetan[� � 3�8s �- 18WE0Q74 E =�'2s . �_. =SSuar2ce �i�q „��, . <_. �:Vflt3JPkpel9ne . � � � Pe�r^nit'fnl�€�dc�wntime� 045 Sp�r�tffrUen�i��. watertank Yes 18WE�75 2 Yes s'ssuance 12% Section 03-�escription of Project _ �, Applicarf has cam�f�ted an Ai;ern�₹ive Emisslons Reques₹�Form aiong wl₹h a techn;ca!justificat:caii�fnr usa c`an Open Fl��e as cantral during ga5•gathering pipe3ine�. . '� downfime in the a�₹ainment are-c.This reque'st has been atrprovsd. � �� Section 04-Pu61ic Comment Requirements Is Public Comment Required? Yes' � If yes,why? Greatax thart 5D toris peryear in an h�xatnmantArea � .... . � ___._ . . . __ .... ____. _.... ' Section DS-Ambient Ac Impact Analysis Requirement� Was a quantitative modeling analysis required? 'ho' If yes,for what poilutarts? ' If yes,attach a copy of Technical Services Unit modeling results summary. Sedion 06-Facility-Wide Stationary Source Classification Is this stationary source a true minor? Na . Is this stationary source a synthetic minor? j Yes - If yes,indicate prograrrvs and which pollutantr: �5O2 N0x� CO VOC PM2.5 PM10 TSP HAPs ..... . _ ...__.. Colarad��ir Permitting Project Preventionof5ignifcantDeterioration(PSD) ❑ [� Q � � � Title V Operating Permits(OP) � � � � � � � ,�' Non-Attainment New Source Re�iew(NANSR) � �, Is this stationary source a major source? ��r� �� If yes,explain what programs and which poilutants here so2 Nox co Voc PM2.5 PMio T5P HAPs Prevention of Signifcant Deterioration(PSD) � � � � Q � Title V Operating Permits(OP) � � � Q � � Q � . Non-Attainment New Source Re�.iew(NANSR) � � Separatot Venting Emissions Inventory 003 5eparator Venting � FacllityAlRSID: _ .,:i'`3-- _ 3F96p� � a93 � : _ . »,,,.,....,� ,,.... , , . Couniy Plant Point Section 02-Equipment Descriation�etails , ,,:,.; , r - ,. ., _, ;separatarvent �urin 'as`thertn downsiEne .:�;: ,.,, . � :� , ,,;: � S€��".+� -: .: .� ;&�. $� �,. , .,., .>: _ a��: Detailed Emissions Unit Descnption: `, - ''" -^- . _ � �� - -- .. „ : , ,;,: ,,, ..:�'ii . . , ;. ,,; . .... ....,: : •Rp�n F3ar�+ �'.� "�"��' Emission Conirol Device Description� �_'; "" "� '' "' . " '' "' ��""' , ., ...,,,.� , . ,. ..: , „ ,„ . . Requested Overali VOC&HAP Control Effic ency%: . �.. . Limited Process Parometer p,.y� �•�--a�= �� ' �� . h...�:� .. W .,r .,- ,::. Gasmeter �Fas.��.5�e ,'�,,,:- :� -a; Seccion 03-Pracessine Rate Intormation for Emissions Estimates Primary Emissions-Separator ActualThroughput : �:��'�MMscFperyear RequestedPermrtLimitThroughput 73,O,IMMscFperyear Reques[edMonthlyThroughput= 6 MMscFpermonth PotentialtoEmit(PTE)Throughput= 73 MMscFperyear � Process Control(Recyding) . Equipped with a Vfttl:�is'�� '�-' �'�e Is VRU pracess equipment:��s�. � - .��Umm�trolled and contralied emissions used to establish requested permit limits are hased only on when ihe VRU is bypassed(i.e.waste gas volume that is routed to ihe flare) ....�:,,-......a_..,.. . Secondary Emissions-Combustion Devire(s)for Air Pollution Control SeparatorGasHeatingValue. ' YST.�ttf��;etu/scF Volume of was[e gas emitted per BBL of� ��,.,��F � liquidsthroughput: -'iF sd/bbl Sec[ion 04-Emissions Fac[ors&Methodolo¢ies �escription MW 27.5412'�.I6/Ih-mol DisplacementEquation . Ex=Q'MW`Xx/C Weight% Helium ��.�.'� CO2 � N2 { �,1G � _.. methane � ' :�'�.'35 3� ._ . .. . _._... . . . _._. . _ ..._ . ... . . .. ..—.. � —_... _ _. —_ .. . . ___. __—_.._ . . ._._ . ....- _.. .. _._—. ___— . __._ __—.. . . _ ethane ' ��.15 propane ' ZG.94 - iso6utane z.°3�� n-6utane 9�3' � isopentane 2 3'�� n-pentane "��i � cyclopentane �.L".37 n-Hexane a�:58 cyclohexane D.27 Otherhexanes 1 73� heptanes S.t.li methylcydohexane ..8:3? 224-TMP t�.27'. Benzene : �:�.I�: Taluene 313� Ethylbenzene ^'v"3 Xylenes � G,G'5�. � C8+Heavies 1.33 Toial �� 99.97 VOC Wt% 45.82 Emission Factors Separator Venting Umm�trolled Contralled Pollutant (Ib/MMscf) (Ib/MMscf� EmissionFacCorSource (GasThroughput) (GasThroughput� VOC 33297.6985 1564.5549 � �' �-�� " " �� -.rv�^'.: �'�G-, -�o--F eenzene 84.9�87 4.2474 �'"'� �p;f�� Toluene 9G.8552 4.8433 � "' i��+;,�yx.�� `° � . Ethylbenzene 18.3850 0.9192 �;��.,��`'� Xylene 45.9587 2.2999 '��``��i„�Py � � 1�fi `�� a _y n-Hexane 715.1239 35.7562 � � �� 224 TMP 126.2967 6.3148 ;�;-. ` �` �'(�,,,�',�,,,_ _: , . , �. ..�_ 7-:,,: Primary Contml Device Uncontrolled Un<ontrolled Pollutant (I6/MMBtu) 16/MMscf EmissionFactor5ource (Waste Heat Com6usied) (Gas7hroughpu4) PM10 0.000 ; ��.,p.� PM25 �� 0.000 � r��-� .F �.�'�' SOx ` �� 0.000 ay�, �� NOz 0.668� 105.400 �'��{}p-+f₹�„�,�°�3Y� . ��i CO fi.316C 48U.500 ,,w'.'�� ..Jq-�'1��F,ts#yEet�... _„ �,;,. ��.v.wvx.z 3 oF 14 K:\PA\2018\I8WE0073.CPl.xlsm Separator Venting Emissions Inventory Sectio�OS-Emiss' ns Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Unconirolled Controlled Uncantrolled Conirolled Conirotled (tans/year) (tons/year) (tons/year) (tors/yeer) (tons/year) (Ibs/month) rnnio o.00 o.oa o.00 o.oa o.00 0 PM2.5 0.00 0.00 o.eo o.00 a.ao 0 so. o.00 o.00 o.ao o.aa a.ao 0 PJOX 3.85 O.QC 0.00 3.U5 3.85 653 - - VOC 1P15.37 Q.Q6 0.00 1215.37 50.77 10322 CO 17.54 0.00 0.00 ll.54 17.54 7979 Potential to Emit Actual Emissions Requested Permit Limits HazardousAirPollutants Umm�trolled Umm�trolled Controlled Unca�ntrolled Conirolled (16s/year) (16s(year) (Ibs/year) �165/year) �Ihs/year� Benzene 62�1 0 0 S201 310 3.101 0.155 7oluene 7071 0 0 s071 354 3.536 0.177 Ethyl6enzene 1342 0 0 7342 b7 0.671 0.034 Xylene 3358 0 0 3'�53 3'00 1.679 0.084 n-Hexane 52204 0 0 5220d ?610 26.102 1.305 224 TMP 922a 0 0 4220 461 4.610 0.230 SectionOfi-Fe ulato Summa Anal sis Regulation 3,Parts A,B Source requires a permit Regulation 7,Section XVII.e,G 5ource is subjeet to Regulation 7,Seciion XVii.6.2,G Regulation 7,Section XVII.82.e The mntrol device far this separamr i�subject to Regu7azion 7,Section XVil.a.2e (See regulatory applicability worksheet for de4ailed analysis) � Sectio�07-Initial and Periodic Samplin¢and Tes4in¢Requiremen6 Using GasThroughput to Monitor Compiiance ��': Does the mmpany use siie specifc emission fac[ors 6ased on a�as sample to estimate emissions? �',�,�kSW;�,,,.�f;,�il��L„3,,;.,� This sample should represent the gas outlet of the equipment covered underihis AIRs ID,and should have 6een collecced witNn one year ofthe application received date However,if the facility has not heen modified(e.g.,no new wells 6rought on-line),then it may 6e app�opriate to use an older site-specific sample. If no,the permit will contain an"Initial Testing RequiremenY'to collect a site-specifc�as sample from ihe equipmerrt heing permitted and conduct an emission factor analysisto demonstrate that the emission factors are less than or equal to the emissions facmrs esta6lished with this application. . Are facilit wide ermitted emissions of VOC reaterthan or e ual to 90 tons R ��,��' � - Y- P g 9 Peryea �r...<.��...<..�. ....a&a If yes,the permit will contain: -An"Initial Testing Requirement"to collect a site-specific�as sample from the equiprnent being permitted and conduc[an emission fac[or analysisto demons[rate that the emission factors are lessthan or equal to the emissions factors esta6lished with Yhis application. -A"Periodic7esting Requi ment"to collec[a site-specific gas sample fram the equipment 6eing permitted and mnduct an emissiori factor analysis to demonstratethat ihe re . . . _ . .._. . . . . . . _ . ._ . ---�� em ssion factors are less than or equal to the emissions factors estahlished with this application on an annual basis.--� � --�-� -- - - �------� ---- � � — � �--- - - ---- Will the operator have a meter installed and operational upon startup of this point? Yes If no,the permit will contain a condition Yhai requires the operatorto calculate gasthroughput usingihe liquid ihraughput until the meter is instalied and opeational�not to exceed 180 days).This mndition will use ihe"Volume of waste gas emitted per BBL of liquidsihroughput"(scf/bbi)value in section 03. Does the company reques[a control device efficiency greaterthan 95%for a flare or combustion devire? '7�v�'3�Yg �� E;;�"� _ If yes,the permit wiil contain and initial compliance test condition to demonstratethe destruction efficiency of ihe mmbustion device based on inleY and outlet concentration sampling Ycu have indicated a6ove that th=monimred process pareme±er is natural gas uented.The foiloviing question=_do not require=_n answer. „=,.y� .,ii . _. �„_. T - ,.. ;.. . . .� r^ : /- l. - � a-.. �,'�� .,: �;. _ = ,_ .,.- . . : ' . :- . . g f:, _, l. ;." ' . ` '..,. � �� /' l' �'"� �.' -;J- ,/ �,; ' ;, u. . .,,,, � ' Y. /, .:, _.. ., • ._' - �.::.� � ' ' � � �, C ..._� :.m ...- .. .. .,,; �;; �l � l � � 4 af 14 K:\PA\2018\38WE0073.CPl.xlsm Separator Veniing Emissions Inventory 5 ct 08 T h I A I is Notes H , ,,, , . ....,., ..,. . :: ..AF,;.. ,:::,.. . , �� . .��.: . ; ;.. . �. .r, a;a/////, = _ : €-�2�PF tineotuatsmeas5ur,r�d�pMztrti'sgiasislPracessiim�cea₹<uta,€ionsi+Feas�t�4„te�.aAplacanthasfiguredumm�rrnit�,�guresbntLpElVtobel�0'lUnc4n�croli�d�emiss¢ansar�e�hexeFn��..�ea�_ena�ve. �,.�,�,f� . <.; �ii�y,�'��yoi : ��>�'v.-�� .. . . K :�: . � , �� .�Yi> ,�� . '� �€c��c6�e�<<ac��`� � . ; 1. -� � i�{��. �1'ii �� i/ ��' �yi�" 5� 6�.��: -� � �� S f h'u"� ,�� r'ii �, j � � �K � � a� �� /�"�`i � . � : �'cc ,°�f �� C �2�-�- � E�`�" � R aR ✓ � C� ��j �i'r ..._/ �� : � ��3 � � - ��v, : ,.�y . �. /�/� �: � �` ��ti : %� �c \ \ N� fi# ' � � �' ": �- ,`�`��.. ', -- „,�. � �i.�S�v�� ; �5 r ��.2 E�� "li�� .�.: iii��3�.� ��'`\ �i <- ' 2\� � �eca�Y �� a i i "\\ �/5FE�o ��ike / � m / i �l 2`� s - ��i �`��v�� x i G/// ,, i� ti'�lr'i� �\� �,�� '� Z� i // �/i- / EE�,�� : /i Y �ii� : � F�� d Il E@�L.� '��.�: _ \��, C��'°' ��kj E � ✓ia - ii d _ �.��/ � � � %,/ � �,� � j y � �, � r�,�� r y � �!�k �� ' F � , ,-......,,, ,.,_.� ,.,.,.. __._� ,.,_,_.�� .,,,,,��.H.u.��... ��,�...,....��. __� ��,.,.,,.., .,.... . Section 09-Inventory SCC Codii¢and Emissions Factors . . Uncontrolled Emissions AIRS Poinf 1F Process# SCC Code Pollutant Factor Conirol% Units 003 Ol 3-�0-001�G Plares PM10 G.oc 0 ib/NIMS[F PM2.5 0.00 0 Ib/MMSCi' ' SOx 0.06 0 :UJMMStP NOx SOS.nO 0 1�/MMStF VOC 33297.70 95 ib/Mm5CF . CO 420.Sa 0 Ib/MMSCF - Benzene 8495 95 Ib/MMSC� " Toluene 96.87 95 IbfMM5CF Ethylbenzene iS.38 95 i6(MMSCF Xylene 46A0 95 !h/MMSCF � n-Hexane 715.11 95 in/MM3CF 224�7MP 126.30 95 Ib/Po'InP�5CP 5 of 14 . K:\PA\2018\18WE0073.CP1.xlsm _ _.. __. . .... . .... ... ... ._... . _.,.,.... _ Separator Venting Regulatory Analysis Worksheet � � � Colorado Re ula[ion 3 Parts A and B-NPEN and Permit Re u enYs Soursx is in tfie Attainment Area ATTAINMENT 1 Are uncontrolled actual em ss'ons From any cr teria pollutants f�om ih 5 ndividual source g�eater than 2 TPY(Regulat�an 3,PartA,Sectian II.D.l.a)? ��Source Req 2. A�etotalfa<ilityunonirolledVOCemissionsgreaterthan5TPY,NOxgreate�thanlOTPVorCOemissionsgreaterthanlOTPY(Regulation3,Part8,Sectionll.�3�7 `-:SourceReq Source requires a permit NON-A7TAINMEM 1. Areun<ontrolledemissionsFromanycrite�iapollutantsfromthisindividualsaurcegreaterthanliPY�Regulation3,PartA,5ectionll.�.l.a)7. . . . 2. AretatalfacilityunconCrolledVOCemissionsfromthegrea[erthan2TPY,NOxgreaterthan5TPYorCOemissionsgreaterthan]DTPY(Regulatian3,PartB,5eciionll.D.2�7 You have indicated that sourre is i�ihe Attainment Pree Colorado Reeulation].Seciioe XVII 1. Was the well newlv�onstrmcted,hydraulicallyfractured,or recampleted on or after August 1,20142 Y85�:: ::Source is s� Source is subjecx xa RZQulation]Secton NVII.8.2 G � Sec[ion XVII.B.2—General Provisions forAir Pollution Control Equipment and Prevention of Emissions Section MVII.G-Emissians Cont�ol AlternaNye Emissions Conirol lOptional5ection) a. Is this separator controlled 6y a back-up or alternate combustion device(i.e.,notthe primary roMrol device)that is nnt enclosed7 ____ The coMrol Thecont�oidevice₹or:hisseparatorissuhjectteasgulotian]SectionXVil.8.2.e � I SecHon XVII.B.2.e-Alternative emissions control equipment Disclaimer This documerd assists ope2tors wifh determining applicability of certain requiraments of tha Clean AirAct,i4s implementing regulations,and AirQuality Cortfro/Commission regulations.This document is � not a rule orregulation,and fhe ana/ysis it contains may not applyto a parficular situation based upon the individual facts and circumstances.This document does no[change or subsfitufe foranylaw, regulaG'on,or any othe�legally binding requirement andls not legally enfolceable.In the event of any contiict behveen the language olthis document and the language ofthe Clean AirAct„its implementing regulaU'ons,aod Air QualityConfrol Commission 2gulafions,the language of the statute orregulation will control. The use of non-mandatorylanguage such as"recommend,""may,""shoultl,"and"can,"is intended fo descnbe APCD interpretations antl recommendations.Mandatory terminology such as"musC'amJ"required"are intended to describe controlling reyuirements under the ferms o(the Clean Air Act and Air qr�ality Confrol Commission regulafions,buf fhis tlocument does not establish legally binding requirements in and o(itse/f. � . . ... .. . _ __. . . .._ .. .. .. . . . _ _ ._... . . .. . Separator Venting Emissions inventory 0045eparator Venting � .r IY3;u„cs,_,4I....,£E�.;�-.9695 �i ,,, Eati Q44,.�;:: �a....�.: FacilityAlRs ID: �ounty Plant Point Section 02-Eouioment Description Details '�tznbngsrarnprsgsGr'°` Qx[vessr�y�u�ac�gpGpeHne'+�awne¢me� ;, a a� -: _ ;z:< Detailed Emissions Unit Des<npnon a��; _�,,,,,,,';� �� , _ ��. .;��.. , „,,,,��,.�„�x�a�,a,�,,,,w;, ,,,,,,, „�- ��;.,,��„�, ctpen€iazc�'�� , ..� ', 1��€E�.:�� i� Fmission Control�evice Desmption .: z�a��,�,,,, •� �',, : �� EE`�,.:.r�C��, .,-,,,, , ,., ,: ... . ,, , . ,,,.E�� `Ca°a.s,.a,...,,,.„ . ..,. ,,',;,�. Requested Overall VOC&HAP Control Effinency/. ,��F,,,,, 9S��.,; . Limited Process Parameter �SdfrgC��T#�,',iµ, � ��'��',.,� �� Gasmeter ��rrr er�sc.uga«ftyu'�i� ��ss - �.'3� — _r_.. . _ ... Section 03-Processine Rate Indormation for Emissions Estimates Primary Emissions-Separatoe . ActualThroughput=z �� .:-.iMMscFperyear q g p �, k�MMscFperyear RequestedMonihlyThroughput= � MMscFpermonih . , Re uested Permit LimitThrou h ut ; � � �� PatentialtoEmit(PTE�Throughput= 4MMscFperyear Process Control��Recycling) Equipped w th a VRU:�� Is VRU process ecpwpment.��,r��.��Uncontrolled and mntrolled emissions used to esta6lish requested permit limits are 6ased only on when the VRU is bypassed(i.e.was[e gas volume that is routed to 2he flare) Secondary Emissions-Combustion Device(s)for Air Pollution Control SeparatorGasHeatingValue: - 235fl'-8tu/scF Volume of waste gas emitted per BBLof� liquidsthroughput: t!'�. scf/hbI . Section 04-Emissions Factors&Methodolo¢ies � D scr�p[�on � ��. ,�'� �l r f��'��'� , : � : \ ��- /% v `_/� : � ., i, ah ' , � '; � •� :: re � /��; _ �� i ii ; „ // '..//,,,,/,. ;>-i'., 3,,,�„� '.��..�F.l�� .... ''�. , ,,; ,.. . �„-;,,,,.,,c�; � „z<&'/e,...,.i: ,,. .,. . .......�' ��,�i�/,y , . ,,,, ,,,,��..... ... . . MW „�F3.6EtfE Ih/Ib-mal _.. . DisplacementEquation . . . Ex=Q*MW*Xx/C � Weight% Heliurti ;.�� f7.tll5; CO2 1:SS' N2 .:.`; 2.?# � ._ _ methane _. . _ . . ., : •xqq . ____ . ..._ .... _ ... _. ._. .._ ._ . _ ... ... .. _. .. .._. _ . . .._ — _ _ "� . — —___—_ — _ —. _.___—__ _ _.___. — .__—_—_ ._ __ _-__—_— ___ __ . ethane •.:, t'2.t1S: . propane ii� ,��%%i%36.7��. iso6utane �?� ;��,S.84'�. . � , mbutane ��^:I�k�£15'�. isopentane �� ....:�_.�-� �4'�4A'�. n-Pentane „�,,,.. ��".�.�8' cyclopentane a.d8'. n-Hexane %/ .-.13t1'�, cyclohexane ''�+'.'.u,��;if:28��: Other hexanes ....7��b`- , ,��35"�. � - � heptanes f��:83 . _ . . methylcyclohexane •`.(i:'��€ � 224-TMP �3`,�:, I :'U.l''-€: . � eenzene �•°. �� ,,,Q.� Toluene ,�au,;,,,.J. �=1#:'flfi Ethyl6enzene ,..tS.0S Xylenes �� "`C�.fl2'�. . C8+Heavies ',.6:6��. Total � 99.30 � NOC Wt°/a - 79.03 Emission Fac[ors Separamr Venting Uncontralled Controlled Pollu4ant (Ib/MMsci) (16/MMscf) EmissionFactor5ource (GasThroughput) (6asThroughput) VOC 9Y987.5135 45543757 - h Benzene 145.2182 7.?6fl9 '��'�n�`�,`5''� ~\ �� Tal�ene 82.059& 4.133D '��-� .<+`�:�'��'„ � Ethylbenzene 8.7592 0.4380 � �^��,�. �'�y� �, %ylene 19.5925 0.9795 `� s a��•��"`-��\ h n-Hexane 1498.3978 74.9199 �� '"i','' ≥ � ��.��4c� . 224TMP 161.0078 IIA504 �n.�„�.,k.:. , .o,x,,,.,,;"' �...,,....,: Primary Contral Device Uncontrolled Umm�[rolled � Pallutant (Ib/MMBtu) 16/MMscfi EmissionfactorSouece - (Waste Heat Combusted) (GasYhroughput) PM10 ��' '. OA60 c'��F� ,,,� r� � :,�.�.#'es"°"�Y^Si��. PM2.5 c : '�'�: O.OOfI �� 1.a-�a�s�l�'� ��' ��., SOx " �'''�.�� 0A60 � � � �� s,�� '�?�i�`�,�,�'c� �'�� `ti� NOx Q�6�k 159.800 , '. .-. . -... �cn.i�+•. CO 4Y3�.tlG , i 728SG0 .- ._ . ..;,.us,,,'�n`,�� ...,: 7 of 14 K:\PA\2018\18WE0073.CPl.xism Separator Venting Emissions(nventory Sectian O5-Emissions Inventory PoteMial to Emit Actual Emission Requested Permit Limits Requested Monthly Limits Criteria Pollutants Umm�trolled Unconirolied 5 controlled Uncamtrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (Ibs/month) PM10 0.00 9.60 L�.(30 6.ba 0.00 0 PM2.5 0.0Q 0.00 a.a0 O.Op 0A0 o , sox o.no �.00 a.�o a.ao c.00 0 Nox D32 o.oa o.ao osz oaz =s � VOC i2�4.95 0.00 C.40 184.45 4.22 155i� CO 1.48 0.00 0.0� 1 c8 1.48 252 Poten[ial to Emit Actual Emission Requested Permit Limits � HazardousAirPollutanis Umm�trolled Uncontrolled 5 Conirolled Unc�trolled ConCrolled (Ibs/year) (Ihs/year) (Ibs/year) (Ibs/year) (I6s/year) . 6enzene 585 0 6 Sg3 39 0.294 0.015 Toluene 332 0 0 332 17 0.166 0.008 Ethyl6enzene 35 0 0 35 2 0.018 0.001 Xylene 79 0 0 79 4 0.040 0.002 n-Hexane E069 0 L' 5�69 303 3.034 0.152 224TMP 65i 0 0 E52 33 0.326 0.016 Section O6-Reeulatory Summary Analysis Regulation 3,Parts A,B 5au:ca requires a permit - Regulation 7,Section XVII.6,G Saurce is subjac:to Regulafio:�7,Ss<tion XV11.8.2,G Regulation 7 Section XVII.B.2.e The cor.frol derrive far chls separa₹o:is subject to Regulation 7,Seccion R`Jil.s.2.e (See regulatory applicability wod<sheetfior detailed analysis) Section 07-Initial and Periodic Samplire¢and Testine Reouirements Using Gas Throughpuk to Monitar Compliance �,r= f;: Does the company use site specific emission factors 6ased on a+�as sample to estimate emissions? ,�'ffi'.�'/��'� This sample should represent the gas ouilet ofthe equipment mvered underthis AIRs ID,and should have 6een collected within one year of the application received date.However,i{ the facility has not heen modified(e.g.;no new welis brought on-line),then it may 6e appropriate to use an older site-specific sample. If no,the permi₹will contain an"Initial Testing Requirement"to mliec[a site-specific�as sample from the equipment 6eing permitted and conduct an emission factor analysis to demonstratethatthe emission factors are less than or equal to the emissions factors estahlished with ih's application. Are facilky-wide permitted emissions of VOC greater than or equal to 90 tons per year? �� --: _,.,_............... If yes,the permit will contain: � -An"Initiai Testing BequiremenY"to collect a site-specific gas sample from the equipment 6eing permitted and conduct an emission factor analysis to demonstrate that ihe emission factors are less Yhan or equal to the emissionsfactors esta6lished with this application. ' - -A"PeriodicTas4ing RequiremenY'to coliect a site-specific gas sample from the equipmen4 4eing permitted-and conduct an emission factor analysis to demonsiate that the . ___.. ... .. . . _ __ . ... . . _ . . __ _._. _. . . ._ . ... --�- ---��emissionfactorsarelessthanorequaltotheernissionsfactorsestablishedwiihthisapplicationonanannual6asis.------- -�-- ---- -- --- ------- . --- ---------- � � --- - ----- -- Will the operator have a meter installed and operational upon startup of this point? _ If no,the permit will contain a condition thac requires the aperatorto calculate gas throughpui using Yhe liquid throughput on4il ihe meter is installed and ope�ational(not to exceed 180 days�.This condition will use the"Volume of waste gas emitted per BBL of liquidsthroughput"(sd/661)value in section 03. . Does the company request a wntrol device efficiency greaterthan 95%for a flare or comhustion device? �',_, ty ,, If yes,the permit wili contain and initial compliance test condition to demonstratethe desiruction e�ciency of the combustion device based on inlet and outlet concentration sampling You have indicated aaove thaY the.mo�Yored pra<=ss par=_me?Ur�s natural gas verYed.Tne fo?Io:vEttg ques4ions do noe require ar znsw=r. . � �-� �a• ;,,. � " ,:..._. , .- /�^ /. . . . :ri- �" r� . ," ?- ... . . ,-,r"� ...� . .a.,. _ �� l"�1�,�lfr �: r 9f . �'_ . -" , oi . .._ ._,. .,',x. . _ _ , / ' � / .� w, s;� � la � � �_ l O�"�� :' �_; �m ... � � . 8 of 14 . K:\PA\2018\18WE0073.CPl.xlsm Separator Venting Emissions Inveniory se�tio�oa-re�h�t�ai n�ai sis Noees ;�EY9G pipe�lne downtiima a,5sumed fpr emrssionsjproceis latn9tcalcutations:Please note,��SpfiranY:has figurad�tnicprrtrolkd it�iires an APEN'tp be lOq'�.Vncanetmkteci emis�₹ons are,tfierefnre conseruative. � Sectian 09-Inventory SCC Godn¢and Emissions Factors Uncontrolled Emissions AIRS Point# Process# SCC Cade Pollutant Factor Control% Units 004 Ol 3-'i�-00'I-60Flares PM10 0.00 0 Ib/MMSCF PM2.5 0.00 0 Ib/MMSCF SOx 0.00 0 Ib/MMSGF NOx 159.80 0 Ib/MMSCF VOC 91087.SY 95 Ib/MMSCF CO 728.50 0 Ib/Mh95CF Benzene 14512 95 Ib/MMSCF Toluene 82.06 95 Ib/MMSCF _ Ethylbenzene 8.76 95 Ib/MM5CF Xylene 19.59 95 Ib/MMSCF n-Hexane 1445.40 95 Ib/MMSCF . 224 TMP 151.01 95 Ib/MMSCf . . . _ _.. ._ .__ . _ . _ . . . g a{14 K:\PA\2018\18WE0073.CPl.xlsm � SeparetorVentingRegulatoryMalysisWorksheet . Colaradofte ulatlon3PartsAandB-APENandPermitRe ulrements Source is in the Attainment Area ATfAINMEM 1 Are uncantrolled actual em ssions from any cr ter a pollutan[s from N s ndmdual source greaterihan 2 TPY(Regulat�on 3,Part A,Sect on II D l.a)7 -5 e fteq 2 Are total fac I ty un onhalled VOC em'ss'ans greater ihan 5 TPY,NOx grea[erthan 10 TPY or CO em ss ons greaterlhan 10 TPY(Regulat on 3,Par[B,Section II.D.3)1 Yeh%.��":'��,��;Saurce Req c So�rce requlms a permit NON-ATTAINMENT 1. Areuncontrolledemissionsfromanycriteriapollutantsfromihisindivid�alsourcegreaterthanlTPY(kegulation3,PartA,5ectlonll.�.i.a)? 2. AretotalfacilltyunwntrolledVOCemissionsfromthegreaterthan2TPY,NOxgreaterthan5TPVorCOemissionsgreaterfhanlOTPY�Regulation3,Parte,Section11.0,2)7 Vou ha�e i�dicated thet source is in the Attainment Aree Colorado Re¢ulaMon 7,Sec[lan xVll 1. WasthewellnewlYconstructed,hydraulicallytractured,orre<ompletedonaraRerNugusY1,20147 _ „��Sourcelssi Sou�ce is sublect to fteeulaxion],Sec[ion%V11.8.2,G ' Sectian%V11.8.2-General Pravisians for Air PolluYian Cont�ol Equipment and Prevention of Emisslons Sectlon%VII.G-Emissions Control Aliernative Em�ulons Controi(Oot onai 5ec[on) a. Is th s separator cantrolled by a ba<k up or alternate<ombust'on dev re('.e,natthe pnmary mntrol dev'ce)Nat is not enclosed7 �The control ITheconlroldevicefarinissepamiorissvbieRtoRegulation]SeRionXV11.8.2.e � � � Sectlon%VII.B.2.e-Altemative emissions control equipment Oi5claimef 7his document assists operators with defermining applicability of certain requirements of the C/ean Air Act,ifs implemenGng regulafions,and Air 4ualityCordrol Commission iegulafions.This documenf is not a rule orregulation,and the analysis it confains may not apply fo a paRicular situation based upon(he indivitlual/ac�s and circumstances.This documenf does not change orsu6stifute loranylaw, regulatton,or any otherlegally binding requirement and is not legally anforceable.ln the event of any conflicf between fhe language of fhis documenf and fhe language of fhe Clean AirAct„ifs implementing regulations,andAirQualityConfrol Commission regula6ons,the language ol fhe statute or regulaG'on will control. The use ofnon-mandatorylanguage such as'recommend,"'may,"'should,"and'can,"is intended fo descnbe APCD interpretations andrecommendations.Mandafory terminology such as'musl"and°required"are intended to dascnbe confrolling requi�emenls undarfhe terms o/the C/ean Air Acl andAir Quality Conirol Commission regulaG'ons,but this documenf does nof establish legally binding requirements in and ofitself. Separator Venting Emissions Inveniory 005 Separeror Venting `i, ,,,,,,,123°.vi„ , ::"� 3F95 .: - D45..::.�....:t FacilityAlRsID: County � Plant � �� Point 5ectioo o2-Equipment�escriQYion�etails � P" --2"t7"�i ' :: : S k:F uen�₹»sass�a-v�kwtt�prpzf3rednwnkii»essprgssurFse �cedu�a`te�preerssuasse3 .: : : ..�: Detailed Emissions Unit Descr pt on ,'. �� ,,,.,,: _,/�;,,cs��s��.�..:', �,,,,,,,, �� ,:��.�»;a. ,...� :Ctpen 3ar� ,.. ',. , . : y - . : � � Emission Cantral Device Descripnon: ,'�, ,;-,, ,., ,�: ,,,, � „ �''�, yii� ;, -; ��.,v,l„y„ � ,,,,,�'. �?� ".'�... I Requested Overall VOC&HAP Control Efficiency%: 9S ;;. , � Limited Process Parameter '�r�te3r,.�� : �� "�'� - Gasmeter .Y��s,mei�[:�___, _ ,_, .� Section 03-Processin¢Rate In#ormation for Emissions Estimates Primary Emissions-Separator . • ActualThroughput �' ��,;MMscFperyear RequestedPermdLimitThroughput S,S"MMscfperyear RequestedMonthlyThroughput= o MMs6permonth PotentialtoEmit(PTE)Throughput= 2 MMsciperyear _ Process Control(Recycling) � Equipped wrth a VRU�p`�c : �`" \ Is VRU process eq ip ent ',�s�� Uncontrolled and controlled emissions used to establish requested permit limits are based only on when the VRU is 6ypassed(i.e.waste gas volume that is routed to ihe flare) Secondary Emissions-Com6ustion Device�s)for Air Poliution ConYrol Separator Gas Heating Value: � '�.�2d17IsBtu/sd Volume of waste gas emitted per BBLof liquids throughput: scf/hbl Section 04-Emissions Factors&Methodolo¢ies D iph n „ . i� . r � '�'� �. .: , : g��`°�� ... ��y� / i �; 5 % ' �"R`�i� - ,.„ �� RF 3' ��!�ii,,, �:: , ,,;" ti�� ,",��,,,�,,;,_,, ., ��c;,,,,,�,., �� ,� i ,;�� MW '�25:£RS':!Ib/16-mol Displacement Equation . . � Ex=q*MW*Xx/C Weight% Helium -��i.;,,, .::::::n=€i� � . CO2 ':� > ,;`.1�::�8; N2 ' .:•�� '!, r&�3a": _ .._._ � methane ....__ ... _ .�::: �! Z5r�' ____ ._ . ...._�:- _.. ._� . . ... . � _ -. __ _ . .. . .. - . .. . ._.____ _.__. . _--___—. _ - _ __ ._._ _-- _—_ . � ethane '��28�7;9� � propane ��Z�3.�f1; - iso6utane �� , s 2.89 n-hutane ii�',L�p�,:3`7,2$'.. sopentane �`�`�,a��/,/°!;:;"'.t''flP�: . n-pentane ,aa.,. , '1:27'�. � cyclopentane ��. •'"0.�3! � , , � n-Hexane �!�0.75 . � _ cyclohexane , �4, �," !�.23:' Otherhexanes ��„ix:1t} � � heptanes - ;��Qs�.9�i m ethylcycbhexane ,...`:��7.°��,�-��- - 224-TMP `�. �7;;� � . Benzene �� -C3�2�a Toluene ;Q,1; Ethylbenzene ;II.{}k � Xylenes � ^.��a�' � , C8+Hea ,.4:22� Total �a10�.00 - V�OC Wt% 38.41 Emission Fac[ors Separator Venting Uncontrolled Controlled EmissionFactorsource Pollutant (16/MMsc� (Ib/MMscf) (Gas Throughput) (Gas Throughput) VOC 29501.3745 1375.0937 ''�i ��Y��t�+�4tly� �. Benzene 1a3.70b2 9.6&53 �� '' �� `� a�; Taluene 9&.9269 4.9C63 ��'" � � ` �� Ethyl6enzene 6.5285 0.3264 � - ��`°� - � . Xylene 15.E990 0.7°4S ;�i�� - �a�� ',s��r zti�� n-Hexane 60�.9283 30.2464 y�, � - � �� ;��$ �c�., �`�� 224 TMP 39.5554 1.9775 �,s?,,,�`,�'�.,s,..,,,,.. ' Primary Control Device Uncon[rolled Unwntrolled Pollutant (Ib/MMStu) I6/MMscf EmissionFactor5ource (WasteHeat . Combusted) �GasThroughput) " PM10 ��_.?,;;'. 0.004 �` �. �C 5 .'s F„,;�?:. PM2.5 :C ' 0.000 �Ta� '� '"y� - �'*�u��`�: sox ��3�s;r.., o.noo �`�� .�� Nax ��tkassv ,;�. ss.sao `�' �. -- er�.�;��,�t�3�'�,�� CO ,,._6s3��t3:, .. 437.100 ;�: .�Ld ..�u,5��itx�Ye's,.�.....- 3'f 11 of 14 K:\PA\2018\18WE0073.CPl.xlsm Separator Jenting Emissions Inventory Section 0S-Emissions Inventory Potential to Emit Actual Emissions Re�uested Permit Limits ftequested Monthly Limits Cnteria Poliutants Uncontrolled Unconirolled Controlled Unconirolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tans/year) (Ibs/month) PM10 0.�0 QA0 6.J0 9.G6 0.�9 4 PM2.5 0.a0 0.00 0.C0 fl.Q0 0.�0 0 � SOx DA� 0.00 Q.60 0.00 0.00 0 NOu �.�3 C.00 a.a0 6.07 0.�7 � 12 � - VOC 2Z.i3 G.0C 0.�0 R.13 l.il ?83 CO 0.33 0.00 0.00 �.33 0.33 55 Potential to Emit Actual Emissions Raauested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Umm�trolled Controlled � (16s/year) �Ihs/year� (Ihs/year) Q6s/year) (16s/year� Benzene Z?1'_ 0 6 29? ?5 0.145 0.007 Toluene 148 0 0 14'H 7 0.074 0.004 Ethylbenzene 1C o il 1U 0 0.005 0.000 %ylene ZR 0 0 2'i 1 0.012 0.001 n-Hexane a07 0 0 907 45 - 0.454 0.023 224 TMP 59 0 � 0 59 3 0.030 0.001 Section 06-Re ulato Summa Anal i Regulation 3,Parts A,6 5ource reouires a perm.iz Regulation 7,Section XV�II.B,G Source is sub�ect to°egulation 7,Sect€c�3 XV11.81,G - Regulation 7 Section XVil.B.2.e The cor,trol dwi<e for YhEs separator is suhject io Rag.ulatian 7,Sectinn XVl1.e.2.e (5ee regulatory applica6ility worksheef for detailed analysis) Section 07-Initial and Periodic 5amplia¢and Testin¢Requirements Using Gas Throughput to Moni₹or Compliance � � Does the company use site specific emission factors based on a gas sample to estimate emissions? � This sample should represent the gas outlet of the equipment covered underthis AIRs ID,and should have heen collected within one year ofthe application received date.However,if Che facility has not been modified(e.g.,no new wells 6rought on-line),then iY may be appropriate to use an older site-specifc sample. If no,ihe permit will contain an"Initial Testing Requirement"to collect a site-specific gas sample from the equipment being permitCed and conduct an emissio�factur analysisto demonstrate that the emission factors are less than or equal ta the emissions factors established with this application. - �Are facility-wide permitted emissions of VOC greaterthan or equal to 90 tons per year? __„� � � � If yes,the permit will contain: -An"Initial7esYing RequiremenY'to mllect a site-specifc�as sample irom the equipment 6eing permitted and conduct an emission factor analysis to demonstrate thaithe emission fac[ors are lessthan ur equal to ihe emissions factors estabiished with 4his application. -A"PeriodicTesYing RequirernenY'2o collect a site-specific gas sample from the equipment heing permiited and conduct an emission factor analysis to demonsirate that ihe . . .. _ .. .__.... .. _ _ .. .._. _. �._ _ .. _ _ _..:. . . ___. _ . . �-� —�-- em sslon factors are less than or equal to the emissions factors esta6lished with this application on an annual basis.- — --�—��- �- - - --------—� --- -------- ----------- ------ �- ----- Will the operator have a meter ins[zlled and operational upon startup of this point? Yes If no,the permit will contain a mndition tha#requiresthe operatorto calculafe gas throughput using Yhe Iiquid thmughput until the meter is installed and vperational(not Yo exceed 180 days).This condition will use the"Volume of�Naste gas emitted per BBL of liquids throughpuP'(sd/661)value in section 03. � Dces the company request a mntrol device efficiencygreaterthan 95%for a flare or com6ustion device? Ik,t ��'-;��.�,��`,`� If yes,Yhe permit will mntain and initial compliance test condition to demonstrate the desiruction e�ciency of the wm6ustion device based on inlet and outlet conceniration sampling You have indicaYed above ihat The mor�l2or=d orac=ss parameYer Is naturzl gas vented.Tne foliow:ng qu=_stEons do not requ�re an answer. e �.. . . . ,., ..., �- , .�" �,..� ,,, �,..' � ,- �,.. - ' . .. " � //.-•, � . /. :; �. �< ' r'` l�-� l ,.F - / �. ��= l l r-rs ;� � � l n i . , 12of14 K:\PA\2018\38WE0073.CPS.xism Separator Venting Emissions Inventory s tion OS Te hnical A�s�s Notes 72f prpe.f�'�e ttownYrme assumed fUr ettt`issfon5fp�o.re;slirFi#��+IcWaS oqs.P�eflsen'ota,��;Ccznt;nas₹igu-ee�ur�eoMmlled{(�ures or�APEN₹o Ue 1G0%.Uflcan�trallederois�ori�are,[harefcre coe;ervaUve Section 09-Inventory SCC Co�nQ and Emissions Factors Uncantrolled Emissions AIRS Point# Process# SCC Code PollutanY Factor Control% Units 005 Ol 3-70-00'i-&0 Fiares PM30 0.00 0 ib/MMSCF � PM2.5 0.00 0 Ib/MMSCF � SOz o.oG 0 Ib/PlIM5CP NOx 95.88 0 14/MMSCF VOC 29501.87 95 16/MMSCF CO 437.16 0 Ib/MMSCF Benzene 193.77 95 ih/MMSCF Toluene 98.93 95 Ib/MMSCF , Ethyl6enzene 6.53 95 Ib/MMSCF Xylene 15.90 95 Ib/MMSCF n-Hexane 604.53 95 Ib/MMSCF 224 TMP 39.56 95 ib(MMSCF 13 of 14 K:\PA\2018\18WE0073.CPl.xlsm Separator Venting Regulatory Analysis Worksheet CaloradaRe�latlon3PartsNandB-APENandPermitReu ents Sour<e is in the Attainment Area AT(AINMEM � 1. Are uncontrolled actual em'ss�ons from any cr ter a pallutants from th s nd v dual source greater than 2 TPY(Regulat on 3,PartA,Sectlon II.D.1 a�7 ,8'-'�`5 e Req 2 Are total fac I ty uncantrolled VOC em ss ans greater than 5 TPY,NOx greater than 10 TPV or CD em sslons greater than 10 TPY(Regulatlon 3,Part B,Section II.D.3)? '(.E5 Sourre Req Source requlres a permit NON-ATTAINMEM _ 1. Are uncontrolled emissions f�om any cn[eria pollutants from[his indlvidual saurce g�eater than 1 TPY(Regulation 3,Part A,Secfion II.D.l.a�? 2. Aretotalfacilityumm�trolhedVOCemissionsfromthegreaterthan2TPV,NOxgreaterthan5TPYorCOemissionsgreaterthanlOTPY(Regulation3,Parte,5eNanII.D.2)7 You ha�e i�dicated that source is in ihe 0.ttaimment Area [olorado Ra¢ulation 7,Sectlan%VII ,� �� 1 wasthewellnewtymnstructed,hydaulicalWfractured,arrecompletedonarafterAugust1,20147 g�5 urceisst Source-s subjectto ftegulat on]Section X411.6.2 G � � SeRion XVII.8.2—General Provisions for Air Pollutlon Cantral Equipment and Prevention of Emissions Seccion XVII.G-Emissions Control Alternative Emissions Cari[ro110pilanal5eRlo�1 � � a. Is this separator controlled by a back-up or aliernate combustion device(I.e.,noi the primary mnhol device)that is rnt endosed7 �,;.��.�`�°;�The control Theconvoldev'cefarth�ssepaatorissubjec[ioRegulation]SeRionXVl1.8.2.e �� Se�tinnXVll.9.2.e—Alternative emissians conirol equipment Dlsclaimer This documerd assrsts ope2fors with deteimining applicability of certain requirements offha C/ean Ai�Act,its implemenb'ng regulations,and AirQuality Co�frol Commission regulaG'ons.This document is nof a rule o�regulatlon,and the analysis il contains may not appry to a particular sifuation based upon Ihe indivitlual/acts and circumsfances.This tlocuma�does nof change orsubsfitute for any law, regulat'on,or any otherlegally binding requiremenf and is not legally enforceable,In the event of any conRict between the language o(this documenf and the language offhe Clean AirAct„its implementing regulations,aod AirQualiry Control Commission iagulations,the lan9uage of the stafute orregulafion will contro/. The use of non-mandatory language such as"racommend,""may,""should,"and"can,"is intended to descnbe APCD interpretations and recommendafions.Mandatory terminology such as"musf"arN"required"are infended to describe confrollinqrequi�ements underthe terms o(the Clean Air Act and AirQuality Control Commission regulafions,buf this document doas nof esfablish legally binding re4uiremenfs in and ofifself. STATE OF COLON COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 PERMIT NO: 18WE0071 CONSTRUCTION PERMIT Issuance 1 DATE ISSUED: ISSUED TO: Whiting Oil and Gas Corporation THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Razor 25 CPB, located in SESW SEC 25 T10N R58W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description ENG-01 001 - One (1) Caterpillar, Model G3516J, Serial Number N6W00226, natural gas -fired, turbo -charged, 4SLB reciprocating internal combustion engine, site rated at 1380 horsepower. This engine shall be equipped with an oxidation catalyst and air -fuel ratio control. This emission unit is used for natural gas compression. This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar, Model 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 THOSE 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. The Notice of Startup form may be downloaded online at https://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 No. 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 AIRS ID: 123/9F95 Page 1 of 15 NGEngine Version 2014-1 compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). Public Health and Environment Air Pollution Control Division 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 per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, 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. (Reference: Regulation No. 3, Part B, Section III.E.) 5. The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • manufacture date • construction date • order date • date of relocation into Colorado • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, 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 (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Monthly Limits: Facility Equipment ID AIRS Point Pounds per Month Emission Type NO. VOC CO ENG-01 001 2262 1585 4524 Point (Note: Monthly limits are based on a 31 -day month.) The owner or operator shall calculate monthly emissions based on the calendar month. Facility -wide emissions of each individual hazardous air pollutant shall be less than 1,359 lb/month. AIRS ID: 123/9F95 Page 2 of 15 Public Health and Environment Air Pollution Control Division Facility -wide emissions of total hazardous air pollutants shall be less than 3,398 lb/month. Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type NOX VOC CO ENG-01 001 13.3 9.3 26.7 Point See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility -wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 8. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility emission limitations as seen below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Total emissions from the facility, including permitted emissions and insignificant activities, shall not exceed: • 100 tons per year of any criteria pollutant and/or 9. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled ENG-01 001 Selective catalytic oxidizer and air/fuel ratio controller CO AIRS ID: 123/9F95 Page 3 of 15 Public Health and Environment Air Pollution Control Division 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 rate shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 days) ENG-01 001 Consumption of natural gas as a fuel 95.7 MMscf/yr 8.2 MMscf/month Fuel consumption shall be measured by one of the following methods: individual engine fuel meter; facilty-wide fuel meter attributed to fuel consumption rating and hours of operation; or manufacturer -provided fuel consumption rate. The owner or operator shall calculate monthly process rates based on the calendar month. During the first twelve (12) months of operation, compliance with both the monthly and annual throughput limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 11. 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) 12. 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. & 4.) 13. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) OPERATING & MAINTENANCE REQUIREMENTS 14. 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 your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) AIRS ID: 123/9F95 Page 4 of 15 Public Health and Environment Air Pollution Control Division COMPLIANCE TESTING AND SAMPLING Periodic Testing Requirements 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: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative -operating scenario and is installing a permanent replacement engine. 18. Federal regulatory program requirements (i.e. PSD or NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS AIRS ID: 123/9F95 Page 5 of 15 Public Health and Environment Air Pollution Control Division 19. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 20. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self - Certify for Final Authorization section of this permit. 21. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 22. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 23. Each and every condition of this permit isa material part hereofandis not -severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 24. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 25. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. AIRS ID: 123/9F95 Page 6 of 15 By: Public Health and Environment Air Pollution Control Division Timothy Sharp Permit Engineer Permit Histo Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation AIRS ID: 123/9F95 Page 7 of 15 Public Health and Environment Air Pollution Control Division Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: https://www.colorado.dov/pacific/cdphe/aqcc-reqs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emission Rate (lb/yr) Are the emissions reportable? Controlled Emission Rate (Ib/yr) 001 Formaldehyde 50000 11460 YES 7730 Acetaldehyde 75070 816 YES - Acrolein 107028 501 YES - n -Hexane 110543 108 NO - Benzene 71432 43 NO - 5) The emission levels contained in this permit are based on the following emission factors: Point 001: CAS Pollutant Emission Uncontrolled Ib/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr NOx 2.73E-01 1.00E00 2.73E-01 1.00E00 CO 6.64E-01 2.43E00 5.21 E-01 2.00E00 VOC 1.91E-01 7.00E-01 1.91E-01 7.00E-01 50000 Formaldehyde 1.17E-01 4.30E-1 7.90E-02 2.90E-01 75070 Acetaldehyde 8.36E-03 - 8.36E-03 - 107028 Acrolein 5.14E-03 - 5.14E-03 - Emission factors are based on a Brake -Specific Fuel Consumption Factor of 8070 Btu/hp-hr, a site -rated horsepower value of 1380, and a fuel heat value of 1020 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Catalyst Manufacturer AIRS ID: 12319F95 Page 8 of 15 Public Health and Environment Air Pollution Control Division CAS Pollutant Uncontrolled EFSource Controlled EF Source VOC Manufacturer Manufacturer 50000 Formaldehyde Manufacturer Catalyst Manufacturer 75070 Acetaldehyde AP -42 AP -42 107028 Acrolein AP -42 AP -42 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 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.gov/ttn/atw/area/fr18ia08.pdf 8) This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www. epa.gov/ttn/atw/area/arearules. html 9) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC; HAP PSD or NANSR Synthetic Minor Source of: VOC MACT ZZZZ Area Source Requirements: Applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A — Subpart KKKK NSPS Part 60, Appendixes Appendix A — Appendix Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A — Subpart Z MACT 63.600-63.1199 Subpart AA — Subpart DDD MACT 63.1200-63.1439 Subpart EEE — Subpart PPP MACT 63.1440-63.6175 Subpart QQQ — Subpart YYYY AIRS ID: 123/9F95 Page 9 of 15 Public Health and Environment Air Pollution Control Division MACT 63.6580-63.8830 Subpart ZZZZ — Subpart MMMMM MACT 63.8980 -End Subpart NNNNN — Subpart XXXXXX 11) A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at: http://www.colorado.gov/pacific/cdphe/air-permit-self-certification AIRS ID: 12319F95 Page 10 of 15 Public Health and Environment Air Pollution Control Division ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. 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. 2.1 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 2.1.2 and make them available to the Division upon request. 2.1.1 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 2.2. AIRS ID: 123/9F95 Page 11 of 15 Public Health and Environment Air Pollution Control Division 2.1.2 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 2.2. 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/altemate-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. 2.2 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-Monitorinq-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. AIRS ID: 123/9F95 Page 12 of 15 Public Health and Environment Air Pollution Control Division For comparison with a short-term limit that is either input based (Ib/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 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. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 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 (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 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. AIRS ID: 12319F95 Page 13 of 15 Public Health and Environment Air Pollution Control Division 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 2.1.2. 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: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 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. 2.3.3 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 2.1.2. 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 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 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, § 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. 2.3.4 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 AIRS ID: 123/9F95 Page 14 of 15 Public Health and Environment Air Pollution Control Division 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 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 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. AIRS ID: 12319F95 Page 15 of 15 STATE OF COLON COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 PERMIT NO: 18WE0072 CONSTRUCTION PERMIT Issuance 1 DATE ISSUED: ISSUED TO: Whiting Oil and Gas Corporation THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Razor 25 CPB, located in SESW SEC 25 T10N R58W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description ENG-02 002 One (1) Caterpillar, Model G3516J, Serial Number N6W00216, natural gas -fired, turbo -charged, 4SLB reciprocating internal combustion engine, site rated at 1380 horsepower. This engine shall be equipped with an oxidation catalyst and air -fuel ratio control. This emission unit is used for natural gas compression. This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar, Model 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 THOSE 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. The Notice of Startup form may be downloaded online at https://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 No. 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 AIRS ID: 123/9F95 Page 1 of 15 NGEngine Version 2014-1 Public Health and Environment Air Pollution Control Division compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, II I.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 per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, 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. (Reference: Regulation No. 3, Part B, Section III.E.) 5. The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • manufacture date • construction date • order date • date of relocation into Colorado • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, 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 (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Monthly Limits: Facility Equipment ID AIRS Point Pounds per Month Emission Type NOx VOC CO ENG-02 002 2262 1585 4524 Point (Note: Monthly limits are based on a 31 -day month.) The owner or operator shall calculate monthly emissions based on the calendar month. Facility -wide emissions of each individual hazardous air pollutant shall be less than 1,359 lb/month. AIRS ID: 123/9F95 Page 2 of 15 Public Health and Environment Air Pollution Control Division Facility -wide emissions of total hazardous air pollutants shall be less than 3,398 lb/month. Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type NO. VOC CO ENG-02 002 13.3 9.3 26.7 Point See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility -wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 8. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility emission limitations as seen below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Total emissions from the facility, including permitted emissions and insignificant activities, shall not exceed: • 100 tons per year of any criteria pollutant and/or 9. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled ENG-02 002 Selective catalytic oxidizer and air/fuel ratio controller CO AIRS ID: 123/9F95 Page 3 of 15 Public Health and Environment Air Pollution Control Division 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 rate shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 days) ENG-02 002 Consumption of natural gas as a fuel 95.7 MMscf/yr 8.2 MMscf/month Fuel consumption shall be measured by one of the following methods: individual engine fuel meter; facilty-wide fuel meter attributed to fuel consumption rating and hours of operation; or manufacturer -provided fuel consumption rate. The owner or operator shall calculate monthly process rates based on the calendar month. During the first twelve (12) months of operation, compliance with both the monthly and annual throughput limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 11. 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) 12. 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. & 4.) 13. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) OPERATING & MAINTENANCE REQUIREMENTS 14. 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 your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) AIRS ID: 123/9F95 Page 4 of 15 Public Health and Environment Air Pollution Control Division COMPLIANCE TESTING AND SAMPLING Periodic Testing Requirements 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: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative -operating scenario and is installing a permanent replacement engine. 18. Federal regulatory program requirements (i.e. PSD or NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS AIRS ID: 123/9F95 Page 5 of 15 Public Health and Environment Air Pollution Control Division 19. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 20. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self - Certify for Final Authorization section of this permit. 21. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 22. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 23. Each and every condition of this permit is a material part hereof and is not -severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 24. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 25. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. AIRS ID: 123/9F95 Page 6 of 15 By: Public Health and Environment Air Pollution Control Division Timothy Sharp Permit Engineer Permit Histo Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation AIRS ID: 123/9F95 Page 7 of 15 Public Health and Environment Air Pollution Control Division Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/agcc-reqs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emission Rate (Ib/yr) Are the emissions reportable? Controlled Emission Rate (lb/yr) 002 Formaldehyde 50000 11460 YES 7730 Acetaldehyde - 75070 - - 816 YES Acrolein 107028 501 YES n -Hexane 110543 108 NO Benzene 71432 43 NO 5) The emission levels contained in this permit are based on the following emission factors: Point 002: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr NOx 2.73E-01 1.00E00 2.73E-01 1.00E00 CO 6.64E-01 2.43E00 5.21 E-01 2.00E00 VOC 1.91 E-01 7.00E-01 1.91 E-01 7.00E-01 50000 Formaldehyde 1.17E-01 4.30E-1 7.90E-02 2.90E-01 75070 Acetaldehyde 8.36E-03 - 8.36E-03 - 107028 Acrolein 5.14E-03 - 5.14E-03 - Emission factors are based on a Brake-Speclic Fuel Consumption Factor of 8070 Btu/hp-hr, a site -rated horsepower value of 1380, and a fuel heat value of 1020 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Catalyst Manufacturer AIRS ID: 123/9F95 Page 8 of 15 Public Health and Environment Air Pollution Control Division CAS Pollutant Uncontrolled EFSource Controlled EF Source VOC Manufacturer Manufacturer 50000 Formaldehyde Manufacturer Catalyst Manufacturer 75070 Acetaldehyde AP -42 AP -42 107028 Acrolein AP -42 AP -42 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 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.gov/ttn/atw/area/fr18ia08.pdf 8) This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www. eoa.gov/ttn/atw/area/arearu les. htm I 9) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC; HAP PSD or NANSR Synthetic Minor Source of: VOC MACT ZZZZ Area Source Requirements: Applicable 10) 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 AIRS ID: 123/9F95 Page 9 of 15 Public Health and Environment Air Pollution Control Division MACT 63.6580-63.8830 Subpart ZZZZ — Subpart MMMMM MACT 63.8980 -End Subpart NNNNN — Subpart XXXXXX 11) A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at: http://www.colorado.gov/pacific/cdphe/air-permit-self-certification AIRS ID: 123/9F95 Page 10 of 15 Public Health and Environment Air Pollution Control Division ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. 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. 2.1 Engine Replacement The following AOS is incorporated into this permit in cyder 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 oount 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 Applicabiity Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 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 2.2. AIRS ID: 123/9F95 Page 11 of 15 Public Health and Environment Air Pollution Control Division 2.1.2 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 2.2. 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. 2.2 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.aov/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. AIRS ID: 12319F95 Page 12 of 15 Public Health and Environment Air Pollution Control Division 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 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. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 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 (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 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. AIRS ID: 123/9F95 Page 13 of 15 Col do 'gip e4 o Public Health and Environment Air Pollution Control Division 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 2.1.2. 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: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 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. 2.3.3 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 2.1.2. 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 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 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, § 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. 2.3.4 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 AIRS ID: 123/9F95 Page 14 of 15 Public Health and Environment Air Pollution Control Division 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 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 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. AIRS ID: 12319F95 Page 15 of 15 Permit number: Date issued: Issued to: Co Air Po Depart CONSTRUCTION PERMIT 18WE0073 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Whiting Oil and Gas Corporation Razor 25 CPB 123/9F95 SESW SEC 25 T10N R58W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description SEP-01 to SEP-08 003 Four (4) two-phase separators and four (4) three-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 COLORADO Air Pollution Control Div sign )inn btnwrta; t Page 1 of 8 www.colorado.gov/pacifi (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire i e owner or operator o f e source or 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 SEP-01 to SEP- 08 003 --- 4.0 60.7 16.7 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 to demonstrate compliance with the facility potential emission limitations as seen below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. Total potential emissions from the facility, including all permitted emissions and potential to emit from all insignificant activities, shall be less than: • 100 tons per year of VOC COLORADO Air Pollution Control Division 000s Page 2 of 8 8. The emission points in t control equipment as lis established in this perm maintained with the emissions ess than or equal to the limits Se , III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled SEP-01 to SEP-08 003 Open Flare during 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-01 to SEP- 08 003 Natural Gas Venting 73.0 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. 10. - _The _owner _or_ operator _shall _ continuously_ monitor and record the volumetric flow rate_ of natural gas vented 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 11. 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) 12. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 13. 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 Pal CwItrol orison Page 3 of 8 14. The separator covered b athis -r ` sub: to latio ' 7, Section XVII.G. (State Only). On or after August 1, 201 gas o n •ff . -. rat.: , rodu -d during normal operation from any newly constructed, d, ple - 'it and gas well, must either be routed to a gas gathering line or controlled from the date of first production by air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. OPERATING Et MAINTENANCE REQUIREMENTS 15. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance ((NM) 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. The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.16) Periodic Testing Requirements 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) shall be filed: (Regulation Number 3, Part A, II.C.) ) • Annually by April 30"' whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) in ozone nonattainment areas emitting less than 100 tons of VOC or NO. per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or COLORADO A nun Control DiViSiork Page 4 of 8 • Whenever a perm • No later than 30 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 provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity, commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 22. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 23. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 24. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 25. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 26. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer Permit Histo Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation FT COLORADO Air Pa lutioiz Control Division Page 6 of 8 Notes to Permit Holder at the ti 1) The permit holder is requir: °'•ay '? -s e = :-='ng ti a 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 (tPY) Controlled Emissions (tPY) SEP-01 to SEP-08 003 Benzene 71432 3.101 0.155 Toluene 108883 3.536 0.177- Ethylbenzene 100414 0.671 0.034 Xylenes 1330207 1.679 0.084 n -Hexane 110543 26.102 1.305 2,2,4- Trimethylpentane 540841 4.610 0.230 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 0.125 tons per year (tpy) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 003: CAS # Pollutant Uncontrolled Emission Factors (lb/MMSCF) Controlled Emission Factors (lb/MMSCF) Source N0x 0.068 AP -42 CO 0.310 AP -42 V0C 33297.6986 1664.8849 Site Sample 71432 Benzene 84.9487 4.2474 Site Sample 108883 Toluene 96.8662 4.8433 Site Sample 100414 Ethylbenzene 18.3850 0.9192 Site Sample 1330207 Xylene 45.9987 2.2999 Site Sample 110543 n -Hexane 715.1239 35.7562 Site Sample COLORADO Air Pollution Control Division C artMert sf Punt: ) ua¢Crt ix f Page 7 of 8 A TT CAS # Pollutant ji c roll s F / ontr led sion actors F) Source ) (lb/ 540841 2'2'4 Trimethylpentane 126.2967 6.3148 Site Sample 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 Synthetic Minor Source of: VOC, HAPs PSD or NANSR Synthetic Minor Source of: VOC 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX COLORADO Air Pollution Control Division Page 8 of 8 Permit number: Date issued: Issued to: Co Air Po Depar CONSTRUCTION PERMIT 1 8WE0074 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Whiting Oil and Gas Corporation Razor 25 CPB 123/9F95 SESW SEC 25 T10N R58W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description SEP-10 004 Venting from crude oil process vessel during gas -gathering downtime. Open Flare This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to this specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. 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 u PotlUtion Control Division . rg( Paa ac kiktthbErmturnvrt Page 1 of 8 3. This permit shall expire or which this permit was issued: (i) does not commence c io '/ .difi or p ratio of this source within 18 months after either, the date an • co •n p t 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 SEP-10 004 --- --- 9.3 --- 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 to demonstrate compliance with the facility potential emission limitations as seen below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. Total potential emissions from the facility, including all permitted emissions and potential to emit from all insignificant activities, shall be less than: • 100 tons per year of VOC 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.) COLORADO Air Pollution Control D vision P u « Page 2 of 8 A TT Facility Equipment ID AIRS Point of v e Pollutants Controlled SEP-10 004 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-10 004 Natural Gas Venting 4.1 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. 10. The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented 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 11. 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) 12. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 13. 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. 14. 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 us hydrocarbons. OPERATING a MAINTENANCE R • I `EM ructi efficiency of at least 98% for 15. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&tM) 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. The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.16) Periodic Testing Requirements 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) 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. 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 OLORADO Pollution Control Division Page 4 of 8 condition. Any relaxatio that nc -a the aen l to e t above the applicable Federal program threshold will r hough construction had not yet commenced on the sour eral 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 provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 22. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 23. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 24. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 25. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 26. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer COLORADO Air Pollution Control Division Page 5 of 8 Permit Histo Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation OLORADO Winn. Control Division Page 6 of 8' Notes to Permit Holder at the tim 1) The permit holder is requir •ay she 'ng ti-- 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 (tPY) Controlled Emissions (tPY) SEP-10 004 Benzene 71432 0.294 0.015 Toluene - 108883 0.166 0.008 - -_ Ethylbenzene 100414 0.018 0.001 Xylenes Y 1330207 0.040 0.002 n -Hexane 110543 3.034 0.152 2,2,4- Trimethylpentane 540841 0.326 0.016 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 0.125 tons per year (tpy) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 004: CAS # Pollutant Uncontrolled Emission Factors (lb/MMSCF) Controlled Emission Factors (lb/MMSCF) Source N0x 0.068 AP -42 CO 0.310 AP -42 V0C 91087.5135 4554.3757 Site Sample 71432 Benzene 145.2182 7.2609 Site Sample 108883 Toluene 82.0598 4.1030 Site Sample 100414 Ethylbenzene 8.7592 0.4380 Site Sample 1330207 Xylene 19.5929 0.9796 Site Sample 110543 n -Hexane 1498.3978 74.9199 Site Sample 'COLORADO .Air Pollutipel Control Division Page 7 of 8 CAS # Pollutant c•,"" rol :"r s F. • '_: .„/ r ) ontr led Sion actors (lb/ F) - Source _.-_, 540841 2, Trimethylpentane 161.0078 8.0504 Site Site Sample 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 Synthetic Minor Source of: VOC, HAPs PSD or NANSR Synthetic Minor Source of: VOC 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX COLORADO Air PQUution Control Davisiori rimmt Page 8 of 8 Permit number: Date issued: Issued to: Co Air Po Depart CONSTRUCTION PERMIT 18WE0075 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Whiting Oil and Gas Corporation Razor 25 CPB 123/9F95 SESW SEC 25 T10N R58W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description SEP-11 005 Venting from produced water process vessel during gas -gathering downtime. Open Flare This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to this specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1 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 i (i) does not commence c after either, the date -''•an or which this permit was issued: ratio of this source within 18 months co • • n p t 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 SEP-11 005 --- --- 1.1 --- 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 to demonstrate compliance with the facility potential emission limitations as seen below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. Total potential emissions from the facility, including all permitted emissions and potential to emit from all insignificant activities, shall be less than: • 100 tons per year of V0C 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.) COLORADO Control Division ent Pts»Gr vg ,S.wor,',,nmc Page 2 of 8 Facility Equipment ID AIRS Point of �'=v' a Pollutants Controlled SEP-11 005 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-11 005 Natural Gas Venting 1.5 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. 10. The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented 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 11. 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) 12. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 13. 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. 14. 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 ₹COLORADO Air Pollution CoatttO1Division Page 3 of 8 combustion device is us hydrocarbons. OPERATING Et MAINTENANCE R • I ' EM efficiency of at least 98% for 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. The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.16) Periodic Testing Requirements 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) 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. 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 COLORADO Pollution Control Divit;3cat Page 4 of 8 condition. Any relaxatio that nc -a th:.ten :l toe t above the applicable Federal program threshold will r: uire f l ; vie a M: u ` e a hough construction had not yet commenced on the sour e - - n. -. th eral 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 provide "final' authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 22. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 23. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 24. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 25. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 26. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer COLORADO Air otion Control Division Serr ot'Flax Re*th rAntormum Page 5 of 8 Permit Histo Issuance Date Description Issuance 1 This Issuance Issued to Whiting Oil and Gas Corporation AFT COLORADO Au Pollution contr+st Division k7¢a3L: r`.€ysxcrgnene Page 6 of 8 Notes to Permit Holder at the tim 1) The permit holder is requir- ""'.ay --s a ng ti + 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 shalt 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 (tPY) Controlled Emissions (tPY) SEP-11 005 Benzene 71432 0.145 0.007 __-Toluene - 108883 0.074 -- - 0.004 - - Ethylbenzene 100414 0.005 0.000 Xylenes Y 1330207 0.012 0.001 n -Hexane 110543 0.454 0.023 2,2,4- Trimethylpentane 540841 0.030 0.001 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 0.125 tons per year (tpy) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 005: CAS # Pollutant Uncontrolled Emission Factors (lb/MMSCF) Controlled Emission Factors (lb/MMSCF) Source N0x 0.068 AP -42 CO 0.310 AP -42 V0C 29501.8745 1475.0937 Site Sample 71432 Benzene 193.7062 9.6853 Site Sample 108883 Toluene 98.9269 4.9463 Site Sample 100414 Ethylbenzene 6.5286 0.3264 Site Sample 1330207 Xylene 15.8990 0.7949 Site Sample 110543 n -Hexane 604.9288 30.2464 Site Sample COLORADO Air Pollution Control Division Page 7 of 8 CAS # Pollutant1.00) c roll s F ontr led sion actors (lb/ F) Source ) 540841 2,2,4 Trimethylpentane 39.5554 1.9778 Site Sample 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 Synthetic Minor Source of: VOC, HAPs PSD or NANSR Synthetic Minor Source of: VOC 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ- Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX COLORADO Air Pothitior, Control Division Fortrotrnem Page 8 of 8 V l&'V' "v -- -.. - -V.•--..- -- " �' i G'(JJ Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit AU 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: i w 06 AIRS ID Number: 123 /c1F9/0° / 0 ° [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: Whiting Oil and Gas Corporation Razor 25 CPB Site Location SESW Sec 25, T10N, R58W County: Weld Mailing Address: (include Zip Code) 1700 Broadway, Suite 2300 Portable Source Home Base: Denver, CO 80290 NAICS or SIC Code: 1 31 1 Permit Contact: Phone Number: E -Mail Address2: coPHEcorrespondence@whiting.com Jacob Parker (303) 357-4078 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 373702 ® COLORADO 1 m xwn.,�.n �, wee Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action Q NEW permit OR newly -reported emission source (check one below) O 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) O Change fuel or equipment ❑ Change company name ❑ Add point to existing permit O Change permit limit ❑ Transfer of ownership's O 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 Et 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 AOS 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-01 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 days/week 52 weeks/year February 1, 2018 ❑ Yes 0 No Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 June -Aug: 25 Sept -Nov: 25 COLORADO Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 2 I� =7r, ¢`„ Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit n and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking O Emergency Back-up O Pump ❑ Water Pump ❑ Other: 0 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 What is the maximum designed horsepower rating? 1380 hp What is the engine displacement? l/cyl What is the maximum manufacturer's site -rating? 1311 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,071 BTU/hp-hr Engine Features: Cycle Type: O 2 -Stroke 0 4 -Stroke Combustion: 0 Lean Burn O Rich Burn Ignition Source: 0 Spark ❑ Compression Aspiration: ❑ Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes D No hours/year Serial Number': N6WO0226 If yes, what type of AFRC is in use? 0 O2 Sensor (mV) ONOx Sensor (ppm) Is this engine equipped with a Low-NOx design? O Yes 0 No Engine Dates: What is the manufactured date of this engine? June 9, 2017 O Other: What date was this engine ordered? April 19, 2017 What is the date this engine was first located to Colorado? August 24, 2017 What is the date this engine was first placed in service/operation? N/A What is the date this engine commenced construction? April 19, 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 A® co�oRaoo 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) 40.803575, -103.8128 Operator' Stack iQ No Discharge ale ght Above Ground level (Feet) Temp ( - Flow state (ACFM) Velocity fftl ) ENG-01 22.5 830 8,070 165.8 Indicate the direction of the Stack outlet: (check one) 0 Upward O Horizontal ❑ Downward O Other (describe): Indicate the stack opening and size: (check one) Circular O Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 8 O 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) - Requested Annual Permit Limit' (MMSCF/year) 10,374 90.87 From what year is the actual annual amount? Indicate the type of fuel used$: 0 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 Y COLORADO 4 LSM� MPanroen�>i Yu.r 14�J'll h [�....m�mew. fi. Permit Number: AIRS ID Number: TSP (PM) [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach alt 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): Primary Control Equipment Description verall,Requested Control_; Efficiency • (% reduction in emissions). PM10 PM2.5 SOX NON. VOC SCO with AFRC 61.7% CO SCO with AFRO 17.7% 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? Permit Limits Pollutant TSP (PM) Uncontrolled Basis Criteria Pollutant Emissions inventory Source (AP -42, Mfg. etc) Actual Annual Emissions9 Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Requested Annual Permit Emission Limit(s)' Uncontrolled'' Emissions (Tons/year) Controlled Emissions (Tonslyear) PM10 PM2.5 0.00991 Ib/MMBtu AP -42 De Minimis De Minimis 0.00991 Ib/MMBtu AP -42 De Minimis De Minimis 0.00991 Ib/MMBtu AP -42 De Minimis De Minimis SOX NOX VOC 0.000588 ib/MMBtu AP -42 De Minimis De Minimis 0.50 g/hp-hr Requested 6.3 6.3 1.83 g/hp-hr Manf Spec 23.2 8.9 CO 2.43 9/hp-hr Manf Spec 30.8 25.3 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? ❑ No If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name Formaldehyde Acetaldehyde Non -Criteria Reportable Pollutant. Emissions Inventory Chemical Abstract Service (CAS) Number 50000 Emission Factor Uncontrolled Basis 0.36 Units g/hp-hr Source (AP -42, .` Mfg. etc) Merit Spec Actual Annual Emissions9 Uncontrolled Emissions (Pounds/year) 9110 Controlled Emissions (Pounds/year) 6330 75070 107028 0.00836 Ib/MMBtu AP -42 775 775 Acrolein Benzene 0.00514 lb/MMBtu AP -42 476 476 71432 0.00044 Ib/MMBtu AP -42 De Minimis De Minimis Other: 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 4 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 'AYCOLORADO .artr€.n H.FNNfi ii N 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. January 16, 2018 Signaof Legally Authorized Person (not a vendor or consultant) Date Jacob Parker Environmental Professional Name (please print) Title Check the appropriate box to request a copy of the: ❑Q 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 I AVCOLORADO ==,„ RECEIVED JUN 12261.8 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 4nternal 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 ign-ition 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.aov/cdphe/aped. 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: \ A.) 00'4- I AIRS ID Number: i a3 [Leave blank unless APCD has already assigned a permit r and AIRS ID] Section 1 - Administrative Information Company Name': Whiting Oil and Gas Corporation Site Name: Razor 25 CPB Site Location: SESW, Section 25, T1 ON, R58W Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Portable Source Home Base: Denver, CO 80290 Site Location County: Weld NAICS or SIC Code: 131 1 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 Ot'O H.A DO- 's11.21takittK 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 (check one below) ❑✓ STATIONARY source 0 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 - O 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 Et 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 AOS 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-01 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: June 1, 2018 Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.qov/cdphe/attainment) Normal Hours of Source Operation: 24 ❑ Yes ✓❑ No hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 June -Aug: 25 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 Sept -Nov: 25 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS !DJ Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up O 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 Number6: N6W00226 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? 8,070 BTU/hp-hr Engine Features: Cycle Type: O 2 -Stroke 0 4 -Stroke Combustion: O Lean Burn ❑ Rich Burn Ignition Source: ❑ Spark ❑ Compression Aspiration: O Natural O Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes O No If yes, what type of AFRC is in use? 0 O2 Sensor (mV) ❑NOX Sensor (ppm) Is this engine equipped with a Low-NOX design? ❑ Yes 0 No Engine Dates: What is the manufactured date of this engine? June 9, 2017 O Other: What date was this engine ordered? April 19, 2017 What is the date this engine was first located to Colorado? August 24, 2017 What is the date this engine was first placed in service/operation? June 1, 2018 What is the date this engine commenced construction? August 24, 2017 What is the date this engine was last reconstructed or modified? N/A Is this APEN reporting an AOS replacement engine? O Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: 6 The serial number must be submitted if coverage under GP02 is requested. Serial Number: Form APCD-201 Reciprocating Internal Combustion Engine APEN - Revision 1/2017 aLO R.A-DO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information 40.80358/-103.8128 �.m ENG-01 22.5 830 8,070 165.8 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward O Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 12 O Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (-inches): Section 6 - Fuel Data and Throughput Information 10,918 95.64 From what year is the actual annual amount? Indicate the type of fuel used": O Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) O Field Natural Gas Heating value: BTU/scf O 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 considerfutureprocess 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 Permit Number: AIRS iD Number: Formaldehyde TSP (PM) [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): nested tticiency reduction emissions PM10 PM2.5 SOX NOX VOC CO SCO with AFRC 21.5% 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 Uncontrolled . '': Basis Source -= (AP -42, Mfg. etc):. ctual Annual Emissions: nested Annua. Emission -:Limit Uncontrolled Emissions (Tons] year) ontrolled "Emissions! (Tons/year) Uncontrolled Emissions" (Tons/year):-" ontrolled'. missions Tons/year) TSP (PM) 0.00991 • Ib/MMBtu AP -42 De Minimis De Minimis PM10 PM2.5 0.00991 Ib/MMBtu AP -42 De Minimis De Minimis 0.00991 lb/MMBtu AP -42 De Minimis De Minimis SOX NOX VOC 0.000588 Ib/MMBtu AP -42 De Minimis De Minimis 1.0 g/hp-hr NSPS JJJJ 13.3 13.3 0.70 g/hp-hr NSPS JJJJ 9.3 9.3 CO 2.43 g/hp-hr Manf Spec 32.4 26.7 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? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: E Yes ❑ No on Criteria Reportable. Pollutant Emissions Inventory emica stract' service (CAS) Number mission'',Fact+ to nnual.Emissions'' 0.43 g/hp-hr Manf Spec ncontrolled Emissions 'Pounds/yenr)° - 7,730 50000 75070 11,460 Acetaldehyde 0.00836 Ib/MMBtu AP -42 816 816 Acrolein 107028 0.00514 Ib/MMBtu AP -42 501 501 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 COLOR.ADO .,m 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 June 12, 2018 n (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 ❑✓ 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 Small Business Assistance Program Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692=3150 (303) 692-3175 or (303) 692-3148 https: / /www.colorado. goy / cd phe / apcd Form APCD-201 Reciprocating Internal Combustion Engine APEN Revision 1/2017 COLORADO sl:ns:cawh+ittmNni CDPHE 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: AIRS ID Number: (-z3 R F 57 a 0 [Leave blank unless APCD has already assigned a permit a` and AIRS ID] Section 1 - Administrative Information Company Name': Whiting Oil and Gas Corporation Site Name: Razor 25 CPB Site Location: SESW Sec 25, T1 ON, R58W 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: Jacob Parker Phone Number: (303) 357-4078 E -Mail Address2: CDPHEcorrespondence@whiting.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2Permits, 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 373703 COLORADO 1 I . �` „ H.�A:4 fi L 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 (check one below) O STATIONARY source O PORTABLE source O 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) O Change fuel or equipment O Change company name O Add point to existing permit O Change permit limit O Transfer of ownership4 O 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 Et 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 AOS 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: December 1, 2017 Will this equipment be operated in any NAAQS nonattainment area? (http: //www.colorado.Rov/cdphe/attainment) ❑ Yes 0 No Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 2 i AYCOLORADO i=7,17.=., Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine ❑ Primary and/or Peaking ❑ Emergency Back-up Function: ❑ Pump ❑ Water Pump O Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 Compression hours/year Engine Make: Caterpillar Engine Model: G3516J Serial Number': N6W00216 What is the maximum designed horsepower rating? 1380 hp What is the engine displacement? What is the maximum manufacturer's site -rating? 1311 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,071 BTU/hp-hr l/cyl Engine Features: Cycle Type: O 2 -Stroke ❑✓ 4 -Stroke Combustion: ❑✓ Lean Burn O Rich Burn Ignition Source: E 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? p O2 Sensor (mV) ❑NOx Sensor (ppm) O Other: Is this engine equipped with a Low-NOx design? ❑ Yes 0 No Engine Dates: What is the manufactured date of this engine? June 9, 2017 What date was this engine ordered? April 19, 2017 What is the date this engine was first located to Colorado? August 24, 2017 What is the date this engine was first placed in service/operation? December 1, 2017 What is the date this engine commenced construction? April 19, 2017 What is the date this engine was last reconstructed or modified? N/A Is this APEN reporting an AOS replacement engine? ❑ Yes Q 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 ifCOl0 R4D0 H�n1 M f 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) 40.803575, -103.8128 Operator Stack ID No Discharge Height Above Ground`Levet _ (Feet Temp. (• Flow Rate (ACFM) Velocity (ltl3ec ENG-01 22.5 830 8,070 165.8 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward O Horizontal ❑ Downward O Other (describe): Indicate the stack opening and size: (check one) Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 8 ❑ 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 (MM5CFl year) Requested Annual Permit Limit (MMSCF/year) 10,374 90.87 From what year is the actual annual amount? Indicate the type of fuel useds: 0 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-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 4 1 Ier •r Permit Number: AIRS ID Number: / / TSP (PM) [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. 1s any emission control equipment or practice used to reduce emissions? El Yes El No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Overall ;Requested Contro: Efficiency (% reduction in emissions) PM10 PM2.5 SOX NOx VOC SCO with AFRC 61.7% CO SCO with AFRC 17.7% 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? Permit Limits Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions v Requested Annual Permit 7 Emission Limit(s) Uncontrolled Basis Units Source (AP -42, Mfg. etc). Uncontrolled Emissions ; (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 0.00991 Ib/MMBtu AP -42 De Minimis De Minimis PM10 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 0.50 g/hp-hr Requested 6.3 6.3 VOC 1.83 g/hhp-hr Manf Spec 23.2 8.9 CO 2.43 g/hp-hr Manf Spec - 30.8 25.3 Does the emissions source have any uncontrolled actual emissions of non -criteria 0 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 ( ) Number Emission Factor - Actual Annual Emissions' Uncontrolled Basis Units Source ` (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled. Emissions (Pounds/year) Formaldehyde 50000 0.36 g/hp-hr Manf Spec 9110 6330 Acetaldehyde 75070 0.00836 Ib/MMBtu AP -42 775 775 Acrolein 107028 0.00514 Ib/MMBtu AP -42 476 476 Benzene 71432 0.00044 Ib/MMBtu AP -42 De Minimis De Minimis Other: 7 Requested values wilt 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. .74 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO .. r� 5 IAY K Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit r 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. January 16, 2018 Signatu of Legally Authorized Person (not a vendor or consultant) Date Jacob Parker Environmental Professional Name (please print) Title Check the appropriate box to request a copy of the: J Draft permit prior to issuance ❑r Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) 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'AY COLORADO Reciprocating Internal Combustion JUN l 2 2018 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: ($ WS o 041 AIRS ID Number: ( 2 3 / 5 /O O [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information. Company Name': Whiting Oil and Gas Corporation Site Name: Razor 25 CPB Site Location: SESW, Section 25, T1 ON, R58W Mailktg 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 COLOR ADO tleparmant arannro-Ent, hoamuxu 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 (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 O Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et 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 AOS 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) December 1, 2017 ❑ Yes 0 No Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-201 Reciprocating Internal Combustion Engine APEN - Revision 1/2017 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 0 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 Number6: N6W00216 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? 8,070 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ❑✓ 4 -Stroke Combustion: ❑✓ Lean Burn ❑ Rich Burn Ignition Source: 0 Spark ❑ Compression Aspiration: 0 Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ✓❑ Yes 0 No If yes, what type of AFRC is in use? ❑✓ 02 Sensor (mV) ONOx Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOx design? ❑ Yes ❑✓ No Engine Dates: What is the manufactured date of this engine? June 1, 2017 What date was this engine ordered? April 19, 2017 What is the date this engine was first located to Colorado? August 24, 2017 What is the date this engine was first placed in service/operation? December 1, 2017 What is the date this engine commenced construction? August 24, 2017 What is the date this engine was last reconstructed or modified? N/A Is this APEN reporting an AOS replacement engine? 0 Yes E 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 3 117 COLOEs0TC? Sia.IN,tb E1w3N+CtMUT,! Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information 40.80358/-103.8128 Q' ¢ b' � 830 ® nn. 8,070 165.8 EN G-02 22.5 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) -0 Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): Interior stack diameter (inches): 12 0 Upward with obstructing raincap Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Yd riA'h Ube Rat o��i' 00% Load> iii� 's.. ,.. &fj >..,,, E ;. Actual Annual Fu' ik-,,. >... ,..fi4%� $5i - :�� se .�rrr . ..? ,d' C Y zkf' 3.E quest d A real mil Lz ttt e %,� ... roP'�/; s. 10,918 95.64 From what year is the actual annual amount? Indicate the type of fuel used: ❑✓ Pipeline Natural Gas ❑ Field Natural Gas ❑ Propane O Landfill Gas Other (describe): (assumed fuel heating value of 1,020 BTU/scf) Heating value: BTU/scf (assumed fuel heating value of 2,300 BTU/scf) Heating Value: BTU/scf Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. s 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 co�:a�.kao Psmtic v�� Permit Number: AIRS ID Number: / / Formaldehyde 50000 11,460 TSP (PM) TSP (PM) [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? O Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Iverall Re uestedrControl icien reduction in "emissior. PM t0 PM2.5 5Ox NOX VOC CO SCO with AFRO 21.5% 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 riteria Pollutant;Emissions Inventor ctual Annual Uncontrolled Emission (Tonslyear) missteps' ontrolled :missions; Tonslyear).:.: De Minimis De Minimis 0.00991 lb/MMBtu AP -42 PMt0 PM2 5 0.00991 Ib/MMBtu AP -42 De Minimis De Minimis 0.00991 Ib/MMBtu AP -42 De Minimis De Minimis SOX NOx VOC 0.000588 Ib/MMBtu AP -42 De Minimis De Minimis 1.0 g/hp-hr NSPS JJJJ 13.3 13.3 0.70 g/hp-hr NSPS JJJJ 9.3 9.3 CO 2.43 g/hp-hr Manf Spec 32.4 26.7 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 n Cnteria Reportable. Pollutani Emissions , nventor mission Facto ua raual mission ontrolled Emission (Pounds!year) `; 0.43 g/hp-hr Manf Spec 7,730 Acetaldehyde 75070 0.00836 Ib/MMBtu AP -42 816 816 Acrolein 107028 0.00514 Ib/MMBtu AP -42 501 501 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. COR.AOO Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 Permit Number: AIRS ID Number: / f [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 jp.,full compliance with each condition of general permit GP02. Signature of Legally Au Ashley Brinkerhoff June 12, 2018 (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 ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, Ii.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $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 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd DO Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 (o' 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, welt 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.Rov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: AIRS ID Number: I 12) 003 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: • SEP-62, SEP-64, SEP-65, SEP-68, SEP-75 TO SEP-76, SEP-79, & FLR-02 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Namel: Site Name: Site Location: Whiting Oil and Gas Corporation Razor 25 CPB Site Location SESW Sec 25, T10N, R58W County: Weld Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Denver, CO 80290 E Mail Address2: CDPHEcorrespondence@whiting.com NAICS or SIC Code: 1311 Permit Contact: Jacob Parker Phone Number: (303) 357-4078 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-2 i 1 iJrtural Gas Venting ADEN - Rev 03/2017 373704 1 [�Y<OIORSDD i�.9LS Permit Number: AIRS II) Number: / [Leave blank uniess APCD has uheady assigned a permit 4 cud -AIRS [D]. 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 0 Add point to existing permit ❑ Change permit limit 0 Transfer of ownership' 0 Other (describe below) -OR- ❑ APEN submittal for update only (Please note blank APENs will not be accepted) • - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info £t Notes: int 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: (4) 3 -phase separators For existing sources, operation began on: For new or reconstructed sources, the projected start-up dateis: (4) 2 -phase separators and October / 18 / 2018 ❑ 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-211 -Natural Gas Venting ADEN Rev 03/2017 days/week weeks/year ❑ Yes ❑ Yes 0 No 0 No fy�.cOLDRdDD 2 INrn4R t-r. Permit Number: AIRS ID Number: / / [Leave la .es ';PCD .. c iscied -pe mii and i-:IR.'.i ID] Section 4.- Process Equipment Information Q Gas/Liquid Separator O Well Head Casing O Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: O Other Description: Serial #: Capacity: Gal/min # of Pistons: Leak Rate: Scf/hr/pist Volume per event: MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: 187 500 SCF/hr Vent Gas Heating Value: 1 550 BTU/SCF Requested: 32.9 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 %) 23.167 VOC (Weight %) 45.80 Benzene (mole %) 0.041 Benzene (Weight %) 0.12 Toluene (mole %) 0.040 Toluene (Weight %) 0.13 Ethylbenzene (mole %) 0.007 Ethylbenzene (Weight %) 0.03 Xytene (mole %) 0.016 Xylene (Weight %) 0.06 n -Hexane (mole %) 0.315 n -Hexane (Weight %) 0.98 2,2,4-Trimethylpentane (mole %) 2,2,4-Trimethylpentane 0.042 (Weight %) 0.17 Additional Required Information: ❑� Attach a representative gas analysis (including BTEX & n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX R n -Hexane, temperature, and pressure) 0 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 3I ®Y COLORADO Department aro-K Halt, b Lemisonrtw o Permit Number: AIRS ID Number: / [Leave , ID. _�ta .., �_m e>� APCD has as��ned ,_ pern,;rt an d ..� � Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.803575, -103.8128 Operator 'Mack iti o Discharge Height Above Ground Level (feet) Tertip ( F) Flow Rate (ACFi1!) Velocity ftlsec) FLR-02 40 >2000 3,125 149.2 Indicate the direction of the stack outlet: (check one) 0 Upward ❑ Horizontal ❑ Downward O Other (describe): Indicate the stack opening and size: (check one) 0 Circular D Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap 8 Section 6 - Control Device Information ❑ VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed ❑ Combustion Device: Pollutants Controlled: Rating: Type: VOC and HAPs 598 Open Flare Requested Control Efficiency: MMBtu/hr Make/Model: Flare Industries SFVP-0824 95 Manufacturer Guaranteed Control Efficiency 98 Minimum Temperature: N/A Waste Gas Heat Content 1,550 Btu/scf Constant Pilot Light: O Yes O No Pilot burner Rating 0.16 MMBtu/hr Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 4I ®V COLORADO Mpat< Department ne u..aeem.e, Permit Number: AIRS II) Number: [Leave blank sunless APCD has al ead/ as. e ned a hermit r 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? j1 Yes O No If yes, p Pollutant PM lease describe the control equipment AND state the overall control efficiency (% reduction): Overall Requested Control Efficiency (% reduction in emissions) Control Equipment Description SOX NO„ VOC Gas is sent to gas gathering pipeline with open flare as backup 95% CO HAPs Gas is sent to gas gathering pipeline with open flare as backup 95% Other: Permit Limits From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: Pollutant _ Uncontrolled Emission Factor ` Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Requested. Annual Permit s Emiss�on'Ltmit(s) Uncontrolled (Tons/year) Controlled6 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM 0.0075 lb/MMBtu AP -42 De minimis SOX 0.0006 lb/MMBtu Gas Analysis De minimis NO„ 0.068 lb/MMBtu AP -42 De minimis VOC 33229.43 lb/MMscf Gas Analysis 545.79 27.29 CO 0.310 lb/MMBtu AP -42 7.40 Benzene 84.82 Ib/MMscf Gas Analysis 1.39 0.07 Toluene 96.66 )lb/MMscf Gas Analysis 1.59 0.08 Ethylbenzene 18.47 lb/MMscf Gas Analysis 0.30 0.02 Xylenes 45,89 lb/MMscf Gas Analysis 0.75 0.04 n -Hexane 714.38 lb/MMscf Gas Analysis 11.73 0.59 th Trimehylpeylpe ntane 126.15 lb/MMscf Gas Analysis 2.07 0.10 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 I � - COLORADO 5 �F rim m Neal. Y Permit Number: AIRS ID Number: / [Leave blarlk _sties; ,APCD has ct. s-eLy ,..1suer.1 a permit AIRS ID] .r . Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. January 16, 2018 Signature,9ttegally Authorized Person (not a vendor or consultant) Date Jacob Parker Environmental Professional Name (please print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance �✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: 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 A® COLORADO Natural G.as 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. ‘114I220iq 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.Rov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: I gwe 0073 AIRS ID Number: I z 3 ' l JF'5• 16,03 [Leave blank unless APCD has already assigned a permit f 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 Namel: Whiting Oil and Gas Corporation Site Name: Razor 25 CPB Site Location: SESW Section 25, T10N, R58W Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Denver, CO 80290 E -Mail Address2: CDPHECorrespondence@whiting.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Ashley Brinkerhoff Phone Number: 303-390-1596 1Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 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 DatpuravAnkof 11/4.1*. coLo Aaa. b1)..: Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS ID) Section 2- Requested Action 0 NEW permit OR newly -reported emission source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment ❑ Change company name ❑ Add point to existing permit O Change permit limit 0 Transfer of ownership' ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Please note blank APENs will not be accepted) ADDITIONAL PERMIT ACTIONS - Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Ft 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: 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: 10 / 18 / 2017 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 Witt 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-211 -Natural Gas Venting APEN - Rev 03/2017 days /week weeks/year O Yes ❑ Yes 0 No ❑✓ No Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit r and AIRS ID] Section 4 - Process Equipment Information El Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ B lowdown Events # of Events/year: ❑ Other Description: Serial #: Capacity: Gal/min # of Pistons: Leak Rate: Scf/hr/pist Volume per event: MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: 166 667 SCF/hr Vent Gas Heating Value: 1 550 , BTU/SCF Requested: 73.0 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 (mote %) 23.17 VOC (Weight %) 45.80 Benzene (mole %) 0.041 Benzene (Weight %) 0.117 Toluene (mole %) 0.040 Toluene (Weight %) 0.133 Ethylbenzene (mole %) 0.007 Ethylbenzene (Weight %) 0.025 Xylene (mole %) 0.016 Xylene (Weight %) 0.063 n -Hexane (mole %) 0.315 n -Hexane (Weight %) 0.985 2,2,4-Trimethylpentane (mole %) 0.042 2,2,4-Trimethylpentane (Weight %) 0.174 Additional Required Information: ❑✓ Attach a representative gas analysis (including BTEX it 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 O3/2017 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit r and AIRS ID] Section 5 - Stack Information Geographkal Coordinates a₹ tzidellongliude',or U , .`` 40.80358/-103.8128 ,"YP FLR-01 . 40 >2,000 2,778 132.6 Indicate the direction of the stack outlet: (check one) 0 Upward O Horizontal ❑ Downward O Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): ❑ Other (describe): O Upward with obstructing raincap 8 Section 6 - Control Device Information ❑✓ VRU: Pollutants Controlled: Size: Make /Model: Requested Control Efficiency VRU Downtime or Bypassed ❑ Combustion Device: Pollutants Controlled: VOC and HAPs Rating: 598 MMBtu/hr h r 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 1,580 Btu/scf Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating 0.44 MMBtu/hr Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 41 COLORADO DCpirtrn. II tat E Permit Number: AIRS ID Number: PM [Leave blank unless APCD has already assigned a permit Y 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): PM SO, 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.) Uncontrolled Emission actor Emission Factor;: . Units: Emission Factor. Source (AP -42, Mfg. etc). Uncontrolled (Tons/year) .. Controlled6 (Tons/year) Control led ;; ,a7.; ns/year) Uncontrolled (Tons/year) 0.0075 Ib/MMBtu AP -42 De Minimis SO, NO), 0.068 lb/MMBtu Btu AP -42 3.98 VOC 33229.43 lb/MMscf Gas Analysis 1,212.88 60.64 CO 0.31 I b/M M Btu AP -42 16.56 Benzene 84.82 lb/MMscf Gas Analysis 3.10 0.15 Toluene 96.66 lb/MMscf Gas Analysis 3.53 0.18 Ethylbenzene 18.47 lb/MMscf Gas Analysis 0.67 0.03 Xylenes 45.89 lb/MMscf Gas Analysis 1.67 0.08 n -Hexane 714.38 lb/MMscf Gas Analysis 26.07 1.30 2,2,4- Trimethylpentane 126.15 lb/MMscf Gas Analysis 4.60 0.23 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 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... Signature of Legally A Ashley Brinkerhoff June 12, 2018 n (not a vendor or consultant) Date Environmental Professional Name (please print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance ✓� Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable, to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: / /www.colorado.gov/cdphe /apcd Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 6 I ORADO motrumuc 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: 1 D (JOE() Ch? -1 -.\AIRS ID Number: (ri.__(10 /4C51 00` [Leave blank unless APCD has already assigned a permit = and AIRS ID] Company equipment Identification: SEP-21, FLR-02 [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: Razor 25 CPB Site Location: SESW Sec 25, T10N, R58W Mailing Address: (include Zip Code) 1700 Broadway, Suite 2300 Denver, CO 80290 E -Mail Address: CDPHECOrreSpOndenCe@Whiting.COM Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Jacob Parker Phone Number: (303) 357-4078 1Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-21 1 - Natural Gas Venting APEN - Rev 03/7017 373705 COLORADO 1 ANT ��: a rnIr.aRm.., Permit Number: AIRS ID Number: [Leave iD[ank. 4PCP l„ dt eau, p ern'Lt and AIRS VLSI Section 2- Requested Action E] 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' 0 Other (describe below) - OR - APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: Crude Oil Vessel 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Flaring associated gas from crude oil vessel during VRU and gas gathering downtime. For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / / October / 18 / 2018 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 • O Yes ❑r No O Yes ❑✓ No Form APED-211-Naturat Gas Venting APEN - Rev 03/2017 2 AY COLORADO Lemv nm n1 Permit Number: AIRS ID Number: / / ht,..ti-,Les/PC' per,.,. - AI PS 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: Crude Oil Pressurized Vessel Serial #: Capacity: Gal/min # of Pistons: Leak Rate: Scf/hr/pist Volume per event: MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? I] Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: 8 ,� 5 SCF/hr Vent Gas Heating Value: 2 350 BTU/SCF Requested: 2.36 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 %) 64.994 VOC (Weight %) 79.03 Benzene (mole %) 0.07 Benzene (Weight %) 0.1260 Toluene (mole %) 0.034 Toluene (Weight %) 0.0712 Ethylbenzene (mole %) 0.003 Ethylbenzene (Weight %) 0.0076 Xylene (mole %) 0.007 Xylene (Weight %) 0.0170 n -Hexane (mole %) 0.659 n -Hexane (Weight %) 1.3001 2,2,4-Trimethylpentane (mole %) 0.053 2,2,4-Trimethylpentane 4-Trimethylpentane (Weight %) 0.1397 Additional Required Information: CI Attach a representative gas analysis (including BTEX ft 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 3j Air COLORADO Permit Number: !?tauk unless APCD AIRS ID Number: / / AIRS Imo] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.803575, -103.8128 Operator; StaCk1D No Discharge Height; Above Ground Level (Feet) Temp CF) ;Flow Rate (ACFM) Velocity': (ftlsec) FLR-02 40 >2000 3,125 149.2 Indicate the direction of the stack outlet: (check one) ❑r Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): D Other (describe): ❑ Upward with obstructing raincap 8 Section 6 - Control Device Information ❑ VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency % VRU Downtime or Bypassed % Combustion Device: Pollutants Controlled: VOC and HAPs Rating: 598 MMBtu/hr Make/Model: Flare Industries SFVP-0824 95 % Type: Open Flare Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: N/A 98 % Waste Gas Heat Content 1 ,550 Btu/scf Constant Pilot Light: O Yes ❑ No Pilot burner Rating 0.16 MMBtu/hr Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 Form APCD-21'I -Natural Gas Venting APEN - Rev 03/2017 A® COLORADO 4 .o ,nK PM Permit Number: AIRS ID Number: / i)t f k ie PCB- has i -c_y 4 ? permit_ 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): Overall Requested Control Efficiency (% reduction in emissions) Control Equipment Description SOX NOx VOC Gas is sent to gas gathering pipeline with open flare as backup 95% CO HAPs Gas is sent to gas gathering pipeline with open flare as backup 95% Other: Permit Limits From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: Pollutant Uncontrolled Uncontrolled Emission Factor Emission Emission Factor Units Emission Factor Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Actual Annual Emissions Requested Annual Permit Requested Annual Permit Emission Limit(s)5 Uncontrolled (Tons/year) Controlled6 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM 0.0075 lb/MMBtu AP -42 De minimis SOX NO), 0.068 Ib/MMBtu AP -42 De minimis VOC 1.685 lb/bbl Gas Analysis 1537.58 5.38 CO 0.310 Ib/MMBtu AP -42 De minimis Benzene 0.0027 lb/bbl Gas Analysis 2.45 0.01 Toluene 0.0015 lb/bbl Gas Analysis 1.39 0.005 Ethylbenzene 0.0002 lb/bbl Gas Analysis De minimis De minimis Xylenes 0.0004 Ib/bbl Gas Analysis De minimis De minimis n -Hexane 0.0277 lb/bbl Gas Analysis 25.26 0.088 2'2'4- Trimethylpentane 0.0030 lb/bbl Gas Analysis 2.71 0.010 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 5 I AV COLORADO c<wnn.ntot Nn.LTb Envnanmvn, Permit Number: AIRS ID Number: / / .`r'_:) Has 7..,11: , 7 ;.I', ID1 • E: Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. January 16, 2018 Signat of Legally Authorized Person (not a vendor or consultant) Date Jacob Parker Environmental Professional Name (please print) Title Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance p 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.govicdphe/apcd A® COLORADO 6 I Ocf I�m[n!c4Fvt�lr. L \/7-.T, JUN 1 2 201R Natural Gas Venting APEN — Form APCD-211 Air Pollutant Emission Notice (APEN) and Application for Construction Permit AR 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 niay 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.aov/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: AIRS ID Number: f Fts / O f [Leave blank unless APCD has already assigned.a permit # and AIRS ID] Company equipment Identification: SEP-10, FLR-01 [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: Razor 25 CPB Site Location: SESW, Section 25, T1 ON, R58W Mailing Address: (delude Zip Code) 1700 Broadway, Suite 2300 Denver, 20 80290 E -Mail Address2: 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. .................. A Form APCD-205 - Natural Gas Venting APEN - Rev 03/2017 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit and AIRS ID] Section 2- Requested Action O NEW permit OR newly -reported emission source - OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Change permit limit ❑ Transfer ofownership3 OR • APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: Crude Oil Process Vessel ❑ Add point to existing permit ❑ Other (describe below) 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: VRU or gas gathering downtime. Flaring gas from crude oil vessel during For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / / 10 / 18 / 2017 ❑✓ 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 0 No ❑ Yes ❑✓ No Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 21 .COLORADO • Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator • Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing _ Make: Serial #: Capacity: Gal/min Model: # of Pistons: Leak Rate: Scf/hr/pist ❑ Blowdown Events # of Events/year: Volume per event: ❑� Other Description: Crude Oil Pressurized Vessel MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑✓ Yes Natural Gas Venting Process Parameters': Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: 3 854 , SCF/hr Vent Gas Heating Value: 2 350 , BTU/SCF Requested: 4.05 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 %) 64.994 VOC (Weight %) 79.03 Benzene (mole %) 0.07 Benzene (Weight %) 0.126 Toluene (mole %) 0.034 Toluene (Weight %) 0.071 Ethylbenzene (mole %) 0.003 Ethylbenzene (Weight %) 0.076 Xylene (mole %) 0.007 Xylene (Weight %) 0.017 n -Hexane (mole %) 0.659 n -Hexane (Weight %) 1.300 methylpentane 2, 2, 4-Trimethylpentane 2,2,4-Trimethylpentane (mole %) 0.053 (Weight %) 0.1397 Additional Required Information: Attach a representative gas analysis (including BTEX £t n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Ft n -Hexane, temperature, and pressure) Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 COLORADO.. 31 Itsyszterte at 011.104c Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit = and AIRS ID] Section 5 - Stack Information eographical Coordinates(-. (La₹itude/Longiiude`or L/TM) 40.80358/-103.8128 3 , �Utsc Star tv�� `�� 8 ar eHeet:Jghtto n eve 1 ��Fx r�)-� �G ��.� Y pve.;E FLR-01 40 >2000 64.2 3.1 Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other. (describe): ❑✓ Upward ❑ Horizontal Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap 8 Section 6 - Control Device Information ❑✓ VRU: Pollutants Controlled: VOC and HAPs Size: 60 -hp electric Requested Control Efficiency VRU Downtime or Bypassed Make/Model: 100 % 12 % Jordan Technologies/J-SCG10-3.05-60-4803 ❑ Combustion Device: Pollutants Controlled: VOC and HAPs Rating: 598 MMBtu/hr Type: Open Flare Make/Model: Flare Industries/SFVP-0824 Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: NA 95 98 % % Waste Gas Heat Content 2,350 Btu/scf Constant Pilot Light: ❑✓ Yes O No Pilot burner Rating 0.44 MMBtu/hr Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit r 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): Overall Requested Control F: Efficiency reduction, emissions PM SO, 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: Permit Limits 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.) PM Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor -' Source (AP -42r.. Mfg. etc) Controlledb (Tons/year) Uncontrolled • (Tons/year) Controlled (Tons/year)- Uncontrolled (Tons/year) 0.0075 lb/MMBtu Btu Ib/MMBtu De Minimis SO, NO), 0.068 lb/MM Btu AP -42 De Minimis VOC 1.685 lb/bbl Flash Liberation 1,537.6 9.23 CO 0.310 Ib/MiMBtu AP -42 De Minimis Benzene 0.0027 lb/bbl Flash Liberation 2.45 0.01 Toluene 0.0015 lb/bbl Flash Liberation 1.39 0.01 Ethylbenzene 0.0002 lb/bbl Flash Liberation 0.15 0.001 Xylenes 0.0004 lb/bbl Flash Liberation 0.33 0.002 n -Hexane 0.0277 lb/bbl Flash Liberation 25.26 0.15. 2,2,4- Trimethylpentane Other: 0.0030 lb/bbl Flash Liberation 2.71 0.02 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. Farm APCD-205 -Natural Gas Venting APEN - Rev 03/2017 Permit Number: AIRS ID Number: - / / [Leave blank unless APCD has already assigned a permit r 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 A Ashley Brinkerhoff June 12, 2018 n (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) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-205 -Natural Gas Venting ADEN - Rev 03/2017 6! COLORADO. ar-coPut. 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: AIRS ID Number: . Z 3 /� �C [Leave blank unless APCD has already assigned a permit k and AIRS ID] Company equipment Identification: • SEP-22, FLR-02 [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: Razor 25 CPB Site Location: SESW Sec 25, T10N, R58W Mailing Address: (Include Zip Code) 1700 Broadway, Suite 2300 Denver, CO 80290 E -Mail Address: CDPHEcorrespondence@whiting.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Jacob Parker Phone Number: (303) 357-4078 IPlejase use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes wilt require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-211 - Natural Gas Venting APEN - Rev 03'2017 373706 �® COLORADO 1ctw.o-m.-�t rwc NUYJ L 6nv'.eenmen„ Permit Number: AIRS ID Number: / [Leave hank APCD has ni ]]iar;y a;s sned a permit t] and AIRS ID] . Section 2- Requested Action O NEW permit OR newly -reported emission source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) 4 Change fuel or equipment ❑ Change company name 0 Add point to existing permit 0 Change permit limit 0 Transfer of ownership' 0 Other (describe below) OR - • APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - 1 Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: Produced Water Vessel 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. , • M_ Section 3 - General Information General description of equipment and purpose: Flaring associated gas from produced water vessel during VRU and gas gathering downtime. For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: October / 18 / 2018 ❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Will this equipment be operated in any NAAQS nonattainment area is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 O Yes ❑ Yes ❑✓ No ❑✓ No J1�COLORe DO 2 liM9 txo� a�nv Permit Number: AIRS ID Number: / / Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: Serial #: Capacity: Gal/min ❑ Compressor Rod Packing Make: Model: # of Pistons: Leak Rate: Scf/hr/pist ❑ Blowdown Events # of Events/year: - Volume per event: MMscf/event fJ Other - Description: Produced Water Pressurized Vessel 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? El Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: 1 425 , SCF/hr Vent Gas Heating Value: 1 410 , BTU/SCF Requested: 0.874 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 %) 22.155 VOC (Weight %) 38.41 Benzene (mole %) 0.094 Benzene (Weight %) 0.25 Toluene (mole %) 0.041 Toluene (Weight %) 0.13 Ethylbenzene (mole %) 0.002 Ethylbenzene (Weight %) 0.01 Xylene (mole %) 0.006 Xylene (Weight %) 0.02 n -Hexane (mole %) 0.266 n -Hexane (Weight %) 0.79 entane 2,2,4 Trimethy(mole %) 0.013 2,2,4 Trimet hpentane (Weight %) 0.05 Additional Required Information: 2 Attach a representative gas analysis (including BTEX ft n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX & n -Hexane, temperature, and pressure) Form APCU-211 -Natural Gas Venting APEN - Rev 03/2017 - Ay COLORADO e..UTY Lrv+unmene Permit Number: AIRS ID Number: / nnipsri APIr ,:nn -any ie!! cif._ and AIRS, Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.803575, -103.8128 Operator _ StaCLc 1D.Nn Discharge Height ` Above` Ground Level (eet) Temp ('F) Flow Rate fACFM) Velocity eft/secs) =. FLR-02 40 >2000 3,125 149.2 Indicate the direction of the stack outlet: (check one) D Upward ❑ Horizontal ❑ Downward El Other (describe): Indicate the stack opening and size: (check one) Q Circular Interior stack diameter (inches): ❑ Other (describe): El Upward with obstructing raincap 8 Section 6 - Control Device Information O VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed D Combustion Device: Pollutants Controlled: VOC and HAPs Rating: 598 MMBtu/hr Type: Open Flare Make/Model: Flare Industries SFVP-0824 Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: N/A 95 98 % % Waste Gas Heat Content 1,410 Btu/scf Constant Pilot Light: O Yes El No Pilot burner Rating 0.16 MMBtu/hr Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 Form APCD-211 -Natural Gas Venting APEN Rev 03/2017 4I AY COLORADO Hra!�n h Enronnnr. t ft Permit Number: AIRS ID Number: e h19 _ ,.e;, kPC ha �tv gnFd � Geer nit :' dr d Jk 1D1 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): Overall Requested control Efficiency (%reduction' in emissions) Pollutant PM Control Equipment Description SOX NO,, VOC CO Gas is sent to gas gathering pipeline with open flare as backup 95% HAPs Other: Gas is sent to gas gathering pipeline with open flare as backup 95% From what year is the following reported actual annual emissions data? Permit Limits Use the following table to report the criteria pollutant emissions from source: Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) - Actual _ Annual Emissions Requested. Annual Permit.. •Emission aimit(s)3 Uncontrolled (Tons/year). Controlled6 (Tons/year). Uncontrolled (Tons/year) Controlled (Tons/year): PM 0.0075 lb/MMBtu AP -42 De minimis SOX NO„ 0.068 lb/MMBtu AP -42 De minimis VOC 0.056 lb/bbl Gas Analysis 184.07 0.64 CO 0.310 lb/MMBtu AP -42 De minimis Benzene 0.000 lb/bbl Gas Analysis 1.21 0.004 Toluene 0.000 lb/bbl Gas Analysis 0.62 0.002 Ethylbenzene 0.000 lb/bbl Gas Analysis De minimis De minimis Xylenes 0.000 lb/bbl Gas Analysis De minimis De minimis n -Hexane 0.001 lb/bbl Gas Analysis 3.77 0.01 Trimethylphylpentane 0.000 lb/bbl Gas Analysis 0.25 0.001 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 APED -211 Natural Gas Venting APEN Rev 03`2017 �coioReoo 5 � w�ms�.H��Gx H.,.Hi Y frv+wnmrn. Permit Number: AIRS ID Number: / / r Section 8 Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. January 16, 2018 Sigre of Legally Authorized Person (not a vendor or consultant) Jacob Parker Date Environmental Professional Name (please print) Title Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance ❑r Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-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 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 6l AY COLORADO Jut, 122018 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: I l.) e CEO --"?- AIRS ID Number: I a3 /C(p95lcws [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: SEP-11, FLR-01 [Provide Facility Equipment lb to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: Whiting Oil and Gas Corporation Razor 25 CPB Site Location: SESW, Section 25, T10N, R58W Mailing Address: (include Zip Code) 1700 Broadway, Suite 2300 Denver, CO 80290 E -Mail Address2: CDPHECorrespondence@whiting.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: 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-2O5 - Natural Gas Venting APEN - Rev 03/2017 Ca:...OR A Da. rasx�srn+ne.nf;.vu.�. 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 -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' 0 Other (describe below) -OR - ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ✓❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info & Notes: Produced Water Process Vessel 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Flaring gas from produced water vessel during VRU or gas gathering downtime. For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / / 10 / 18 / 2017 ❑✓ 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 O Yes O Yes ❑✓ No ❑✓ No Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 COLORA DO 2 ` iY.portrocatAdiic - 3lsanTk'�osn>+aonr Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information O Gas/Liquid Separator O Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: Serial #: Capacity: Gal/min # of Pistons: Leak Rate: Scf/hr/pist ❑ Blowdown Events # of Events/year: Volume per event: MMscf/event 0 Other Description: Produced Water Pressurized Vessel If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑✓ Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: 1 425 SCF/hr Vent Gas Heating Value: 1 410 BTU/SCF Requested: 1.50 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 %) 22.16 VOC (Weight %) 38.41 Benzene (mole %) 0.094 Benzene (Weight %) 0.252 Toluene (mole %) 0.041 Toluene (Weight %) 0.129 Ethylbenzene (mole %) 0.002 Ethylbenzene (Weight %) 0.009 Xylene (mole %) 0.006 Xylene (Weight %) 0.021 n -Hexane (mole %) 0.266 n -Hexane (Weight %) 0.788 2,2,4-Trimethylpentane (mole %) 0.013 2,2,4-Trimethylpentane (Weight %) 0.052 Additional Required Information: ❑✓ Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 Permit Number: AIRS ID Number: / / [Leave blank unless APED has already assigned a permit # and MRS ID] Section 5 - Stack Information 23.75 1.1 FLR-01 3eograptireal�Coocrli hat (Latitude7Longatude-car L TM) 40 40.80358/-103.8128 >2000 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): O Other (describe): O Upward with obstructing raincap 8 Section 6 - Control Device Information ❑✓ VRU: Pollutants Controlled: VOC and HAPs Size: 60 -hp electric Requested Control Efficiency VRU Downtime or Bypassed Make /Model: 100 12 % Jordan Technologies/J-SCG10-3.05-60-4803 O Combustion J Device: Pollutants Controlled: VOC and HAPs Rating: 598 MMBtu/hr Type: Open Flare Make/Model: Flare lndustries/SFVP-0824 Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: NA 95 % 98 % Waste Gas Heat Content Constant Pilot Light: p Yes O No Pilot burner Rating 1,410 0.44 Btu /scf MMBtu/hr r Other: Pollutants Controlled: Description: Control Efficiency Requested Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 4I .COLORADO. Permit Number: AIRS ID Number: PM [Leave blank unless APCD has already assigned a permit and AIRS IDI 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): PM SO, NOX 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: Permit Limits From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled 'Er ission Factor'.;" Emission. Factor I b/M M Btu Emission, Factor`. Source (AP -42, Mfg. etc) ncontrolled (Tonsfyear) . Controlledb (Tons/year) . ncontrolled (Tons/year) Controlled, 0.0075 Ib/MMBtu De Minimis SOX NO, 0.068 Ib/M M Btu AP -42 De Minimis VOC 0.0560 lb/bbl Flash Liberation 184.07 1.10 CO 0.310 I b/M M Btu AP -42 De Minimis Benzene 0.0004 lb/bbl Flash Liberation 1.21 0.007 Toluene 0.0002 lb/bbl Flash Liberation 0.62 0.004 Ethylbenzene 0.00001 lb/bbl Flash Liberation De Minimis De Minimis Xylenes 0.00003 lb/bbl Flash Liberation De Minimis De Minimis n -Hexane 0.0011 lb/bbl Flash Liberation 3.77 0.02 2,2,4- Trimethylpentane 0.0001 lb/bbl Flash Liberation 0.25 0.001 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 Permit Number: AIRS ID Number: / I [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. Signature of Legally Aut Ashley Brinkerhoff June 12, 2018 (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) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-205 -Natural Gas Venting ADEN - Rev 03/2017 6 I COLOR ADO neasxmnuedtusbc Hello