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Home My WebLink About20190177.tiffCOLORADO Department of Public Health Et 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 January 3, 2019 Dear Sir or Madam: RECEIVED JAN 0 7 2019 COMMISSIONERS On January 10, 2019, the Air Pollution Control Division will begin a 30 -day public notice period for Noble Energy, Inc. - LC22-AF&B Econode. 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 8 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 PLAa1 ic. P,e, t Itigitq 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer PLL1Pi,14LLIN), P\AJLIM !ER Ic1k t OM 11'1114 2019-0177 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Noble Energy, Inc. - LC22-AftB Econode - Weld County Notice Period Begins: January 10, 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: Noble Energy, Inc. Facility: LC22-A&B Econode Oil and gas production facility NWNE Sec 22, T9N, R59W Weld County The proposed project or activity is as follows: Applicant proposes to operate two (2), co -located, oil and gas production trains at a new exploration and production facility. Facility includes natural gas engines used for compression, hydrocarbon liquid storage tanks, hydrocarbon liquid loading operations, and flaring of gas from gas/oil separators. 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 18WE0279 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 submittedusing 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: Brad Eades Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 Nieskis ORADO Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer Package #: Received Date: Review Start Date: Section 01- Facility Information Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Locatia NWNE quadrant of Section 22, Township 91 Type of Facility: PopfweAanBP 8ifeticA W0lrPad\�`� What industry segment?ww&NaeusaocascraMuctiinn& erocasang Is this facility located in a NAAOS non -attainment area? _•r�a;,.Np If yes, for what pollutant? larbol Monoiae(cm lam�.lao Ma Weld Section 02 - Emissions Units In Permit Application In Weld Cot Quadrant Section Township Range BNOx&MC) Point# Emissions Source Type Equipment Name Emissionswins Control? Permit it Issuance It 5eRCert Required? Arden Engineering Remarks y/ l G f7la��A��iiE^�1 55 gNG, RU42A4 %/// . Y 3&t1E62T4 1 - 3`25 I y� #sstiante LC22 i 002' � Natu 119 RICE \� �Nd �5S'[j4.2�i6r � ,'" ..;, %%/�g � 3dWE6275` i 7, - - Y 1554 n ' • v^6.3 A 2 R Y \� 13 f�y €573�,,9g' EEY' W?+�'%al > #v`orf f1 A r i� '�"5 // , ri CSd,adzl7T �7_. .. •� 77N7,� 3 ��'k�y3l11�,"A3 „,i ,, jTp�v�11 jh •a: pqqp' ,�'ENGEEF.[iS'OY32Siru3e, .y: :f i - _CE+i«Z...G CN KEC7/913 Natural Gat ME- ,,. iNG-1QC(iMM5Q309DD3� .:'. � deal, 1 ,� SWEb2l is 11 i � Y,•; ,1 •.C kai g2r0 ?nitral 7951FeisCe- :. . T9 3i 006 K.2f+ivaFCp gYCF"' fQCHMM303D6O0g0 'E SWED273 ". T'4V�ddfii l flak d C22 h i W7a' 9 NatVral.taas,tYdC61•, Q2050Q fi,�Jc,"•*1#ICHMM5£= .' r s YSWE62 79 \\�\��a��• i• #sVanc\\\s•\a`3 LC'2'2. i .'. :k 408 r 9 ::,;;:, ',, •,, ,' y' f%%s% P12T*>` RICE i ." .,,. 3BNG 3F271026 \ \\Z\,\� SWEDZ32 1 _ Y �. g� in�'swl' y55c78 Cctsee24 f.2}91A 49S NaNY iGa5 R3GE�'\\i ENG NbW00224 .: ��SaWgD278 1 YS �� i7'\\\ L. • 414 , " y" Y ad+r ed[KaT Tank 3 • ' ": to vied Water Tartk %rN,'iJ 'Yesy6/.'�l 8WED2??b F k �'�25/ C$tpah PetrE3Yt \\"•CR2 iS41f3Ae£ A . .. 0114,tyd'r' dcar Fmrrlygmd Lo'adng TLC .. Y IE;WE0272 ",,. •',1, `t. ‘-'....',1, Perrmti is E ib5Cf7318 ..' LC22.A - .. -. .012'` :. �.; '7%an'k•.. Good sate Tank; ,,. yam,......;. &WE0274, Y Y s, LC22 fl13 SE'atA YemRng A "VRT)LP i � L9'Ev 1 YES l Z LQ2 A • 4 ,y ,: } d ,. ,t S Y �.. , F c i I3 \ 1��1 . i Ce - ai£aiAamtli'1'r7 tit12' ' Ll Yak r'i aG R ' l ! £ P6 30,91 , �\\ , ER �\ " ��/ T1c'fE62 2 ' F i ' n kt LRf e-raila=e�u ce#^„asdTjsl:}$ 41Ci:•`,�,• \\ N�t4Ya}t"2v R4�#', - V u-^A3z3i " in Y�'3 C42 3 % P3NyeiRob 9 6 4,n/nyon �" 417 itaW IGasffiC6 FNGfi6504892' '- d/ .,� :. 1$WE0272 i vx �1\`\ �S.i y \�i�'��ss l L€22D .. tF1B #atufahGasftfcE, EWG R6S03102 r`" etc. ` - 1' Yes �� 912 - - .... NatvcaJ5astt#C£ ENG,3']27094'S ��: Z- 1HWEQ2Zq =- - - 1 .� ...`. � �� Y25\\�`7 r� 1710/S`3;1?p', 't Y'fX$/2i5i$ 3i 215,u,%t S ,: ,2jjaLhaEGa 1ktE ENG-Nbz13002SY � '•�":..: SAW�007y' 42Y' aSrJ[aP.r; AfCE tN6-SOGHMM503060426 $ ... 48WED273 Y k i'erpae l 1 IAab / qua ,,., [t�2 fl SNG-x4cHMMas.4xso41� Yss _ ]BWEQi& 3�" P I iy- _ 6errmE 0501 - LC22-B 023 PrA400Pd 3y2� �{ '3 €Pfnd ed Water Ta nk Yes,- 28WE0270I lr� l �3' .armttin del . .., I.ef:22B ... a jl''"S?4 's /l .3fVdMW₹[sp £i94t1uvLOb P jj71 r 11111 '.t ': TLO� Yes 18WE8276 s" ' 'i fer05 110 aI 1s9ux e LC22 B Cond T k "., avV "k ao 1aWED375 1 i �7si do E r• ,LC2z a -...-\...,�,�� t7tB -` 19 S'SP,kttw7( ,, c=': .. =;._ WWII,. ...2aWED15�a ��, : =.0 ,.-_.Y— � . @ey''mrEsmeia€ �s4anoa I.C22 S ion 03 - Description of Project New ell sductien fanikyconsisdno gftwd w (2) prodocemn saw ]--edvii ha Pr ductorYLr ns are6 Emnnde Ls.. ,.'. C2z-A Fnel4des em In a ted ma; thine 11,3}wells( ,tt 7wdrIDedi=iCZaBin Iddes Nobe�abmned prat ppi�r,at<nFf theLC?XA �d [C-z2b 6conodessmee eak prates "determined tna h S,ii!q Idb ggYeg3Y day xTnglesta M ouroeisf ,Yhefaellit[ ,.,.:. On }2/Sj26F8)N hIE ubD7 ff ;d ellaYon mqueetS for Engines V r d9v@h PornuDOd and'0 ken d rIs E 0004 LClA W nO ai (0 oW-Asfxt6Yaew1Vd :11 yell Section 04 - Public Comment Requirements Is Public Comment Required? y , .e•�51�: . W.�. If yes, why? R+sH!?ceuyEfiE'.�P.t.�a.�. ithnm«>r,oeat+lt___-_�� Section 05 - Ambient Air Impact Analysis Requiremen Was a quantitative modeling analysis required? If yes, for what pollutants? 1?13lliS1lP':ztlu�llll:(Yiit'. If yes, attach a copy of Technical Services Unit modeling results summary. Section OR - Facility -Wide Stationary Source Classification Is this stationary source e true mino 7 Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (00) Non -Attainment New Source Review(NANSR) Is this stationary source a major source? If yes, explain what programs and which pollutants hen SO2 N Prevention of Significant Deterioration IPSO) Title V Operating Permits (OP) Non -Attainment New Source Review(NANSR) PM�.5 PM1q TSP HAPs "0 I.1 I 14 PM2.5 PM10 TSP HAPs I I RICE Emissions Inventory Section 01 - Adminstrative Information 1 S123 ,,, " ,';. Facility AIRs ID: County Plant Point *The points listed above cover the same engine make and model. As such, this spreadsheet provides an analysis foreach engine as emissions are identical from each. Section 02- Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested NOx control Efficiency %: Requested VOC Control Efficiency %: Requested CO Control Efficiency %, Requested HCHO Control Efficiency %: POINT# 001 002 017 018 Engine Manufacture Date: '' ^.- ;- 10/31/2014 "; ll r �' 10/27121714 iO.r 00,'≥ i3 tp it 61 12014 ; . Manufacturer: d _ Caterpillar Caterpillar .. ... , 3tetpd(A33U4 goatgiplllar Model Number: x�.��'.,,.G3'..O6NA. G33p61VA "C{3306NAe v.. � G380yNk°. Serial Number: '' f16604244 %6504206 A6500892< ? 716$3102 Engine Function /i`"tnp(pgM. [3 +74th��,; pp{pr rmy � - mFiessiolf Mfg's Max. Rated Horsepower @ sea level: berating " Horsepower used for calcuations: 145 BSCF @ 100% Load (btu/hp-hr): 25.., Site- Rated BSCF@100% load (btu/hp-hr): 8625 Other Parameters Engine Type. Aspiration .- Electrical Generator Max Site Rating (kw) 0 Requested Hours of Operation 6'i PTE Hours of Operation Actual Hours of Operation Section 03 - Processing Rate Information for Emissions Estimates Fuel Use Rate @ 100% Load 1250,625 scf/hr ACTUAL Annual Fuel Consumption k.;;S ,,, , ,. ,.; i '�- tff MMscf/yr MAX POTENTIAL Annual Fuel Consumption 10.96 MMscf/yr REQUESTED Annual Fuel Consumption 10.96 MMscf/yr Fuel Heating Value btu/scf This is a new engine at this facility, so there is no actual data. 18WE0279.CP1.xlsm RICE Emissions Inventory Section 04- Emissions Factors & Methodologies Emission Factors Pollutant SI RICE Engine Uncontrolled Units Controlled. - Units (Natural Gas Consumption) (Natural Gas Consumption) Source NOx 0.500 g/hp-hr 2.000 - g/hp-hr CO voC -.O60CgEI Ufa 0.700 g/hp-hr PMzs 1.941E-02 1.941E-02 Ih/MMBTU 1.941E-02 lb/MM BTU - PMia 502 5.880E-04 . 5,880E-04 Ib/MMBTU Formaldehyde Acetaldehyde 2.790E-03 NjaM TfG„ 2.790E-03 Ib/MMBTU' 0.110 g/hp-hr Acrolein Methanol 3.060E-03 3.0600E-03 Benzene 1.580E-03 �' � 1.580E-03 Toluene 5.580E-04 2.630E-03 2.630E-03 Ib/MMBTU lb/MMBTU .gmELaj. lb/MMBTU .€a€s`1en3s 5.580E-04 lb/MMBTU 2.480E-05 lb/MMBTU Ethylbenzene 2.480E-05 b • a 1.950E-04 lb/MMBTU n -Hexane 0,000E+00 N1 l - 0.000E+00 lb/MMBTU Xylene 1.950E-04 2,2,4-TMP 0.000E+00 1,3 -Butadiene 6.630E-04 B7 0.000E+00 lb/MMBTU 6.630E-04 lb/MMBTU Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tans/year) (tons/year) 500 18.86 0.00 , 0.00 18.86 0.70 CO 18.86 0.00 0.00 18,86 2.80 VOC 0,98 0.00 0.00 0.98 0.98 Mks 0.11 0.00 0.00 0,11 0.11 PMm 0,11 0.00 0.00 0.11 0.11 S02 0.00 0.00 0.00 0.00 0.00 Hazardous Air Potential to Emit Actual Emissions Requested Permit Limits Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year) Formaldehyde - - 756 0 0 756 308 Acetaldehyde 31 0 0 31 31 Acrolein 29 0 0 29 29 Methanol 34 0 0 34 34 Benzene 17 0 0 17 17 Toluene 6 0 0 6 6 Ethylbenzene 0 0 0 0 0 Xylene 2 0 0 2 2 n -Hexane 0 0 0 0 0 2,2,4-TMP 0 0 0 - 0 0 1,3 -Butadiene 7 0 0 7 7 18WE0279.CP1xlsm RICE Emissions Inventory Section 06 - Regulator/ Analysis. Regulatory Requirements Regulation 1 ' Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner oreperator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at15-second intervals for six minutes, The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation.' Regulatien2, - Section I.A - No person,wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable- odors which are measured in excess of the -following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors aredetected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 3 Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: each individual emission point in an attainment area with uncontrolled actualemissions of two ton per year or more of any individual criteria pollutant (pollutants are not summed(. Applicant is required to file an APEN since emissions exceed 2 ton per yearVOC, CO and NOx. Part B — Construction Permit Exemptions - - Applicant is required to obtain a permit.since uncontrolled VOC/NOx/CO emissions from this facility are greater than the threshold In Regulation Number 3, Part B, Section II.D.3.a Regulation 7 Section XVI.B: These engines have a design rate less than 500HP; As a result, the engines are not subject to the air pollution control technology requirements of Section XVI: Section XVII.E: According to Regulation 7 Section XVII.B.5: "intemal combustion engines that are subject to an emissions control requirement in a federal maximum achievable control technology ("MACC') standard under 40 CFR Part 63, a Best Available Control Technology ("BACI") limit, ore New Source Performance Standard ("NSPS") under 40 CFR Part 60 are not subject to Section XVII., except for the leak detection and repair requirements in Section XVII.F." The manufacture date for each of these engines is after July 1, 2008 and will commence construction afterJune 12, 2006, Therefore Theseenginesare "new" per MACIZZZZ and are subjectto requirements in NSPS JJJJ. Since each engine is subject to en applicable standard in NSPS Jill (table 1), they are not subject to the requirements of Regulation 7 Section XVII.E. MACT ZZZZ Each engine will be constructed afterJune 12, 2006 and are therefore "new" per MACI7777 and shall comply with 7777 by complying with NSPS JJJJ. This facility will be an area source for HAPS. NSPS JJJJ Is this engine subject to NSPSJJJJ? I ITe%'``, As noted above, each engine construction date and manfucture date indicate that the engine is subjectto NSPS JJJJ. Per 60.4233(e), SI ICE with maximum engine power greater than 100HP shall comply with the emission standards in Tablet of this subpart. The applicable emission standards in Table 1 are as follows (manufactured after 2011): 1 g/hp-hr NOx, 2 g/hp-hr CO, 0.7 g/hp-hr VOC 18W E0279.CP1.xlsm RICE Emissions Inventory Section 07 - Technical Analysis Notes Addttlonalf%tea *An tHtiel cxenpltan4e'tee+ fiirthisenge #iil`neit4Q iegniPed slr Cequirements asaut5nedrie.G?0.2: AIfheohh this foeillty does.n i *MAGI- 73n#or.area. sources aswell'=asNSPSJU1 have not been adop i not be a cditfon contained within the hod of the permit since 1OPHE Section 08 - Inventory 5CC Coding and Emissions Factors AIRS Point # Process # 5CC Code 001 01 :hp and manufacturerwarenlaes.:a :dueto#aetfihr-iuide emi'ssionxgreatar loradoA! eoteilUaeca0et1 en! to tltc:'co3os.to permit Ito Uncontrolled Emissions Pollutant Factor Control% Units PM10 0.019 0.00% lb/MMBtu PM2.5 0.019 0.00% Ib/MMBtu NOx 3.4430E+00 96.29% lb/MMBtu VOC 0.179 0.00% lb/MMBtu CO 3.443 85.15% Ib/MMBtu Formaldehyde 0.069 59.26% Ib/MMBtu Acetaldehyde 2.79E-03 0.00% lb/MMBtu Acrolein 2.63E-03 0.00% lb/MMBtu Methanol 3.06E-03 0.00% lb/MMBtu Benzene 1.58E 03 0.00% lb/MMBtu Toluene 5.58E-04 0.00% lb/MMBtu Ethylbenzene 2.48E-05 0.00% Ih/MMBtu Xylene 1.95E-04 0.00% lb/MMBtu n -Hexane 0.00E+00 0.00% lb/MMBtu 2,2,4-TMP '0.00E+00 0.00% lb/MMBtu 1,3 -Butadiene 6,63E-04 0.00% lb/MMBtu 'Points 001, 002, 017, 018 cover the same engine make and model. As such, this spreadsheet provides an analysis for each engine as emissions are identical from each. 18WE0279.CP1.xlsm RICE Emissions Inventory Section 01-.Adminstmt ve Information Facility AIRs ID: ,;; -,025 - ', 9FEs ,;! 000 323 �flr il; ljii 31" sFEF :'. 07>z;-, Fp 9FEF County Plant Point *The points listed above cover the same engine make and model. As such, this spreadsheet provides an analysis for each engine as emissions areidentical from each. Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control , Device Description: Requested-NOx Control Efficiency %: Requested VOC Control Efficiency %: Requested. CO Control. Efficiency °A: Requested HCHO Control Efficiency %: Requested Other HAP Control Efficiency %: POINT ft 005 006 007 021 D22 Engine Manufacture Date: ��3j9j2015: 3/6/2015 3/0/2015�� Manufacturer: X33_. ;GM. ..;... 'GN1 ts ,r ,1 GM;-; GM Model Number: 31 S7l. , . 57C a.' %5J 5.71. ',;i:` 331.10.571.:: `.,'._ Serial Number: W00GHMlflo00aspa 00 IOCRMM5000cdoao i}Dcff5A5%55WY 10CHjytM5oa06o05H 3#OCAM0l43oSgoo, Engine Function Derating ' Mfg's Max. Rated Horsepower @ sea level: iiiii,N92iiraiMi Horsepower sed for celcuations: 92 BSCF @ 100% Load (btu/hp-hr): Site - Rated BSCF @ 100% load (btu/hp-hr): -9000 Other Parameters, Engine Type ' 4150 Aspiration ,,yy Electrical Generator Max Site Rating (kw) '-0 Requested Hours of Operation 3IIx 875p: PTE Hours of Operation s875O- Actual Hours ofOperation iiiiiiiIiiiiiiiiffigkitififfil2.. Section 03 - Processing Rate Information for Emissions Estimates Fuel Use. Rate @ 100% Load 828 scf/hr ACTUAL Annual Fuel Consumption '''ti'; MMscf/yr MAX POTENTIAL Annual Fuel Consumption 7.25 NMMscf/yr REQUESTED Annual Fuel Consumption 7.25 MMscf/yr. Fuel Heating Value ',(a;]p _3DWI btu/sof 18WE0279.CP1.xlsm This is a new engine at this facility, so there isno actual data RICE Emissions Inventory Section 04 - Emissions Factors & Methodologies Emission Factors SI RICE Engine Pollutant Uncontrolled I • Units Controlled Units . (Natural Gas Consumption) (Natural Gas Consumption) Source NOx CO VOC 4 000'{,'i"' 11.000 0.7000 'g/hp.=txr 1.000 2.000 . g/hp-hr g/hp-hr g/hp-hr • 0.700 PMzs PMzs. 502 1.941E-02 I ibjtiih94Tt1 1.941E-02 5.880E-04 2.050E-02 2.790E-03 2.630E-03 3.060E-03 1.580E-03 5.580E-04 2.480E-05 1.950E-04 0.000E+00 0.000E-100 6.830E-04 1.941E-02 Ib/MMBTU lb/MMBTU Ib/MMBTU Ib/MMBTU lb/MMBTU . Ib/MMBTU Ib/MMBTU Ib/MMBTU Ib/MMBTU Ib/MMBTU Ib/MMBTU Ib/MMBTU Ib/MMBTU Ib/MMBTU 1.941E-02 5.880E-04 2.050E-02 2.790E-03 2.630E-03 STtt".. _. Formaldehyde Acetaldehyde ififmmaw Acrolein Methanol Benzene Toluene ,.ems ry.�.�'«e• ;F0161.24i 4=Stm)s t's�i rf. , ,3.0600E -03.0 - 1.580E.03 5.580E-04 2.480E-05 1.950E-04 0.000E+00 0.000E+00 6.630E-04 y,�7r,'Eair[e32 3.4-siave�t�,ch-surn.3EieY Ethylhenzene Xylene 3b/1'AR98TU'__ bi n -Hexane 2,2,4 -IMP 1,3 -Butadiene Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) NOx CO 12.44 _ 0.00 0.00 12.44 0.89 9.77 0.00 0.00 9.77 1.78 VOC 0.62 0.00 0.00 0.62 0.62 PMz., 0.07 0.00 0.00 0.07 '0.07 PM,. . 0.07 0.00 0.00 0.07 • 0.07 SO2 0.00 0.00 0.00 0.00 0.00 Hazardous Air Potential to Emit Actual Emissions Requested Permit Limits Pollutants • Uncontrolled. Uncontrolled Controlled Uncontrolled Controlled' (lbs/year) (lbs/year( (lbs/year) (lbs/year) - (lbs/year) Formaldehyde 149 0 0 149 149 Acetaldehyde 20 0 0 20 20 Acrolein 19 0 0 19 19 Methanol 22 0 0 22 22 Benzene 11 0 .' 0 11 11 Toluene 4 0 0 4 4 Ethylbenzene 0 0 0 0 0 Xylene 1 0 0 1 1 n -Hexane 0 0 0 0 0 2,2,4 -IMP 0 0 0 0 0 1,3 -Butadiene - 5 0 0 5 5 18WE0279.CP1.xlsm RICE Emissions Inventory Section 06 - Regulatory Analysis.. Regulatory Requirements. Regulation1 Section. II. A.1 - Except as provided in paragraphs 2through 6 below; no owner or operator of a -:source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20%opacity.This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions Measurement is EPA Method 9 (40 CFR, Part 60; Appendix A (July, 1992)) in all subsections of Section II. A--and'B of this regulation. Regulation 2 - ' Section I A No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single.. source such as to result in detectable odors which are measured in excess of the following -limits: For areas used predominantlyfor residential or commercial purposes it is a violation if odors are detected after the odorous air has been. diluted with seven (7) or more volumes of odor free air. Regulations Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: each individual emission point in an attainment area with uncontrolled actual emissions of two ton per year or more of any individualcriteriapollutant (pollutants are not summed). - Applicant is required to file an APEN since emissions exceed 2 tan per year VOC, CO. and NOx. - Part 0 —Construction Permit Exemptions. Applicant is required to obtain a permit since uncontrolled VOC/NOx/CO emissionsfrom this facility are greater than the threshold in Regulation Number 3, Part B, Section 11.0.3.0 - - Regulation? - Section XVI.B: These engines have a design rate less than SOOHP; As a result, then gins are not subject to the air pollution control technology requirements of Section XVI. Section XVII.E: According to Regulation 7 SectionXVll.B.5: "internal combustion engines that are subject to an emissions control requirement in a federalmezimum achievable control technology("MACi"t standard. under 40 CFR Part 63, a Best Available Control Technology ("BACT") limit, or a New Source Performance Standard ("NSPS") under 40 CFR Part 60 are not subject to Section XVII., except for the leak detection and repair requirements in Section XVII:F." The manufacture date for each of these engines is. after July 1, 2008 and will commence construction after June 12, 2006. Therefore These engines are "now" per MACFZZZZ and are subject to requirements in NSPSJJJJ. Since each engine is subject to an applicable standard in NSPS Jill (see below), they are not subject tathe requirements of Regulation 7 Section XVII.E. - MACT ZZZZ Each engine will be constructed after June 12, 2006 and are therefore "new" per MACTZZZZ and shall comply ZZZZby omplying with NSPS JJJJ. This facility will bean area source for HAPS.' NSP5101 Is this engine subject to NSPS JJJJ As noted above, each engine construction date and manfucture date indicate thatthe engine is subject to NSPS JJJJ. Per. 60.4233(0), SI ICE with maximum engine power greaterthan 25HP and less than 100HP shall comply with the emission standards for field testing in 40 CFR 1048.101(0). The applicable emission standards per 1048.101(c) are as follows (approximate): 2.8 g/hp-hr NOx, 4.8 g/hp-hr CO 18WE0279.CP1.xlsm RICE Emissions Inventory Section 07 -Technical Analysis Notes Section 08'- Inventory SCC Ceding and Emissions Factors AIRS Point # Process # 5CC Code 005 01 Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.019 0:00% Ib/MMBtu PM2.5 0.019 0.00% Ib/MMBtu NOx3.4294E+00 92.86% Ib/MMBtu VOC 0.171 0.00% Ib/MMBtu CO 2.695 81.82% Ib/MMBtu Formaldehyde 0.021 0.00% Ib/MMBtu Acetaldehyde 2.79E-03 0.00% Ib/MMBtu Acrolein 2.63E-03 0.00% Ib/MMBtu Methanol 3.06E-03 0.00% Ib/MMBtu Benzene 1.58E-03 0.00% Ib/MMBtu Toluene 5.58E-04 0.00% Ib/MMBtu Ethylbenzene 2.48E-05 0.00% Ib/MMBtu Xylene 1.95E-04 0.00% Ib/MMBtu n -Hexane 0.00E+00 0.00% Ib/MMBtu 2,2,4-TMP 0.00E+00 0.00% Ib/MMBtu 1,3 -Butadiene 6.63E-04 0.00% lb/MMBtu 'Points 005,006, 007, 021, 022 cover the same engine make and model. As such, this spreadsheet provides an analysis for each engine as emissions are identical from each. 18WE0279.CP1xlsm RICE Emissions Inventory Section 01- Adminstmtive Information Facility AIRS ID: County Plant Poin ii ',Points 001-005 cover the same engine make and model. As such, this spreadsheet provides an analysis for each engine as emissions are identical from each. Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested NOx Control Efficiency 96: Requested VOC Control Efficiency %: Requested CO Control Efficiency %: Requested HCHO Control Efficiency %: Requested Other HAP Control Efficiency %: Point: 009 020 Engine Manufacture Date: ' X6/0120Y1. '7/6/ Manufacturer: �.;,,, C.qt rpiUar I''' x," e "CakerptRar ` Model Number: _.G35161 ' 'G35161. Serial Number: :::::3I6W00224 ,,,:i'N6W90252iiliil Engine FunctionCompression 4,--VVIa0.061 Mfg's Max Rated Horsepower @ sea level: berating Horsepower used for calcuations: 1380 BSCF @ 100% Load (btu/hp-hr): Site - Rated BSCF @ 100% load (btu/hp-hr): 8256 Other Parameters Engine Type Aspiration -- a Electrical Generator Max Site Rating (lomi Requested Hours of Operation "3A:;;c,,:::�;:,;F,giRs PTE Hours of Operation Actual Hours of Operation ,iiiiaiiillailitilliiilii,iiimi0. Section 03- Processing Rate Information for Emissions Estimates Fuel Use Rate @ 100% Load 11393-28 scf/hr ACTUAL Annual Fuel Consumption '-' ....._..........._..._.. ; ≥;fc_.=;:' .(f' MMscf/yr MAX POTENTIAL Annual Fuel Consumption 99.81 MMscf/yr REQUESTED Annual Fuel Consumption 99.81 MMscf/yr Fuel Heating Valueiiiiiiiilih:ii''.,Iil''iti;°Y/1iII ihii i@'.iU 000' btu/scf quipped with This is a new engine at this facility, so there is no actual data. 18WE0279.CP1.xlsm RICE Emissions Inventory Section 04- Emissions Factors & Methodologies Pollutant PM, PMzs Formaldehyde SI RICE Engine Uncontrolled (Natural Gas Consumption) Controlled IMEREIZM (Natural Gas Consumption) 0.700 9.987E-03 9.987E-63 5.880E-04 8.360E-03 5.140E-03 2.500E-03 4.400E-04 4.080E-04 1.840E-04 'TM qp .000 0.700 9,987E-0 9.987E-03 5.880E-04 Ib/MMOTU IM3E= =5111f=tiL Y... __... MIIMMM MEMMEM _ s .:,: r Source 8,360E-0 5.140E-03 2.5000E-0 4.400E-04 4.080E-04 3.970E-0 2.500E-04 2.670E-04 2.500E-04 2,670E-04 Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) NOx CO VOC PM, PM. SO2 9.33 0.00 0.00 9.33 9.33 32.38 0.00 0.00 32-38 . 13.33 9,33 0.00 0.00 9.33 9.33 0.50 0.00 0.00 0.50 0.50 0.50 0.00 0.00 0.50 0.50 0.03 0.00 0.00 0.03 0,03 Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (lbs/year) Requested Permit LimitsHazardous Uncontrolled Controlled (lbs/year) (lbs/year) Formaldehyde Acetaldehyde Acrolein Methanol Benzene Toluene Ethylbenzene Xylene n -Hexane 2,2,4-TMP 1,3 -Butadiene 11460 0 0 11460 5730 834 0 0 ' 834 834 513 0 0 513 513 250 0 0 250 250 44 0 0 44 44 41 0 0 41 41 4 0 0 4 4 18 0 0 18 18 111 0 0 111 111 25 0 0 25 25 27 0 0 27 27 18WE0279.CP1.xlsm RICE Emissions Inventory Section 06 - Regulatory Analysis Regulatory Requirements • Regulation 1 Section II.A.1- Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow. or cause -the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second Intervals for six minutes. The approved reference test method. for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Regulation 2 - - Section IA,- No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess ofthe following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors aredetected after the odorous air has been diluted with seven (7)'or more volumes of odor free air. I Regulation 3 Part A-APENRequirements - - Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices am requiredfor:each individual emission point in an attainment area with uncontrolled -actual emissions of two ton per year or more of any individual criteria pollutant (pollutants are not summed). Applicant is required to file an APEN since emissions exceed 2 ton per year VOC, CO and NOx. Part B —Construction Permit Exemptions Applicant is required to obtain a -permit since uncontrolled VOC emissions from the facility are greater than the 5.0 TPV threshold (Regulation Number 3, Part B, Section II.D.3.a) Regulation 7 - I Section XVI.B: These engines have a design rate greater than 50011P (reported as 1380HP);.however, they are not located in the ozone non -attainment area. As a result, the engines are not subject to the air pollution control technology requirements of Section XVI.B.2 for lean burn engines. Section XVil.E: According to Regulation 7 Section XVII.B.5: "internal combustion engines that are subjectto an emissions control requirementin a federal maximum achievable control technology ("MACF") standard under 40 CFR Part 63, a Best Available Control Technology ("BACT") limit, or a New$ource Performance Standard ("NSPS") under40 CFR Part 60 are not subject to Section XVII., except for the leak detection and repair requirements in Section XVII.F." The manufacture date for each of these engines is after July 1, 2007 (>500HP) andwill commence construction after - June 12, 2006. Therefore These engines are "new" area source per MACE i/r/ and are subject to requirements in NSPS JJJJ. Since each engine is subject to an applicable standard in NSPS JJJJ (table 1), they are not subject to the requirements of Regulation 7 Section XVII.E.. MALT ZZZZ Each engine will be constructed after June 12, 2006 and are therefore "new" per MACE TM. Since this is an area source for purposes of HAPs, it shall comply with 272.2 by complying with NSPS JJJJ. NSPS JJJJ Is this engine subject to NSPS JJJJ? I I As -noted above, each engine construction date and manfucture date indicate that the engine is subject to NSPS Jul.J Per 60.4233(e), Si ICE with maximum engine power greater than 100HP shall comply with the emission standards in Table 1 of this subpart. "the applicable emission standards in Table 1 areas follows (manufactured after 2010, >1,350HP): 1 g/hp-hr NOx, 2 g/hp-hr CO, 0.7 g/hp-hr VOC 18WE0279.CP1xlsm RICE Emissions Inventory Section 07 - Technical Analysis Notes Additional N t s 'tAn'imtiat compliance:kes{¢oz'thisenginewitl.hnregtlrrgd.faf'the.followmgreasons (i};The engine ha's'? rontrolldevr.e ttda;itc.. TO„VOC dldOtr...Tftlsinitial'cnmpi retest is bohs#s%n0w tti the qureiv ts.in-the general perm102lfornatoralgas'tced lest wilt sego€re the.etrgirra•be tasted.for HCHO.:since saircedrregvesdlig a control effielencyof lo% as NSPsd7:5'hove not beenadeptadtnr ,lagetatlon & or 8 by Cotoru4oAOCC: Therefore, thesereglr e €ned within thebodyafthe perrnitshtee-Ct3PHETsnrii the enforcing agencyfar,these regtdremeh%. ' ' ' AIRS Point it Process # SCC Code 009 01 Section 08 - inventory SCC Coding and Emissions Factors ¢ban 500 HP sod { STnei rhbushum engi ries:'Additi Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.010 0.00% lb/MMBtu PM2.5 0.010 0.00% lb/MMBtu NOx 1.8692E-01 0.00% lb/MMBtu VOC 0.187 0.00% lb/MMBtu CO 0.649 58.85% lb/MMBtu Formaldehyde 1.15E-01 50.00% lb/MMBtu Acetaldehyde 8.36E-03 0.00% lb/MMBtu Acrolein 5.14E-03 0.00% lb/MMBtu Methanol 2.50E-03 0.00% lb/MMBtu Benzene 4.40E-04 0.00% lb/MMBtu Toluene 4.08E-04 0.00% lb/MMBtu Ethylbenzene 3.97E-05 0.00% lb/MMBtu Xylene 1.84E-04 0.00% lb/MMBtu n -Hexane 1.11E-03 0.00% lb/MMBtu 2,2,4-TMP 2.50E-04 0.00% lb/MMBtu 1,3 -Butadiene 2.67E-04 0.00% lb/MMBtu *Points 009 6 020 cover the same engine make and model. As such, this spreadsheet provides an analysis for each engine as emissions are identical from each. 18WE0279.CP1xlsm Produced Water Storage Tank(s) Emissions Inventory , Pollutant Section 01- Administrative Information Facility AIRs ID: $J��.31�311i1� 1:33} County Plant Point Section 02- EquipmentDescriptionDetails Detailed Emissions Unit Description: - Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: (produced water Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Produced Water Throughput= Requested Permit Limit Throughput = Potential to Emit (PTE) Produced Water Throughput = Secondary Emissions - Combustion Device(s) Heat content of waste gas= ,_; 1,496! Btu/sd Volume of waste gas emitted per BBL of liquids produced = 36 scf/bbl Actual heat content of waste gas routed to combustion device Requested heat content of waste gas routed to combustion device = age vessels connect anifold Barrels (bbl) per year Actual Produced Water Throughput While Emissions Controls Operating = Barrels (bbl) per year Barrels (bbl) per year 59,775 MMBTU per year 59,775 MMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 59,775 MMBTU per year Section 04 -Emissions Factors & Methodologies Will this storage tank emit flash emissions? Emission, Factors Produced Water Tank Uncontrolled Controlled (lb/bbl) (Ib/bbl) (Produced Water Throughput) VOC 0.262 Benzene D007 Toluene Ethylbenzene Xylene n -Hexane 224 TMP Control Device (Produced Water Throughput) 0.0131 0.0011 0.000 Emission Factor Source Pollutant Uncontrolled Uncontrolled (Ib/MMBtu) (lb/bbl) (waste heat combusted) (Produced Water Throughput) Emission Factor Source PM10 PM2.5 NOx CO :'. Oi0075 it O:0075 _ O:I'680..:.:. 0.3100 Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC 145.4 145.4 7.3 - 145.4 7.3 PM10 0,2 - 0,2 0,2 0.2 0.2 PM2.5 0.2 0.2 0.2 0.2 0.2 NOx 2.0 2.0 2.0 2.0 2.03 CO 9.3 9.3 9.3 9.3 B.27 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled , (lbs/year) Uncontrolled Controlled (lbs/year) llbs/year) Uncontrolled Controlled. (lbs/year) (lbs/year) Benzene 7769 7769 388 7769 388 Toluene 0 0 0 0 0 Ethylbenzene 0 0 0 0 0 Xylene 0 0 0 0 0 n -Hexane 24418 24418 1221 24410 1221 224TMP 0 0 0 0 0 Section 06- Regulatory Summary Analysis Regulation 3, Parts A, B. Source requires a permit Regulation 7, Section XVII.B, C.1, C3 Storage tank is subject to Regulation 7, Section XVII, B, Cl & C.3 Regulation 7, Section XVI I.C.2 Storage tank is subject to Regulation 7, Section XVIi.C2 Regulation 6, Part A, NSPS Subpart OOOO Storage Tank Is not subject to NSPS OOOO (See regulatory applicability worksheet for detailed analysis) 14 of 45 K:\PA\2018\18WE0279.CP1.xlsm Produced Water Storage-Thnk(s) Emissions Inventory Section 07- Initial and Periodic Sampling and Testing Requirements Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized- liquid water sample drawn at the facility being permitted and analyzed using flash liberation analysis? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. - However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. - If no, the permit will contain an."lnitlal Compliance" testing requirement to develop a site specific emissions factor. See PS Memo 14-03, Questions 5.9 and 5.12 for additional guidance on testing. Does the company request a control device efficiency greater than 95% for a flare or combustion device? Ifyes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling . Section 08 - Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # Process # SCC Code 010 - 01 4-04,003-15 Fixed Roof Tank, Produced Water, working+breathing+flashing losses Uncontrolled Emissions Pollutant Factor Control 9 Units PM10 0.01 0 lb/1,000 gallons liquid throughput PM2.5 0.01 0 lb/1,000 gallons liquid throughput NOx 0.09 0 lb/1,000 gallons liquid throughput - VOC 6.2 95 lb/1,000 gallons liquid throughput CO 0.40 0 - lb/1,000 gallons liquid throughput Benzene 0.17 95 lb/1,000 gallons liquid throughput Toluene 0.00 95 lb/1,000 gallons liquid throughput Ethylbenzene 0.00 95 lb/1,000 gallons liquid throughput Xylene 0.00 95 _ lb/1,000 gallons liquid throughput n -Hexane 0.52 . 95 lb/1,000 gallons liquid throughput 224 TMP 0.00 95 lb/1,000 gallons liquid throughput 15 of 45 K:\PA\2018\ 18WE0279.CP1.xlsm Produced Water Storage Tank Regulatory Analysis Worksheet Please note that NIPS Kb might be might be applicable for certain tanks at water management and injection facilities. If the tanks you are reviewing are at one of these facilities, please review NSPS Kb. Colorado Regulation 3 Parts A and B - APEN and Permit Requirements 'Source is inthe Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility far processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions' greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? WORM Pit 'Source requires a permit NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the operator claiming less than 1% crude oll and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M) 3. Are total facilit uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section II.D.2)? You have indicated that source is in the Attainment Area Colorado Regulation 7, Section XVII 1. Is this tank located ate transmission/storage facility? 2. Is this produced water storage tank' located at an oil and gas exploration and production operation , well production facility', natural gas compressor station' or natural gas processing plant? 3. Is this produced water storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions°of this storage tank equal to or greater than 6 tons per year VOC? No 'Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3 Section XVII.B —General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1 - Emissions Control and Monitoring Provisions Section XVII.C.3 - Recordkeeping Requirements 5. Does the produced water storage tank contain only "stabilized" liquids? If no, the following additional provisions a Storage tank is subject to Regulation 7, Section XVII,L.2 Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment Ply. 40 CFR, Part 60, Subpart OOOO, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this produced water storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the Industry? 2. Was this produced water storage vessel constructed, reconstructed, or modified (see definitions. 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Are potential VOC emissions' from the Individual storage vessel greater than or equal to 6 tons per year? 4. Does this produced water storage vessel meet the definition of "storage vessel"' per 60.5430? 'Storage Tank is not subject to NIPS OOOO Subpart A, General Provisions per 460.5425 Table 3 §60.5395 - Emissions Control Standards for VOC §60.5413 -Testing and Procedures §60.5395(g) - Notification, Reporting and Recordkeeping Requirements 460.5416(c) - Cover and Closed Vent System Monitoring Requirements 460.5417 -Control Device Monitoring Requirements, [Note: If a storage vessel Is previously determined to be subject to NSPS OOOO due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS OOOO per 60.5365(e)(7) even if potential VOL emissions drop below 6 tons per year] RACT Review RACT review is required if Regulation 7 does not apply AND if the tank Is In the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend,"'may," "should,"and .can,"is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. Y Produced Water Storage Tank(s) Emissions Inventory Section 01 -Administrative Information Facility AIRs ID, 1231;' i T 9FA9 Countv Plant .023 Section 02- Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: ........................ Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Produced Water Throughput = Requested Permit Umit Throughput= Potential to Emit (PTE) Produced Water Throughput = Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquid produced = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = Barrels (bbl) per year Actual Produced Water Throughput While Emissions Controls Operating= Barrels (bbl) per year Barrels (bill) per year Btu/scf 6: scf/bbl 39,713 MMBTU per year 39,713 MMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 39,713 MMBTU per year Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Emission Factors Produced Water Tank Pollutant Uncontrolled Controlled (Ib/bbl) (Ib/bbl) (Produced (Produced Water Water Throughput) Throughput) Emission Factor Source VOC ^:;3''-- 0:262. 0.01 0.000 0.000 0.000 0.000 0.001 0.000 Benzene =:0i00J .; • Toluene Ethylbenzene X lene Pollutant Control Device Uncontrolled Uncontrolled (lb/MMBtu) (lb/bbl) (Produced Water Throughput) (waste heat combusted) Emission Factor Source PM10 PM2.5 NOx. CO 4111* Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC PM10 PM2.5 NOx CO 96.6 96.6 4,8 96.6 4.83 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 1.4 1.4 1.4 1.4 1.35 6.2 6.2 6.2 6.2 6.16 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TM 5162 5162 258 5162 258 0 0 0 0 0 0 0 0 0 o 0 0 0 0 0 16223 16223 811 16223 811 0 0 0 0 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XVII.B, C.1, C.3 Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3 Regulation 7, Section XVII.C2 Storage tank is subject to Regulation 7, Section XVII.C.2 Regulation 6, Part A, NSPS Subpart 0000 Storage Tank is not subject to NSPS 0000 (See regulatory applicability worksheet for detailed analysis) 713.65138 0.19 17 of 45 K:\PA\2018\ 18WE0279.CP1.xlsm Produced Water Storage Tank(s) Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use a site specific emissions factor to estimate emissions? ?; If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn at the facility being permitted and analyzed using flash liberation analysis? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g-, no new wells brought on-line), then it maybe appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor. See PS Memo 14-03, Questions 5.9 and 5.12 for additional guidance on testing. Does the company request a control device efficiency greater than 95%for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 -Technical Analysis Notes Section 09- Inventory SCC Coding and Emissions Factors AIRS Point # 023 Process# SCC Code 01 4-04-003-15 Rued Roof Tank, Produced Water, working+breathing+flashing losses Uncontrolled Emissions Pollutant Factor Control ? Units PM10 0.01 0 lb/1,000 gallons liquid throughput PM2.5 0.01 0 lb/1,000 gallons liquid throughput NOx 0.09 0 lb/1,000 gallons liquid throughput VOC 6.2 95 lb/1,000 gallons liquid throughput CD 0.40 0 lb/1,000 gallons liquid throughput Benzene 0.17 95 lb/1,000 gallons liquid throughput Toluene 0.00 95 lb/1,000 gallons liquid throughput Ethylbenzene 0.00 95 lb/1,000 gallons liquid throughput Xylene 0.00 95 lb/1,000 gallons liquid throughput n -Hexane 0.52 95 lb/1,000 gallons liquid throughput 224 TMP 0.00 95 lb/1,000 gallons liquid throughput 18 of 45 K:\PA\2018\ 18WE0279.CP1.xlsm Produced Water Storage Tank Regulatory Analysis Worksheet Please note that NSPS Kb might be might be applicable for certain tanks at water management and Injection facilities. If the tanks you are reviewing are at one of these facilities, please review NSPS Kb. Colorado Regulation 3 Parts A and B - APEN and Permit Requirements (Source is in the Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II,D.1,M) 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.3)? 'Source requires a permit NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the operator claiming lass than 1% crude oil and Is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section II.D.2)? 'You have indicated that source is in the Attainment Area Colorado Regulation 7, Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this produced water storage tank' located at an oil and gas exploration and production operation , well production facility', natural gas compressor station' or natural gas processing plant? 3. Is this produced water storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions° of this storage tank equal to or greater than 6 tons per year VOC? !Storage tank;is suftlect to Regulation 7, Section XVII, 0, 0.1 & C.3 Section XVII.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1 - Emissions Control and Monitoring Provisions Section XVII.C.3 - Recordkeeping Requirements 5. Does the produced water storage tank contain only "stabilized" liquids? If no, the following additional provisions apply. 'Storage tank is subject to Regulation 7, Section XVll,C.2 Section XVII.C.2 -Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR. Part 60, Subpart 0000, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this produced water storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this produced water storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Are potential VOC emissions' from the Individual storage vessel greater than or equal to 6 tons per year? 4. Does this produced water storage vessel meet the definition of "storage vessel"' per 60.5430? 'Storage Tank is not subject to NSPS 0000 Subpart A, General Provisions per §60.5425 Table 3 §60.5395 - Emissions Control Standards for VOC §60.5413 -Testing and Procedures §60.5395(g) - Notification, Reporting and Recordkeeping Requirements §60.5416(c) - Cover and Closed Vent System Monitoring Requirements §60.5417 - Control Device Monitoring Requirements [Note: If a storage vessel is previously determined to be subject to NSPS 0000 due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS 0000 per 60.5365(e)(2) even if potential VOC emissions drop below 6 tons per year] RACE Review RACE review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACE requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not &range or substitute for any law, regulation,, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend,""may," "should," and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must' and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself, 9 CS' MOM No Yes —! Yes Nod Hydrocarbon Loadout Emissions Inventory Section 01- Administrative Information 'Facility AIRS ID: 4R/t4Ai}rim'. Plant Polo Section 02- Equipment Description Details .Detailed Emissions Unit Description: Emission ControlDevice Description: Is this loadout controlled? Collection Efficiency: Control Efficiency: • Requested Overall VOC & HAP Control Efficiency %: Section 03- Processing Rate Information for Emissions Estimates Primary Emissions - Hydrocarbon Loadout Actual Volume Loaded = Requested Permit Limit Throughput = Potential to Emit (PTE) Volume Loaded = Secondary Emissions - Combustion Device(s) Heat content of waste gas= - - Volume of waste gas emitted per year = 133053 scf/year Actual heatcontent of waste gas routed to combustion device= - Requested heat contentof waste gas routed to combustion device = - 95.00 'Barrels (bbl) per year Barrels (hbl) per year Barrels (bbl) per year ;TPLS5g Btu/scf Potential to Emit (PTE) heat content of waste gas routed to combustion device = Section 04- Emissions Factors & Methodologies Does the company use the state default emissions factors to estimate emissions? Are the emissions factors based on a stabilized hydrocarbon liquid sample drawn at the facility being permitted? Loading Loss Equation L= 12:46°5°P°M/T No Actual Volume Loaded While Emissions Controls Operating = Volume (sct/year( = [Uncontrolled VOC (tan/yearfit[2000 lb/ton)/[Molecular Weight (lb/lb-mol)(°l379 scf/ib-moll 0 MMBTU pe ryear - - 300 MMBTUper year 300 M MBTII per year A site specific stabilized hydrocarbon liquid sample must be provided to develop a site specific emissions factor. Factor Meaning Value Units Source 5 Saturation Factor 0.6 P True Vapor Pressure MONNA-am psis P 42Ch-pter 71 I:*.1 : 44 M Molecular Weight of Vapors i 68 - :Ib/Ib-teal = '.733 j3131jj 31>v Q�1yh AP 42 Ui pter7Fable 7 li. ,.;,=zsjl UgIitI T Liquid Temperature t, $3 43V Rankine �� II�lI p)l3j 3,,,, ,, - P014 iiii4a1]] t L Loading Losses 3.32847'3634 lb/1000 gallons ;, 3 ,., � •a i > ( `^� t , _- ' -- _ 0.139795393 lb/bbl Component Mass Fraction Emission Factor Units Source Benzene 0.000363469 1b/hhl Y§ �� ,�„ lf, �,yt', 33j3Ij 3 •- missron T nK Flash E5pe {H atop YSVS _ ,,, ; .. j- \ 'r t ,� , /fj ``:„ . , - _ Toluene fi"isbaii1 1232006 l 0000307551 lb/bbl Ethylhe �i. iLU30°fei1 - 4.19388E-05 I6/bbl Xyle '?l�a `rW1 3 �3 0,0005a l 0.000111837 lb/lab n-Hexane 0.001817347 lb/bbl 2247MP =1."-� a .0.350 „ _ 0.000209694 lb/bbl Emission Factors Hydrocarbon Loadout Pollutant Control Device Pollutant Uncontrolled Controlled (Ih/bbl) (Volume Loaded) 0b/bbl) (Volume Loaded) Uncontrolled (Ib/MMBtu) Uncontrolled (waste heat combusted) (Ib/bbl) (Volume loaded) Emission Factor Source Emission Factor Source 0.0026 0.0022 0.0003 0.0008 0.013 0.0015 20 of 45 Ki \PA\2018\18 W E0279. CP 1. xl sm Hydrocarbon Loadout Emissions Inventory Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tone/year) Requested Permit Limits Uncontrolled Controlled Itono/yeerl Bone/year) PM10 PM2.5 5Ox NOx VOC _ _ _ CO 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.01 0.01 11.94 0.00 0.00 11.94 0.60 0.05 0.00 0.00 0.05 0.05 Hazardous Air Pollutants Potential to Emit Uncontrolled Ilbs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (Ibs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224TMP 62 0 0 62 3 53 0 0 53 3 7 0 0 7 0 19 0 0 19 1 310 0 0 310 16 36 0 0 36 ' 2 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit RACT- Regulation 3, Part B, Section III.D.2.a (See regulatory applicability worksheet for detailed analysis) Not enough information Section 01- Initial and Periodic Sampling and Testing Requirements Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 0a - Technical Analysis Notes I )nfprmedNobe of the caiculation methodsu da aiRAP specialism ibased onmodeled flash emission composition fmm condensates 'With revised application received May 201g, eppliean₹peavided.stable oil analysis Ind • Section 09 - InventorySCC Coding and Emissions Factors AIRS Point # 011 Process # 01 hres)tolds, ameoylisluefimtt Is navglhe • issupports the applicants useafgasoline 1VP7ffr encnuvocalculations. SCC Code 4-06-001-32 Crude Oil Submerged Loading Normal Service (1.6) Uncontrolled Emissions Pollutant Factor Control% Units FIM10 0.00 0 lb/1,000 gallons transferred PM2.5 0.00 0 Ib/1,000 gallons transferred SOx 0.00 0 lb/1,000 gallons transferred NOx 0.00 0 lb/1,000 gallons transferred VOC 3.3 95 lb/1,000 gallons transferred CO 0.01 0 lb/1,000 gallons transferred Benzene 5.01 95 lb/1,000 gallons transferred Touene 0.01 95 lb/1,000 gallons transferred Ethygrenzene 0.00 95 lb/1,000 gallons transferred Xylene 0.00 95 16/1,000 gallons transferred n -Hexane 0.04 95 lb/1,000 gallons transferred 224 TMP 0.00 95 lb/1,000 gallons transferred 21 of 45 Ki\PA\2018\ 18WE0279.CP1.xlsm Hydrocarbon Loadout Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - AP EN and Permit Requirements Source Is In the Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.1)? 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.3)? 'Source requires a permit NON -ATTAINMENT 1. -Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.0.1.a)? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.1)? 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? - 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section I I.D.2)? You have indicated that source Is in the Attainment Area 7. RACT-Are uncontrolled VOC emissions from the loadout operation greater than 20 tpy (Regulation 3, Part B, Section III.D.2.a)? Not enough information Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, . and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," "may," "should," and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself Hydrocarbon Loadout Emissions Inventory Section 01 -Administrative Information (Facility AIRS ID: 123 County Plant 031. Point Section 02- Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Is this loadout controlled? Collection Efficiency: Control Efficiency: 95.00 Requested Overall VOC & HAP Control Efficiency %: Section 03- Processing Rate Information for Emissions Estimates Primary Emissions - Hydrocarbon Loadout Actual Volume Loaded = Requested Permit LimitThroughput = Potential to Emit (PTE) Volume Loaded = Secondary Emissions- Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per year= Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = Barrels (bbl) per year Barrels (bbl) per year Barrels (bbl) per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = Section 04 - Emissions Factors & Methodologies Does the company use thestate default emissions factors to estimate emissions? Actual Volume Loaded While Emissions Controls Operating = Barrels (bbl) per year Volume (scf/year) = [Uncontrolled VOC (ton/year)]*[2000 lb/ton]/[Molecular Weight (Ib/Ib-mal)]*[379 scf/Ib-mol] 0 MMBTU per year 193 MMBTU per year 193 MMBTU per year Are the emissions factors based on a stabilized hydrocarbon liquid sample drawn at the facility being permitted? Loading Loss Equation L =12.46*S*P*M/T No Factor Meaning . Value Units Source S Saturation Factor 0,6 /,�. %// ''// ' ' ; ii.<'.1APt+4�'JCE�p�N�`,+`�'le;5Z3,SUliiri9rgFd Eoa¢.n.7"x P True Vapor Pressure / ;� 'I'� p a AP -42 Chapter 7Tabia'.7.12 M Molecular Weight of Vapors Y „.fi8h'3:�' '.', Ib/Ib-mol AP 42 Chapter 7Table 7,1-2 ;.�, T Liquid Temperature s 5.`ARS_/a Rankine '.'. Field Data L Loading Losses 3.328473634 lb/1000 gallons _-_ 0.139795893 lb/bbl Component Mass Fraction Emission Factor Units Source Benzene :0 962 0.000566481 1b/bbl i 3 ," s N .... " s T rtk Fla hEmissconSpecaatcan YSgglg 3>l� (H !" ?P Toluene ll.tetllalr, 98s�''i ' 0.000335231 1b/bbl Ethylbenzene ra( iv 111f I ;ilV 0.000297765 Ib/bbl Xylene / 060t _,,, v 1226 0.00017139 lb/bbl n -Hexane MEPIP1133 0018495 0.002585525 lb/bbl 224 'IMP i ,1311„1,:7q tl0%7,7 0.000303357 lb/bbl CO 23 of45 K:\PA\2018\18WE0279 CP1.xlsm Section 05 - Emissfons Inventory Hydrocarbon Loadout Emissions Inventory Criteria Pollutants - - - Potential to Emit - 'Uncontrolled. (tons/year) Actual Emissions Uncontrolled- : Controlled (tons/year)- ` (tons/year) ,,Requested Permit Limits ' Uncontrolled Controlled (tons/year)-(tons/year).' PM10 ' PM2.5 - - ' 50x ' - NOx VOC . CO ' 0.05 '. 0.00 0.00 ' 0.00 0.00 - 0.00 - .0.00 0.00 0.00 0.00 0.00 0.00 - 0.00 - 0.00 0.00 0.01 0.00 0.00 0.01 0.01 7.69' - 0.00 -0.00 7.69 . 0.38 'w 0:03 0.00 0.00 - 0.03 0.03 ' Hazardous Air Pollutants Potential to Emit Uncontrolled:':. (lbs/year). _ . - Actual Emissions ,Uncontrolled- --Controlled (Ibs/year) - - (Ibs/year) Requested Permit limits Uncontrolled Controlled:. . (Ibs/year)• (Ihs/year) Benzene Toluene. - Ethylbenzene Xylene. n -Hexane 224 TMP - 56 - 0 - - 0 56 3 37 . 0 0 37 2 33 0 _ 0 33 2 19 0 - 0 19 1 284 0 0 284 14 33 - 0 - - 0 33 2 Section 06 -Ile Summary Analysis Regulation 3, Parts A, 0 Source requires a permit RACE- Regulation 3, Part B, Section 111.0.2.a (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Not enough information Does the company request a control device efficiency greater than 95% for a flareor-combustion device?,�- If yes, the permit will contain and initial compliancetest condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 -Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors - AIRS Point # 011. Process # 01 deny combustion emissions from -the control device However oreem.ssions are below repo rt griaesholds an rnrsson fenny isnn on was usedfor LC22 A.and LG22-0 as they setc`avQ�gJds. pilcants useof obneRVPi r emosr''n cakbaid idd's�' 1 SCC Code 4-06-001-32 Crude Oil: Submerged Loading Normal Service (S=0.6) Uncontrolled Emissions Pollutant Factor Control % Units PM10 - 0.00 0 lb/1,000 gallons transferred PM25 0.00 0 - lb/1,000 gallons transferred SOn 0,00 0 lb/1,000 gallons transferred NCk 0.00 0 - lb/1,000 gallons transferred VOC 3.3 95 Ib/1,000 gallons transferred CO 0.01 - 0 lb/1,000 gallons transferred Benzene 0.01 - 95 lb/1,000 gallons transferred Toluene 0.01 95 lb/1,000 gallons transferred Ethylbenzene 0.01 95 lb/1,000 gallons transferred Xylene 0.00 95 lb/1,000'gallons transferred n -Hexane 0.06 -95 lb/1,000 gallons transferred 224 IMP 0.01 95 lb/1,000 gallons transferred 24 of 45 IC: \PA\2018\18WE0279:CP1'.xlsm Hydrocarbon Loadout Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements (Source is in the Attainment Area .ATTAINMENT _ 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the loadout located at an exploration and production site (e.g„ well pad) (Regulation 3, Part B, Section 11.0.1.1)? 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill -procedure? 6. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? (Source requires a permit NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than 1 TPY (Regulation 3, Part A, section 11.0.1.8)? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.1)? 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section II.D.2)? You have indicated that source is in the Attainment Area 7. RACT - Are uncontrolled VOC emissions from the loadout operation greater than 20 tpy (Regulation 3, Part B, Section III.D.2.a)? INot enough information Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," "may," "should,"and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself Y dA # No' Yesl Condensate Storage Tank(s) Emissions Inventory Section 01- Administrative Information Facility AIRs ID: ki3h iii llii i .�� :l. .r 9FA9 lrpl i./ ,,,: County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency it: Section 03- Processing Rate Information for Emissions Estimates Primer/ Emissions - Storage Tank(s) Actual Condensate Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Condensate Throughpu Secondary Emissions - Combustion Device(s) Heat content of waste gas= .,,2693#tj Btu/scf Volume of waste gas emitted per BBL of liquid produced = - scf/bbl Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = Barrels (hbl) peryear Barrels (bbl) per year Barrels (hall per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Actual Condensate Throughput While Emissions Controls Operating= 3.3 ur•, ' : Barrels (bbl) per year 285.1342313 scfh 0 MMBTU peryear 6,726.64 MMBTU peryear 6,727 MMBTU peryear Pollutant Pollutant Uncontrolled Controlled (Ib/bbl) (lb/bbl) (Condensate Throughput) 0.2339 4.5F 04 3.9E-04 5:9E-05:'`'% S 15E-04.:' 23003: 2.6E-04 (Condensate Throughput) 3.0E-06 Control Device Uncontrolled Uncontrolled (Ib/MMBts) (waste heat combusted) (Ib/bbl) 5:1 ): R 06751';; ,A�668Q.-3S.-fsi 0(3100;;;•;1 (Condensate Throughput) 0.0000 0.0000 0.0003 0.0012 Emission Factor Source Emission Factor Source Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC PM10 PM2.5 NOx CO 210.5 0.0 0.0 210.48 - 10.52 0.0 0.0 0.0 0.03 0.03 0.0 5.0 0.0 0.03 0.03 0.2 0.0 0.0 0.23 - 0.23 1.0 0.0 0.0 1.04 1.04 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controled (Ibs/year) (Ibs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 809 0 0 809 40 693 0 0 693 35 107 0 0 107 S 270 0 0 270 14 4115 a 0 4115 206 470 0 0 470 24 Section 06'- Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XII.C, D, E, F Storage Tank is not subject to Regulation 7,Section XII.C-F Regulation 7, Section XII.G, C Storage. Tank is not subject to Regulation 7, Section XII.G Regulation 7, Section XVII.B, C.1, C.3 Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3 Regulation 7, Section XVII.C.2 Storage tank is subject to Regulation 7, Section XVII.C.2 Regulation 6, Part A, NIPS Subpart Kb Storage Tank is not subject to NSPS Kb. Regulation 6, Part A, NSPS Subpart OO0O Storage Tank is not subject to NSPS OOOO or NSP5 0000a (based on emissions < 6tpy VOC per vessel) Regulation 8, Part E, MACE Subpart HH Storage Tank is not subject to MAR HH (See regulatory applicability worksheet for detailed analysis) 26 of 45 K:\PA\2018\18W E0279.CPLxlsm Condensate Storage Tank(s) Emissions Inventory Section 07 - Initial and PeriodicSampling and Testing Requirements Does the company use thestate default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions estimated to be gloater than or equal to 80 tens VOC per year? If yes,,the permit will contain an "Initial Compliance" testing requirementte develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company use a site specific emissions factor to estimate emissions? Ifyes.and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted? This sample should -he considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based.on guidelines In PS Memo 05-0 _ Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes pmb soon rn i sioi e.e �, and prvycril a prose throuEhpt(2693BPD] 5a i 104 tpyr ¢p ti ly (c AIRS Point # 012 Section 09 - Inventory SCC Coding and Emissions Factors Process # SCC Cade 01 t erefined the calcolat Btu/scf (fr Hysys};;a y alcubtmn methodoteg io use default values in the memo or gas flows olumetnc flow (0:2688 MSCFH) and modeled stilts in NOx ands emissions 090,23 tpy and Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons condensate throughput PM2.5 0.00 0 lb/1,000 gallons condensate throughput NOx 0.01 0 Ib/1,000 gallons condensate throughput VOC 5.6 95 Ib/1,000 gallons condensate throughput CO 0.03 0 Ib/1,000 gallons condensate throughput Benzene 0.01 95 lb/1,000 gallons condensate throughput Toluene 0.01 95 lb/1,000 gallons condensate throughput Ethylbenzene 0.00 95 Ib/1,000 gallons condensate throughput Xylene 0.00 95 Ib/1,000 gallonscondensate throughput n -Hexane 0.05 95 lb/1,000 gallons condensate throughput 224 TMP 0.01. 95 lb/1,000 gallons condensate throughput . 27 of 45 K:\PA\2018\18W E0279.CPLxism Condensate Tank Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APBN and Permit Requirements 'Source is in the Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2TPY (Regulation 3, Part A, Section q.D.1.e)? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, Nor greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.3)? 'Source requires a Hermit NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)?• 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPV or CO emissions greater than 5 TPY (Regulation 3, Part B, Section 11.0.2)? You have indicated that source is in the Attainment Area Colorado Regulation 7, Section XII.C-F 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at en oil and gas exploration and production operation', natural gas compressor station or natural gas drip station? 3. Is this storage tank located upstream of a natural gas processing plant? Storage Tank is not subject to Regulation 7, Section ;411.0-F Section XII.C.1 —General Requirements for Air Pollution Control Equipment— Prevention of Leakage Section XILC.2 —Emission Estimation Procedures Section XII.D — Emissions Control Requirements Section XII.E —Monitoring Section XII.F— Recordkeeping and Reporting Colorado Regulation 7, Section XII.G 1. Is this storage tank located in the B -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located eta natural gas processing plant? 3. Does this storage tank exhibit 'Flash" (a,g, storing non -stabilized liquids) emissions and have uncontrolled actual emissions greater then or equal to 2 tons per year VOC? Storage Tank is not subject to Repletion 7, Section 511.0 Section 511.0.2 - Emissions Control Requirements Section XII.C.1 —General Requirements for Air Pollution Control Equipment— Prevention of Leakage Section XII.C.2 — Emission Estimation Procedures Colorado Regulation 7, Section XVII 1. Is this tank iodated eta transmission/storage facility? 2. Is this condensate storage tank' located at an oil and gas exploration and production operation , wet production facility', natural gas compressor station or natural gas processing plant? 3. Is this condensate storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions' of this storage tank equal to or greater than 6 tons per year VOC? 'Storage tank is subject to Regulation 7, Section XVR, 8, 0.1 iG C.? Section XVII.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1- Emissions Control and Monitoring Provisions Section XVII.C.3 - Recordkeeping Requirements 5. Does the condensate storage tank contain only "stabilized" liquids? Storage tank is subjectto Regulatun 7, Suction Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Pert 60, Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1, Is the Individual storage vessel capacity greater than or equal to 75 cubic meters (m5) ["472 BBLs]? 2. Does the storage vessel meet the following exemption in 60.111b(d)(4)? a. Does the vessel has a design capacity less than or equal to 1,589.874 m5 ['10,000 BBL] used for petroleum' or condensate stored, processed, or treated prior to custody transfer' as defined in 60.1116? 3. Was this condensate storage tank constructed;reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23, 1984? 4. Does the tank meet the definition of "storage vessel"' In 00.111k? 5. Does the storage vessel store a "volatile organic liquid (VOL)"a as defined in 60.1110? 6. Does the storage vessel meet any one of the following additional exemptions: — a. Is the storage vessel a pressure vessel designed to operate In excess of 204.9 kPa ("29,7 psi] and without emissions to the atmosphere (60.110b(d)(2))?; or b. The design capacity Is greater than or equal to 151 m5 [-950 BBL] and stores a liquid with a maximum true vapor pressures less than 3.5 kPa (60,110b(6))?; or c. The design capacity Is greater than or equal to 75 M5 ["472 BBL] but less than 151 ma ("950 BBL] and stores a liquid with a maximum true vapor pressures less than 15.0 kPa(60.1106(b))7 'Storage Tank is not subject to NSPS Kb Subpart A, General Provisions §60.1126 - Emissions Control Standards for VOC §60.1130 - Testing and Procedures §60.1150 - Reporting and Recordkeeping Requirements §60.1166- Monitoring of Operations No Yes No No No Yea WEN 40 CFR, Part 60, Subpart 0000, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this condensate storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this condensate storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 20157 3. Are potential VOC emissions' from the Individual storage vessel greater than or equal to 6 tons per year? 4. Does this condensate storage vessel meet the definition of "storage vessel"' per 60.5430? 5. Is the storage vessel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart HH? 'Storage 'funk is ca 000 or NSPS 00000 (based ah omissions 4 604 VOC pe€ vessel) Subpart A, General Provisions per 460.5425 Table 3 460.5395 - Emissions Control Standards for VOC 460.5413 -Testing and Procedures §60.53951gj - Notification, Reporting and Recordkeeping Requirements 560.5416(e) - Cover and Closed Vent System Monitoring Requirements §60.5417 - Control Device Monitoring Requirements [Note, if a storage vessel Is previously determined to be subject to NSPS 0000 due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS 0000 per 60.5365(e)(2) even if potential VOC emissions drop below 6 tons per year] 40 CFR, Part 63, Subpart MACT HH, Oil and Gas Production Facilities 1. Is the storage tank located at an ail and natural gas production facility that meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR b. Afacility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or Is delivered to a final end users (63.760(a)1311? 2. Is the tank located at a facility that is major' for HAPs? 3. Does the tank meet the definition of "storage vessel"' to 63.7617 4. Does the tank meet the definition of "storage vessel with the potential for flash emissions"' per 63.7617 5. Is the tank subject to control requirements under 40 CFR Part 60, Sub art Kb or Subpart 0000? 'Storage 'tank is not subject to MAC? flit Subpart A, General provisions per §63.764 (a) Table 2 §63,766 - Emissions Control Standards §63.773 - Monitoring §63.774-Recordkeeping §63.775 - Reporting RACT Review RACT review Is required if Regulation 7 does not apply AND If the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," may," 'should," and "can,"is Intended to describe APCD interpretations and recommendations. Mandatory terminology such as 'must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself You Condensate Storage Tank(s) Emissions Inventory Section 01- Administrative Information Facility AIRs ID: Coun Plant Pain Section 02'- Equipment Description Details Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions- Storage Tank(s) Actual Condensate Throughput= Requested Permit Limit Throughput= Potential to Emit (PTE) Condensate Throughpu Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquid produced= �l`l' b534SC'scf/bbl Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = Potential to Emit (PTE) heat content of waste gas routed to combustion device= Section 04 - Emissions. Factors & Methodologies Barrels (bbl) per year Actual CondensatoThroughput While Emissions Controls Operating 00O Barrels (bbl) per year arrels (bin) per year Will this storage tank emit flash emissions? Section 05 - Emissions Inventory (Condensate. Throughput) Benzene 1111"fl3tict. Toluene Ethylbenzene Xylene n -Hexane 224 TMP Pollutant (Condensate Throughput) 3.4E-05 1.2£-05 2,6E-04 Control Device Uncontrolled Uncontrolled (Ib/MMBtu) (Ib/bhl) Emission Factor Source (waste heat combusted) Btu/scf . .173.4458028 scfh 0 MMBTU per year 4,063 MM BTU per year 4,063. MM BTU per year (Condensate Throughput) 0.0000 Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tans/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC 144.3 0.0 0.0 144.28 7.21 PM10 0.0 0.0 0.0 0.02 0.02 PM2.5 0.0 0.0 0.0 0.02 - 0.02 NOx 0.1 0.0 0.0 0.14 0,14 CO 0.6 0.0 0.0 0,63 0.63 Potential. to Emit. Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled fibs/year) (Ibs/year) (lbs/year) (lbs/year) (lbs/year) Benzene 1222 0 0 1222 61 Toluene 809 0 0 809 40 Ethylbenzene 719 0 0 710 36 Xylene 293 0 0 , 293 15 n -Hexane 6241 0 0 6241 312 224 TMP 732 0 0 732 37 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Section XII.C, D, E, F Regulation 7, Section.XII.G, C Regulation 7, Section XVII.B, C.1, C.3 Regulation 7, Section XVI I.C.2 Regulation 6, Part A, NSPS Subpart Kb Regulation 6, Part A,NIPS Subpart0000 Regulation 8, Part E, MACT Subpart HH (See regulatory applicability worksheet for detailed analysis) Source requires a permit Storage Tank is not sobjectto Regulation 7, Section.Xll.C-F Storage Tank is notsubject to Regulation 7, Section XII.G Storage tank is subject to Regulation 7, Section XVII, 0, C.1 & C.3 Storage tank is subject to Regulation 7, Section XVIl.C.2 Storage Tank is not subject to NSPS Kb Storage Tank is not subject to NSPS 0000 or NSPS 0000a (based on emissions a 6tpy VOC per vessel) Storage Tank is not subject too:MAGI Hit 30 of 45 K:\PA\2018\18WE0279.CP1.xlser Condensate Storage Tank(s) Emissions Inventory Section 07- Initial and Periodic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? lives, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? • If yes, the permit will contain en "Initial -Compliance" testing requirement to develop a site specificemissions factor based on guidelines in PS Memo 05-01. Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based ono pressurized liquid sample drawn at the facility being permitted? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it maybe appropriate to use an older sine -specific sample. Iks If no, the permit will contain arr"Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes om Wticnamissans9rncalevlaterlu;nglb/lbf fiowo:and ptopertiec from,. process S0f I-Il 604 tiaeled throughpt, i29 xa4d:C.,D en*issians of 0,14a� AIRS Point# 025 Section 09 - Inventory SCC Coding and Emissions Factors Process # SCC Code 01 lyef6rrvfrom contr F'ofsttsrc tanksl5 to use defac tt; vfved'af1:2l6scf/bbl based'anHysys'fiash`.tree Tow of 4,061 MMBTU/yr is touted to the storase tanks f P Icy the appiicant. Uncontrolled Emissions Pollutant Factor Control% Units PM10 0.00 0 lb/1,000 gallons condensate throughput PM2.5 0.00 0 Ib/1,000 gallons condensate throughput NOx 0.01. 0 lb/1,000 gallons condensate throughput VOC 5.7 95 lb/1,000 gallons condensate throughput CO 0.02 0 lb/1,000 gallons condensate throughput Benzene 0.02 95 lb/1,000 gallons condensate throughput Toluene 0.02 95 lb/1,000 gallons condensate throughput Ethylbenzene 0.01 95 lb/1,000 gallons condensate throughput Xylene 0.01 95 lb/1,000 gallons condensate throughput n -Hexane 0.12 95 lb/1,000 gallons condensate throughput 224 TMP 0.01 95 lb/1,000 gallons condensate throughput 31 of 45 - - K:\PA\2018\ 18WE0279.CP1.xlsm Condensate Tank Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements scarce is In the Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? • 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VDC emissions greaterthan 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.31? 'Source requires a permit NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this Individual source greaterthan 1 TPY (Regulation 3, Part A, Section ll.D.1.a)? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section ll.D.2)? You have indicated that source is le the Attainment Area Colorado Regulation 7, Section XII.C-F 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at an oil and gas exploration and production operation', natural gas compressor station or natural gas drip station? 3. Is this storage tank located upstream of a natural gas processing plant? [Storage Tank le not subject to Regulation 7, Section )(11.C -F Section Xll.C.1 —General Requirements for Air Pollution Control Equipment— Prevention of leakage Section XII.C.2—Emission Estimation Procedures Section 011.0 —Emissions Control Requirements Section XII.E— Monitoring . Section XII.F— Recordkeeping and Reporting Colorado Regulation 7, Section 011.6 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located ate natural gas processing plant? 3. Does this storage tank exhibit "Flash" (e.g. storing nen-stabilized liquids) emissions end have unCdntrellad actual emisslehs greater than If equal t8 2 tansper year VOc? 'Storage tank is not subject to Regulation 7, Section X11.6 Section 011.8,2 - Emissions Control Requirements Section 011.C.1 —General Requirements for Air Pollution Control Equipment —Prevention of Leakage Section XII.C.2 — Emission Estimation Procedures Colorado Regulation 7, Section XVII 1. Is this tank located et a transmission/storage facility? 2. Is this condensate storage tank' located at an oil and gas exploration and production operation , well production facility', natural gas compressor station' or natural gas processing plant? 3. Is this condensate storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions" of this storage tank equal to or greater than 6 tons per yearVOC? St rage tank is. subject to Regulation 7, Section XVII, 8, 01 0 C.3 Section XVII.B— General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1 - Emissions Control and Monitoring Provisions Settles XVII.C.3 - Recotdkeeping Requirements 5. Does the condensate storage tank contain only "stabilized" liquids? - Ifuioragntank -€t.kkhlssifio)tuula6i9sin 5iNitien.KVUL&s-- _ Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the Individual storage vessel capacity greater than or equal to 75 cubic meters (m') ("472 BBLs]7 2. Does the storage vessel meet the fallowing exemption In 60.1116(d)(4)? a, Does the vessel has a design capacity less than or equal to 1,589.874 m' (-10,000 BBL] used for petroleum' or condensate stored, processed, or treated prior to custody transfer' as defined in 60.11167 3. Was this condensate storage tank constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23, 1984? 4. Does the tank meet the definition of"storage vessel"' in 50.111k? .n 5. Does the storage vessel store a "volatile organic liquid (V0L)"'as defined In 60.1116? 6. Does the storage vessel meet any one of the following additional exemptions: a, Is the storage vessel a pressure vessel designed to operate In excess of 204.9 kPe ["29.7 psi] and without emissions to the atmosphere (60.110b(d)(2))?; or b. The design capacity is greaterthan or equal to 151 m' ["950 BBL] and stores a liquid with a maximum true vapor pressure' less than 3.5 kPe (60.110h(b))?; or c. The design capacity is greaterthan or equal to 751155 [-472 BBL] but less than 151 m' (-950 8B11 and stores a liquid with a maximum true vapor pressure' less than 15.0 kea(60.110b(b))? ' ISthrage Tank is not subjeot to NSPS Kb Subpart A, General Provisions §60.11213- Emissions Control Standards for VOC §60.1136 - Testing and Procedures §60.1156 - Reporting and Recordkeeping Requirements 460.1166. Monitoring of Operations No Yes MOM No No No Yes WAN 40 CFR, Part 60 Subpart 0000 Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1, IS thl5 condensate storagg ogsigl IaGatgd eta faglllty in the onshore oil and natural Ras production 5ggmgnt, natural gas Rructs5Ing segment or natural gas trans,m„isslon and stntogo segment of the Industry? 2. Was this condensate storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 58, 20157 3. Are potential VOC emissions' from the Individual storage vessel greater than or equal to 6 tons per Year? 4. Does this condensate storage vessel meet the definition of "storage vessel"' per 60.5430? 5. Is the storage vessel subject to and controlled In accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart HH7 ISturoge Tank' in not subject no NSPS 0000 or NSPS 00000 (based on emissions c 6tpy VOC GOY come)) Subpart A, General Provisions per §60.0425 Table 3 460.5395 - Emissions Control Standards for VOC §60.5413 - Testing and Procedures 460.5395(g) - Notification, Reporting and Recordkeeping Requirements 460.5416(c) - Cover and Closed Vent System Monitoring Requirements §60.5417 -Control Device Monitoring Requirements [Note: If a storage vessel is previously determined to he subject to NSPS 0000 due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS 0000 per 60.5365(e)(2) even if potential VOC emissions drop below 6 tons per year] 40 CFR, Part 63, Subpart MACT HH, Oil and Gas Production Facilities 1, Is the storage tank located at an oil and natural gas production,facility that meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids' (53.760(0)(2)); OR b. A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end users (63.760(a)(3()? 2. Is the tank locatedat a facility that is major' for HAPs7 3. Does the tank meet the definition of"storage vessel"' in 63.7617 4. Does' the tank meet the definition of"storage vessel with the potential for flash emissions"' per 63.7617 5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or Subpart 00007 'Storagelank is not subject to MALT lilt Subpart A, General provisions per §63.764 (a) Table 2 §63,766. Emissions Control Standards 463.773 - Monitoring -§63.774-Recordkeeping §63.775 - Reporting RACT Review RACT review is required If Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, Its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any otherlegally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the,Ianguage of the statute or regulation will control. The use of non -mandatory language such as "recommend," "may," "should," and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are Intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in end of itself Yes Separator Venting Emissions Inventory Section 01- Administrative Information 'Facility AIRs ID: County 9FA9.'.: Plant 013:. Point Section 02- Equipment Description Details Detailed. Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency Limited Process Parameter Gas meter Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Separator Actual Throughput = Requested Permit limit Throughput = Potential to Emit. (PTE) Throughput = Process Control (Recycling) Equipped with a VRU Is VRU process equipment: '. Uncontrolled and controlledemissions used to establish requested permit limits are based only on when the VRU is bypassed (i.e. wastegas volume that is routed to the flare) Secondary Emissions - Combustion Device(s) for Air Pollution Control MMscf per year is MMscf per year 7.015 MMscf per year Determining Requested Limits Max rate from LP is 8.50 Mscf/hr Max rate from VRT is 5.53 Mscf/hr Total Requested 8501 scfh 5530 scfh 4.25 2.765 7.015 MMSCF/yr MMSCF/yr MMSCF/yr Separator Gas Heating Value:. Volume of waste gas emitted per BBL o liquids throughput: Section 04- Emissions Factors & Methodologies Description _.. .. ............ __. The'lew pressure separators arell'ocated downstream of inlet (high pressor comply with acombined.lied LP and WEEgas, theywdl consersatfeely us rare Ofthis waste gas streem are derived from the'YRT gas streams. An extended gas analys VRT en 4/20/18. Thesample composition wih:the:higher VOC:contentwas,consenrattire€y us Displacement Equation Ex=Q* MW*Xx/C Weight H2S N2 CO2 methane ethane propane isobutane n -butane isopentane n -pentane cyclopentane n -Hexane cyclohexane Other hexanes heptanes methylcyclohexane 224-TMP Benzene Toluene Ethylhenzene Xylenes CS* Heavies .4 :11.57 0:47 1:6 1:027 005'. 036 Total VOC Wt 100.05 85.78 Ib/Ib-mul par+recoverytower (VRT);is lecated dowgstream of (S.e. fecei"ves lequid ae VOTgas stream to ddeveloplimitsandcalcufateemissions__Therefore iferrxed du a sa'mpteA celletted'4/20/10 frot»..the LC22. A VRT. Anlentend late emissiaesfom thisenission stream, the LC22-BART:. ore separate'sySiege Noble tulecutar weight (MW (, and` also collected front�the'1C2: 34 of 45 K:\PA\2018\18 W E0279.CP1.xlsm Separator Venting Emissions Inventory Emission Factors Separator Venting Pollutant Uncontrolled Controlled (lb/MMscf) (lb/MMscf) (Gas Throughput) (Gas Throughput) VOC 106899.3163 5344.9655 Benzene Toluene 330.7346 202.8772 60.5641 94.5846 16.5367 10.1439 3.0282 4.7292. Ethylbenzene Xylene.. n -Hexane 224 TMP 2370.8463 118.5423 30.1574 1.5079 Emission Factor Source Emission Factor Source Pollutant Primary Control Device Uncontrolled Uncontrolled (Ib/MMBtu) lb/MMscf (Waste Heat Combusted)(Gas Throughput) PM10 PM2.5 002 19.730 19.730 1.558 SOx NO5 CO 180.064 820.880 Section 05 Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled. • (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Umits Uncontrolled Controlled (tons/year) (tons/year) PM10 0.07 0.00 0.00 0.07 0.07 PM2.5 0.07 0.00 0.00 0.07 0.07 5Ox - 0.01 0.00 0.00 0.01 0.01 NOx 0.63 , 0.00 0.00 0.64 0.64 VOC 374.95 0.00 0.00 374.95 18.75 CO 2.88 - 0.00 0.00 2.94 2.94 - Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ibs/year) (Ibs/year) fibs/year) (Ibs/year) (Ibs/year) Benzene 2320 0 0 2320 116 Toluene 1423 0 0 1423 71 Ethylhenzene • 425 0 0 425 21 Xylene 664' 0 0 664 33 n -Hexane 16631 0 0 ' 16631 832 224 TMP 212 0 0 212 11 Section 06- Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Section XVII.B, G Regulation 7, Section XVII.B.2.e (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Using Gas Throughput to Monitor Compliance Source requires a permit Source is subject to Regulation7, Section XVII-8.2, G The control device for this separator is riot subject to Regulation 7, Section XVil.B.2.e •additional 365 MMBTU/yr @ 0.068 Ib/mmbtu for pilot *additional 365 MMBTU/yr @ 0.31 Ib/mmbtu for pilot Does the company use sitespecific emission factors based on a gas sample to estimate emissions? This sample should represent the gas outlet of the equipment covered under this AIRs ID, and should have been collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to 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 "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. -A "Periodic Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application on an annual basis. Will the operator have a meter installed and operational upon startup of this point? - Yes If no, the permit will contain a condition that requires the operator t0 calculate gas throughput using the liquid throughput until the meter is installed and operational (not to exceed 180 days). This condition will use the "Volume of waste gas emitted per BBL of liquids throughput" (scf/bbl) value in section 03.. Does the company request a control device efficiency greaterthan 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling 35 of 45 K:\PA\2018\ 18WE0279.CP1.xlsm Separator Venting Emissions Inventory Section 08 - Technical Analysis Notes A's noted lathe-seelion-44hholde has requested tecenserva₹lve#y:es₹imate emiseonsfroni:this point using the nidd'eted gas corn he Vti.T:g stream:eorstal pesl₹ion frr+m the VRT. Some ₹so heav;eehydsacar gas results in n. higher ikrVflG`pec:tulMscf ofwaste�gas rquted-id:ehrflare� €urtbermora,.applicaat submitted VRT'sampfesfromboth tte,€C22 Aeean©de VRF and ifie I.CZ2-6 eedndde VRTand� usedtl£n ComlA5sitid content and MW (i,e:.the heavier'" ges)toestunatecomposition;i o l ofh Pomt013a0dPPant 02& - -:n `'.�` *Permit will occlude a cumbmedlimitfor Point013 and a25and. eompliantewikl:he demoottrdteed usingthe_camtrinad gas threo rput(ie Lilgasfaflare+VRT gasaoflazs as measuredbxflow meters otteacft stream:end:F0readt eeo and the emissionfactorscalculated"usingthe:VOTges cnmpositioro. This is accepta€ole setce dieeeorce w31 use emissionfackrrs based:an the mnst'corroervalave [ix: higl waight%Vocbs r060r based-uri�s)te-epeafle A Econode LP'separator; LC22-A,Ecnhode €PSeparatoF, LC'22-R Econode VRT, and; f:C27,rB Ewnede uhf be nute4-thatahe source is uoesg the veT gas.campasb10oe to estresote emSssirsnsfrcaet tkte estorety of Edee'missfanstream, tehsch a#sa Inc-ta'fesi.Psegaratergas. Tbeootnpositidn o€the LP separator 0as, as 0otedals ed to heye-significantly fess VOG on a mass:basis. Tfierefbre, the compteance method usfngthe V,R3`sainpnsitian4s mopecledmo preducearoesetvathteresult{i a hglterh01000an tfidiat amore refrned.oalceYatioOo using r end YATtiarin}jds#4San; m9ght produee):'herefi5te;'the appktdattwlll, nct.fke.requiredtncarry ou# any addiutOmat sampling bn thr tPjVRT' As discusseda0ove, the.lim tsw0l becambbted for 013and 026;.The resulting limits aresummed hetweenthetwn points andline asfoifaws: NaturaftiasCambuated duringVRU dmmtrrne .lLZ6MMsdJyr=-' ... .. N09:1.1'tpy is VOCi.31.5tpq, CO: S.009y :... Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # Process # SCC Code 013 01 3-10-001-60 Flares ition of:the:NfsT:,,_I Uncontrolled Emissions Pollutant Factor Control % Units PM10 19.73 0 Ib/MMSCF PM2.5 19.73 0 Ib/MMSCF S0x 1.56 0 Ib/MMSCF N0x 180.06 0 Ih/MMSCF V0C 106899.31 95 Ib/MMSCF CO 820.88 0 Ib/MMSCF Benzene - 330.73 95 lb/MMSCF Toluene 202.88 95 lb/MMSCF Ethylbenzene 60.56 95 Ib/MMSCF Xylene 94.58 95 Ib/MMSCF n -Hexane 2370.85 95 Ib/MMSCF 224 TMP 30.16 95 Ib/MMSCF 36 of 45 K:\PA\2018\ 18WE0279.CP1.xlsm Separator Venting Regulatory Analysis Worksheet aaisA_.adolleglatlon 3 Parts and R - OPEN and Permit Requlremen Source is in the Aftainrnynt Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from the individual source greater than 2TPy(Regulation 3, Part A, Section ll.D.1.a)? • 2. Are total facility uncontrolled VOC emissions greater than 5TPY, Non greater than. 1OTPY or CO emissions greater than SOTPY (Regulation3, Part B, Section 11.0.3)? (Source requires r permit NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Are total facility uncontrolled VOC emissions from the greater than 2TPY, NOx greater than 5 TPY or CO emissions greater than 5 TN (Regulation 3, Part B, Section ll.D.2)? too have indicated that sourer is in the Attainment Ace r Colorado Regulation 7, Section )(VII 1. Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014? (Source is subiactnc Regulation 7, SaMeon KVlE.82, G Section XV11.B.2—General Provisions for Air Pollution Control Equipment and Preventlan of Emissions Section 0011,0- Emissions Control AltOtdatitie Emlailace Cont.! (OPtiut3132etlOR) Is this separator controlled by a back-up or alternate combustion device (I.e., not the primary control device) that is not enclosed? I The control device for this Separator is not subject to Regulation 7, Section XVa.11.2.e Section XVll.a.2.e—Alternative emissions control equipment Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Arc Act, ids implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis It contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law) regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the languageof the Clean Air Act„ its implementing regulations, and Air tluelity Control Commission regulations, the language of the statute or regulation wit control. The use of non -mandatory language such as "recommend,""may""should,"and "can,"is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. keirbV k0..&41 Source Requires an APES. Go to the new quertion Source Requires a permit The control device for this separator is not subject to Regulation 7, Section XVII.B.2.e Separator Venting Emissions Inventory Section 01- Administrative Information Facility AIRs ID: County Plant Point Section 02 - Equipment Description Details flaring 'of.gas from:two (2(Tow-pressure'ueparatomand one (1(:vapor mow time, Pe milt Ras are haiedion SOU hours per year ofVRU downtime. Detailed Emissions Unit Description: Enclosed plane:':;:_ Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter Gas meter Section 03 - Processing Rate Information for Emissions Estimates. Primary Emissions - Separator Actual Throughput Requested Permit Limit Throughput = Potential to Emit (PEE) Throughput = Process Control (Recycling). Equipped with a VRU: Is VRU process equipment: MMscf per year 4,140MMscf per year 4.740 MMscf per year daringvapor Determining Requested Limits Max rate from LP is 6.19'Mscf/hr 6190Iscfh 3290 scfh Max rate from VRT is 3.29 Mscf/hr 3.095 1.645 MMSCF/yr MMSCF/yr Total Requested 4.74 MMSCF/yr Uncontrolled and controlled emissions used to establish requested permit limits are based only on when the VRU is bypassed (i.e. waste gas volume that is routed to the flare) Secondary Emissions - Combustion Device(s) for Air Pollution Control Separator Gas Heating Value: :2648 Btu/scf Volume of waste gas emitted per BBL of liquids throughput: cf/bbl Section 04 - Emissions Factors & Methodologies Description The low pressure separators are located downstream at inlet (high pressure'separatorsrand the vapor resovery,tower (*FiTy.iS Located downstream of (i.e. receives Squidss frpm(the tow press - mmplywit6a combittediim-r. forL:PandVRTgas, tlieywi0 mrisenratively trsethe composition of the VPTgao stream to develop !Milts snd.calculafe ettriisions Therefore, the massfractwns,-mdle rate of this Waste gas stream are derivedfrom they/Rrgas streatn-An extended gas miaiysiswas performed on a sanrpiecollected 4/20/ill trom the1C22.-A VR'f An=extended gas anaiyddu ighealsocal 'VRT ono/20/10. The sample compositionwiththe higher VOC corstentwas conseroatively used to estimate emissions franrthis emlesienotreatrb the tcoBVRT; - Displacement Equation Ex=Q*MW. Xx/C MW 47.23 Weight % H2S N2 CO2 methane ethane 75: 0;77 10:49 propane isobutane n -butane isopentane n -pentane cyclopentane n -Hexane cyclohexane Other hexanes hoptunes methylcyclohexane 224-TMP Benzene Toluene Ethylbenzene Xylenes C8+ Heavies Qi 0.02' 0.27: . -.. RIGS' 0[Oa 4S& Total VOC Wt % 100.05 85.78 Iti/Iti-mol Fiobl will f);ondvent.' he CC22-B K:\PA\2018\18 \18WE0279 Separator Venting Emissions Inventory Section 05 - Emissions Inventory Emission Factors Pollutant Separator Venting Uncontrolled Controlled (Ib/MMscf) (Ib/MMecf) (Gas Throughput) VOC - 106899.310 Benzene 330.7346 Toluene' - 202.877 Ethylbenzene 60.5641 Xylene 94.5846 n -Hexane 2370.8463 224 TMP 30.1574 (GastThroughpu 5344.965 6.5367 0.1439 3.0282 4729 118.542 1.5079' Primary Control. Device Uncontrolled - Uncontrolled Pollutant (Ib/MMBtu) (Waste Heat Combusted) Emission Factor Source Ib/MMscf Emission Factor Source (Gas Throughput) 19.730' 180.064 820.880 Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions. Uncontrolled Controlled (tons/year) (tans/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) PM10 0.05 0.00 0.00 0.05 0,05 PM2.5 0.05 0.00 0.00 0.05 0.05 Sox - 0.00 0.00 0.00 0.00 0.00 NOx 0.43 0.00 0.00 0.44 0.44 VOC 253.35 0.00 0.00 253.35 12.67 CO _ 1.95 0.00 - 0.00 2.00 2.00 . Potential to Emit Actual Emissions. Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (Ibs/year) (Ibs/year)' (Ibs/year) (Ibs/year) Benzene 1568 0 0 0560 70 Toluene 962 0 0 962 -48 Ethylbenzene 287 0 0 287 14 Xylene 448 0 0 448- 22 n -Hexane 11238 0 0 11238 562 224 TMP 143 0 0 143 7 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Section XVII.B, Regulation 7, Section XVII.B.T.e Source requires a permit Source is subject to Regulation 7, Section XVII.B.2, G The control device for this separator is not subject to Regulation 7, Section XVII.B.2.e *additional 365 MMBTU/yr @ 0.068 lb/mmbtu for pilot *additional 365 MMBTU/yr @ 0.31 lb/mmbtu for pilot (See regulatory applicability worksheet for detailed analysis) ' Section 07- Initial and Periodic Sampling and Testing Requirements Using Gas Throughput to Monitor Compliance Does the company usesite specific emission factors based on a gas sample to estimate emissions? c� This sample should represent the gas outlet of the equipment covered under this AIRS ID, and should have been collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it maybe appropriate to use an older site -specific sample. • -If no, the permit will contain an"Initial Testing Requirement" to collect a site -specific pd sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equalto the emissions factors established with this application. Are facility -wide permitted emissions of VOC greater than or equal to 90 tons per year? If yes, the permit will contain: - -An "Initial Testing Requirement" to collecta site-specificgas sample from the equipmentbeing permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. -A "Periodic Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application on an annual basis. Will the operator have a meter installed and operational upon startup of this point? Yes If no, the permit will contain a condition that requires the operator to calculate gas throughput using the Squid throughput until the meter is installed and operational (not to exceed 180 days). This condition will use the "Volume of waste gas emitted per BBL of liquids throughput" (scf/bbl) value in section 03, Does the company request a control device efficiency greater than 95% for a flare or combustion. device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling 1.13 4.89 39 of 45 K:\PA\2018\ 18WE0279.CP1.xlsm Separator Venting Emissions Inventory Section Oa -Technical tki24 Fermfrotill mcissde a carnbaned limit forf!aint113 and 036 and comtsliam 'and €he eml lion beotors coin l t dtrsltg ih Itolcas cbmpasltfon_ "5==is A Esonode tpseparator, LC22 AEpmrrodebP Seperotcnsl122 BEconodnV ltshbuid be:noted thotth ;source �s asing Eh VAT gas < mgosrti expeoxd€o have significantly less VOCo�n am ss basis. Therefore enmpos'ttisae and VRT<o posiYon, might produce}. The o1nre,the Eetlulred do dernonstrefe that the VOC Contaotlsat bosstgonserva diecassedabova, the roodtssserip be combined"Per 033. ₹arot Gas Coiobented durie�gPRl€dowrttime:31J xa.lapy „ , Section 09 Inventory SC[ Coding and Eerissi AIRS Paint # 026 atones' 01 etiies Econot A to estimate efloionsR the.compliance method u applicant wilt not ho regyi nice. The initial saniple.will SCC Code 3-10-001-60 Flares ons Factors _a conservative P. N. gas s'nret t it Is expected? Uncontrolled Emissions Pollutant Factor Cont000'1% rol % Units PM10 19.73 0 Ib(MMSCF PM2.5 10.73 0 'Ib/MMSCF Sox 1.56 0 ib/MMSCF NO. 180.06 0 ib/MMSCF VOC 106899.31 95 Ib/MMSCF CO 82488 0 Ib(MMSCF Benzene 330.73 95 I6/I+AMSCF Toluene 202.88.- 95 Ib/MMSCF Ethylhenzene 60.16 95 ib/MMSCF Xylene 94.58 95 Ib/MMSCF n -Hexane 2370.01 95 Ib/MMSCF 224 IMP 30.15 95 Ib/MMSCF 40 of 45 K:\PA\2018\18 W E0279.CP1.xlsm Separator Venting Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements Source is in the Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this Individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? 'Source requires a permit NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section 11.0.2)? 'You have indicated that source is in the Attainment Area Colorado Regulation 7, Section XVII 1. Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014? 'Source is subject to Regulation 7, Section XVIl.B.2, G Section XVII.B,2 —General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.G - Emissions Control Alternbtive_E a. Is this separator controlled by a back-up or alternate combustion device (i.e., not the primary control device) that is not enclosed? 'The control device for this separator is not subject to Regulation 7, Section XVIt.8.2.e Section XVII.B.2.e —Alternative emissions control equipment Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and Is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as °recommend," "may," "should," and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and 'required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. 1.1 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION FACILITY EMISSION SUMMARY Company Name County AIRS ID Plant AIRS ID Facility Name Noble Energy Inc 123 SFAS LC22 - A&B Econode T9N-R59W-S22 LO1 History File Edit Date Ozone Status 12/12/2018 Attainment EMISSIONS - Uncontrolled (tons per year EMISSIONS With Controls (tons per year POINT AIRS ID PERMIT Description PM10 PM2.5 H2S S02 NOx VOC Fug VOC CO Total HAPs PM1D PM2.5 H2S So2 NOx VOC Fug VOC CO Total HAPs REMARKS Previous FACILITY TOTAL New Facility - No Previous Total Previous Permitted Facility total 001 18WE0279 Caterpillar G3306NA s: R6S04244 0.1 0.1 18.9 1.0 18.9 0.4 0.1 0.1 0.7 1.0 2.8 0.2 NewCP 002 18WE0279 Caterpillar G3306NA s: R6S04206 0.1 0.1 18.9 1.0 18.9 0.4 0.1 0.1 0.7 1.0 2.8 0.2 NewCP 4222. ss3;k 1752 `! :, � .F:�:":4:.^..2f^..:3,q C'.uo . c- .0 - O'3:.:2 II):,,•x k i.1'.1 L. ;, EEP v ,1'.tC ::C0!v:? 005 18WE0279 GM 5.7L s: 10CHMM503090035 0.1 0.1 12.4 0.6 9.8 0.1 0.1 0.1 0.9 0.6 1.8 0.1 NewCP . 006 18WE0279 GM 5.7L s: 10CHMM503060080 0.1 0.1 12.4 0:6 9.8 0.1 0.1 0.1 D.9 0.6 1.8 0.1 New CP 007 18WE0279 GM 5.7L s: 10CHMM50205001 . 0.1 0.1 12.4 0.6 9.8 0.1 0.1 0.1 0.9 0.6 1.8 0.1 New CP OMCP'CS.'<. 1 ,..ii'i;!'tll!'I:x KT.A16:c'a.. 222,2 01f : C9rl0 it sti0Y: roceived 121611 /i 009 18WE0279 Caterpillar G3516J s: N6W00224 0.5 0.5 9.3 8.3 32.4 6.6 0.5 0.5 9.3 9.3 13.3 3.7 New GP02 010 18WE0279 Produced WaterTankA 0.200 0.200 2.0 145.40 9.3 16.1 0.20D 0.200 2.0 7.30 9.3 0.8 NewCP 011 18WE0279 LoadoutA 0.0 11.94 0.1 0.2 0.0 0.60 0.1 0.0 NewCP 012 18WE0279 Condensate Tanks A 0.2 210.50 1.0 3.2 0.2 10.5 1.0 0.2 Updated but need to have them revise talcs or agree to mine 013 18WE0279 LPNRT Separator Venting A 0.7 374.94 2.9 10.8 0.7 18.8 2.9 0.5 New CP .!14 k .. 4 12 2 7.2 0.4Cal ... F.. 4422^,.. .. .;.. .-.-;4 • 0.0 . 0.0 ; lb (1'.? u'v";,'t !,, r^' r. , r. ,,l , :1 ! 0.0 0.0 ';: 3.i:.: > C . , 9118 017 18WE0279 RICE (P6S00892) 0.106 0.106 18.9 0.98 18.9 0.4 • 0.106 0.106 0.7 1.0 2,8 0.2 NewCP 018 18WE0279 RICE (R6S03102) 0.106 0.106 18.9 0.98 18.8 0.4 0.106 0.106 0.7 1.0 2.8 0.2 NewCP 019 180/00.0 Ci.illiiitinS I<T0 1900' (37270(/45) C:ance€lation receiwd 2/0/10 020 18WE0279 Caterpillar G35163 (N6W00251) 0.500 0.500 9.3 9.33 32.4 6.6 0.500 0.500 9.3 9.3 13.3 3.7 021 18WED279 RICE (10CHMM503060026) 0.070 0.070 12.4 0.62 9.8 0.1 0.100 0.100 0.9 0.6 1.8 0.1 NewCP 022 18WE0279 RICE (10CHMM410150017) 0.070 0.070 12.4 0.62 9.8 0.1 0.070 0.070 0.9 0.6 1.8 0.1 New CP 023 18WE0279 Produced water Tank B 0.100 0.10D 1.4 96.60 6.2 10.7 0.070 0.070 1.4 4.8 6.2 0.5 New CP 024 18WE0279 Loadout B 0.0 7.69 0.0 0,2 0.0 0.4 0.0 0.0 025 18WE0279 . Condensate Tanks B 0.1 144.28 0.6 5.0 0.1 7.2 0.6 0.3 026 18WE0279 VRT/LP Venting B 0.5 253.29 2.0 7.3 0.5 12.7 2.0 0.4 XA Fugitives (A) 1.3 1.3 Updated from Form102 rec'd 7/9/18 XA Fugitives (B) :1.2 1.2 Updated from Form102 rec'd 7/9/18 XA Separator Heaters (16) 1.8 0.1 1.5 1.8 0.1 1.5 Updated from Form102 rec'd 7/9/18 FACILITY TOTAL 2.1 2.1 0.0 0.0 163.4 • 1,537.1 2.5 214.7 76.2 2.1 2.1 0.0 0.0 32.6 88.0 2.5 70.4 11.8 VOC: Syn Minor (PSD and OP) NOx: Syn Minor (OP) CO: Syn Minor (OP) HAPS: Syn Minor HH: Syn Minor + no TEG dehy zjzZ: $yn Minor Emissions from all APEN reportable emissions points 2.1 2.1 0.0 0.0 30.8 87.9 0.0 68.9 11.4 Permitted Facility Total , 2.1 2.1 0.0 0.0 30.8 87.9 0.0' 68.9 11.4 Excludes units exempt from permits/APENs (A) Change in Permitted Emissions 2.1 2.1 0.0 0.0 30.8 . 87.9 0.0 68.9 Pubcom required based on new synthetic minor limits. Modeling not required based on project emissions Note 1 Total VOC Facility Emissions (point and fugitive) (A) Change in Total Permitted VOC emissions (point and fugitive) 90.5 Facility is NOT eligible for GP02 because > 90 tpy 87.9 Project emissions greater than 50 tpy Package containing 9 GRO2 applications was processed prior to aggregation of LC22A and LC228 econodes (Noble originally submitted the, applications under 2 separate facilities, however, they were found to meet the definition of a single source and were combined into a single AIRS ID. At that time, source no longer qualified for GP02 (facility -wide emissions VOC) and submitted revised application materials requesting -individual permits for the RICE engines. Natal CN Was received for 008 and 019 on 12/5/18 during analysis . Page 42 of 45 Printed 1/2/2019 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY - HAPs Company Name County AIRS ID Plant AIRS ID Facility Name Noble Energy Inc 123 9FA9 LC22 - A&B Econode T9N-R59W-S22 L01 Emissions - uncontrolled (Ibs per year POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane MeOH 224 TMP H2S TOTAL (tpy) Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 18WE0279 Caterpillar G3306NA s: R6S04244 756 31 29 17 34 0.4 002 18WE0279 Caterpillar G3306NA s: R6S04206 756 31 29 17 34 0.4 003 GP02 Doosan D8.1 L s: EEPOG402688 386 53 50 30 58 0.3 004 GP02 Doosan D8.1L s: EEPOG301928 386 53 50 30 58 0.3 005 18WE0279 GM 5.7L s: 10CHMM503090035 149 20 19 11 22 0.1 006 18WE0279 GM 5.7L s: 10CHMM503060080 149 20 19 11 22 0.1 007 18WE0279 GM 5.7L s: 10CHMM50205001 149 20 19 11 22 0.1 008 GP02 Cummins KTA19GC s: 37271010 0.0 009 18WE0279 Caterpillar G3516J s: N6W00224 11460 834 513 44 250 6.6 010 18WE0279 Produced Water Tank A 7769 24418 16.1 011 18WE0279 LoadoutA 62 53 7 19 310 36 0.2 012 18WE0279 Condensate Tanks A 809 693 107 270 4115 470 3.2 013 18WE0279 LPNRT Separator Venting A 2320 1423 425 664 16631 212 10.8 014 18WE0279 VRT Gas Venting A 1744 1596 262 668 9010 1086 7.2 015 18WE0279 RICE (EEPOG301912) 0.0 016 18WE0279 RICE (EEPOG301831) 0.0 017 18WE0279 RICE (R6S00892) 756 31 29 17 34 0.4 018 18WE0279 RICE (R6S03102) 756 31 29 17 34 0.4 019 18WE0279 Cummins KTA 19GC: (37270945) 0.0 020 18WE0279 Caterpillar G3516J (N6W00251) 11460 834 513 44 250 6.6 021 18WE0279 RICE (10CHMM503060026) 149 20 19 11 22 0.1 022 18WE0279 RICE (10CHMM410150017) 149 20 19 11 22 0.1 023 18WE0279 Produced water Tank B 5162 16223 10.7 024 18WE0279 Loadout B 56 37 33 19 284 33 0.2 025 18WE0279 Condensate Tanks B 1222 809 719 293 6241 732 5.0 026 18WE0279 VRT/LP Venting B 1568 962 287 448 11238 143 7.3 XA Fugitives (A) TOTAL (tpy) 13.7 1.0 0.7 10.5 2.8 0.9 1.2 44.2 0.4 1.4 0.0 0.0 76.8 43 18WE0279.CP1.xlsm 1/2/2019 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY- HAPs Company Name Noble Energy Inc County AIRS ID 123 Plant AIRS ID 9FA9 Facility Name LC22 - A&B Econode T9N-R59W-S22 L01 Emissions with controls (Ibs per year POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane McOH 224 TMP H2S TOTAL (tpy) Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 18WE0279 Caterpillar G3306NA s: R6S04244 308 31 29 17 34 0.2 002 18WE0279 Caterpillar G3306NA s: R6S04206 308 31 29 17 34 0.2 003 GP02 Doosan D8.1L s: EEPOG402688 386 53 50 30 58 0.3 004 GP02 Doosan D8.1L s: EEPOG301928 386 53 50 30 58 0.3 005 18WE0279 GM 5.7L s: 10CHMM503090035 149 20 19 11 22 0.1 006 18WE0279 GM 5.7L s: 10CHMM503060080 149 20 19 11 22 0.1 007 18WE0279 GM 5.7L s: 10CHMM50205001 149 20 19 11 22 0.1 008 GP02 Cummins KTAI9GC s: 37271010 0.0 009 18WE0279 Caterpillar G3516J s: N6W00224 5730 834 513 44 250 3.7 010 18WE0279 Produced Water Tank A 388 1221 0.8 011 18WE0279 Loadout A 3 3 0 1 16 2 0.0 012 18WE0279 Condensate Tanks A 40 35 5 14 206 24 0.2 013 18WE0279 LP/VRT Separator Venting A 116 71 21 33 832 11 0.5 014 18WE0279 VRT Gas Venting A 87 80 13 33 450 54 0.4 015 18WE0279 RICE (EEPOG301912) 0.0 016 18WE0279 RICE (EEPOG301831) 0.0 017 18WE0279 RICE (R6S00892) 308 31 29 17 34 0.2 018 18WE0279 RICE (R6S03102) 308 31 29 17 34 0.2 019 18WE0279 Cummins KTA 19GC: (37270945) 0.0 020 18WE0279 Caterpillar G3516J (N6W00251) 5730 834 513 44 250 3.7 021 18WE0279 RICE (10CHMM503060026) 149 20 19 11 22 0.1 022 18WE0279 RICE (10CHMM410150017) 149 20 19 11 22 0.1 023 18WE0279 Produced water Tank B 258 811 0.5 024 18WE0279 Loadout B 3 2 2 1 14 2 0.0 025 18WE0279 Condensate Tanks B 61 40 36 15 312 37 0.3 026 18WE0279 VRT/LP Venting B 78 48 14 22 562 7 0.4 XA Fugitives (A) 44 18WE0279.CP1.xlsm 1/2/2019 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY - HAPs Company Name Noble Energy Inc County AIRS ID 123 Plant AIRS ID 9FA9 Facility Name LC22 - A&B Econode T9N-R59W-S22 L01 TOTAL (tpy) 7.1 1.0 0.7 0.7 0.1 0.0 0.1 2.2 0.4 0.1 0.0 0.0 12.4 45 18WE0279.CP1.xlsm 1/2/2019 CONSTRUCTION PERMIT Permit number: Date issued: Issued to: 18WE0279 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: I Noble Energy, Inc. LC22-A Et B Econode 123/9FA9 NWNE SEC 22 T9N R59W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description ENG-R6SO4244 001 One (1) Caterpillar Model: G3306NA SN: R6504244, natural gas fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 145 HP. This emission unit is used for compression Non -selective catalytic reduction (NSCR) system and air -fuel ratio controller ENG-R6S04206 002 One (1) Caterpillar Model: G3306NA SN: R6504206, natural gas fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 145 HP. This emission unit is used for compression Non -selective catalytic reduction (NSCR) system and air -fuel ratio controller ENG- 10CHMM503090035 005 One (1) GM Model: 5.7L SN: 10CHMM503090035, natural gas fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 92 HP. This emission unit is used for compression. Non -selective catalytic reduction (NSCR) system and air -fuel ratio controller 'COLORADO Air Pollution Control Division Dewt ner:t of Public Envir6rarr,ent Page 1 of 25 ENG- 10CHMM503060080 006 One (1 j4. .7L SN 10CH V I I . 0080, natura gas fire., naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 92 HP. This emission unit is used for compression. " -sel- :.; catalytic reduction (NSCR) system and air -fuel ratio controller ENG- 10CHMM50205001 007 One (1) GM Model: 5.7L SN: 10CHMM50205001, natural gas fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 92 HP. This emission unit is used for compression. Non -selective catalytic reduction (NSCR) system and air -fuel ratio controller ENG-N6W00224 009 One (1) Caterpillar Model: G3516J SN: N6W00224, natural gas fired, turbocharged, 4SLB reciprocating internal combustion engine, site rated at 1,380 HP. This engine shall be equipped with a selective oxidation catalyst and air -fuel ratio control. This emission unit is used for gas compression. Oxidation catalyst and air -fuel ratio controller PW Tanks (LC22-A) 010 Four (4) 500 barrel fixed roof produced water storage vessels connected via liquid manifold. Tanks store produced water from LC22-A Econode wells. Enclosed Flare TLO (LC22-A) 011 Truck loadout of condensate from LC22- A Econode tanks by submerged fill. Enclosed Flare Condensate Tanks (LC22-A) 012 Twelve (12) 500 barrel fixed roof condensate storage vessels connected via liquid manifold. Tanks store condensate from LC22-A Econode wells Enclosed Flare VRT£tLP (LC22-A) 013 Flaring of gas from two (2) low-pressure separators and one (1) vapor recovery tower (VRT) during vapor recovery unit (VRU) compressor downtime. Enclosed Flare ENG-R6S00892 017 One (1) Caterpillar Model: G3306NA SN: R6500892, natural gas fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 145 HP. This emission unit is used for compression Non -selective catalytic reduction (NSCR) system and air -fuel ratio controller COLORADO Mr Polttttion Control Division Page 2 of 25 ENG-R6S3102 018 •One (1 t ' odel: ` r06N ' • R6S31 1 , na ural gas fire • , na urally aspirated, 4SRB reciprocating internal combustion engine, site rated at 145 HP. This emission unit is used for compression -sel_. catalytic reduction (NSCR) system and air -fuel ratio controller ENG-N6W00251 020 One (1) Caterpillar Model: G3516J SN: N6W00251, natural-gas fired, turbocharged, 4SLB reciprocating internal combustion engine, site rated at 1,380 HP. This engine shall be equipped with a selective oxidation catalyst and air -fuel ratio control. This emission unit is used for gas compression. Oxidation catalyst and air -fuel ratio controller ENG- 10CHMM503060026 021 One (1) GM Model: 5.7L SN: 10CHMM503060026, natural gas fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 92 HP. This emission unit is used for compression. Non -selective catalytic reduction (NSCR) system and air -fuel ratio controller ENG- 10CHMM410150017 022 One (1) GM Model: 5.7L SN: 10CHMM410150017, natural gas fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 92 HP. This emission unit is used for compression. Non -selective catalytic reduction (NSCR) system and air -fuel ratio controller PW Tanks (LC22-B) 023 Four (4) 500 barrel fixed roof produced water storage vessels connected via liquid manifold. Tanks store produced water from LC22-B Econode wells. Enclosed Flare TLO (LC22-B) 024 Truck loadout of condensate from LC22- B Econode tanks by submerged fill. Enclosed Flare Condensate Tanks (LC22-B) 025 Twelve (12) 500 barrel fixed roof condensate storage vessels connected via liquid manifold. Tanks store condensate from LC22-B Econode wells Enclosed Flare VRTaLP (LC22B) 026 Flaring of gas from two (2) low-pressure separators and one (1) vapor recovery tower (VRT) during vapor recovery unit (VRU) compressor downtime. Enclosed Flare Point 001, 002, 017, 018: These engines may be replaced with another engine in accordance with the temporary engine replacement provision or another Caterpillar 3306NA engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. ,COLORADO Air Pollution Control Division Depar,anem* Ysub C Hn eh,n Er.sornT2fIt Page 3 of 25 Point 005, 006, 007, 021, O22: These engin � may be laced ,'th a er en •" e in ac the temporary engine replacement pro ': • her e cordi permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Point 009, 020: These engines may be replaced with another engine in accordance with the temporary engine replacement provision or another Caterpillar G3516J engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II .A.4. ) Annual Limits: COLORADO Air Pollution Control Division 61S Page 4 of 25 Facility Equipment ID AIRS Point PM2.5 ons :� Yea missi NO, V0C CO ype ENG-R6S04244 001 --- 0.7 --- 2.8 Point. ENG-R6S04206 002 --- 0.7 --- 2.8 Point ENG- 10CHMM50309 0035 005 --- 0.9 --- 1.8 Point ENG- 10CHMM50306 0080 006 --- 0.9 --- 1.8 ENG- 10CHMM50205 001 007 --- 0.9 --- 1.8 ENG- N6W00224 009 --- 9.4 9.4 13.4 Point PW Tanks (LC22-A) 010 --- 2.0 7.3 9.3 Point TL0 (LC22-A) 011 --- --- 0.6 --- Point Condensate Tanks (LC22-A) 012 --- --- 10.6 --- Point VRT£tLP (LC22A) 013 --- 1.1 31.5 5.0 Point VRT&LP (LC22B) 026 Point ENG-R6S00892 017 --- 0.7 --- 2.8 Point ENG-R6S3102 018 --- 0.7 --- 2.8 Point ENG- N6W00251 020 --- 9.4 9.4 13.4 Point ENG- 10CHMM50306 0026 021 --- 0.9 --- 1.8 Point ENG- 10CHMM41015 0017 022 --- 0.9 --- 1.8 Point PW Tanks (LC22-B) 023 --- --- 4.9 6.2 Point TL0 (LC22-B) 024 --- --- 0.4 --- Point Condensate Tanks (LC22-B) 025 --- -- 7.2 --- Point COLORADO Air Pollution Centric' Division i Deparix!'4e 3 of Pu6?Ii_ 5ieu`h E n.tttrr er; Page 5 of 25 Note: See "Notes to Permit Holder" fo formatlo. " emi 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 indicated below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities are defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. (Reference: Regulation 3, Part C. II.E.) Total potential emissions from the facility, including all permitted emissions and potential to emit from all insignificant activities, shall be less than: • 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.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled ENG- R6SO4244 001 Non -selective catalytic reduction (NSCR) and air/fuel ratio controller NOx CO ' ENG- R6504206 002 Non -selective catalytic reduction (NSCR) and air/fuel ratio controller NOx, CO ENG- 10CHMM5030 90035 005 Non-selective catalytic reduction (NSCR) and air/fuel ratio controller NOx, CO ENG- 10CHMM5030 60080 006 Non-selective catalytic reduction (NSCR) and air/fuel ratio controller NOx, CO ENG- 10CHMM5020 5001 007 Non-selective catalytic reduction (NSCR) and air/fuel ratio controller NOx, CO ENG- N6W00224 009 Oxidation catalyst and air/fuel ratio controller CO, HCHO PW Tanks (LC22-A) 010 Enclosed Flare VOC and HAP TLO (LC22-A) 011 Enclosed Flare VOC and HAP COLORADO Air Pollution Control Division EY?iinirir:te're Page 6 of 25 Facility Equipment ID AIRS Point utant on ro "e. ._ �,..ntrol .�. Condensate Tanks (LC22- A) 012 Enclosed Flare VOC and HAP VRTFtLP (LC22A) 013 Emissions are routed. to an enclosed flare during Vapor Recovery Unit (VRU) downtime VOC and HAP ENG- R6S00892 017 Non -selective catalytic reduction (NSCR) and air/fuel ratio controller NOx, CO ENG-R653102 018 Non -selective catalytic reduction (NSCR) and air/fuel ratio controller NOx, CO ENG- N6W00251 020 Oxidation catalyst and air/fuel ratio controller CO, HCHO ENG- 10CHMM5030 60026 021 Non -selective catalytic reduction (NSCR) and air/fuel ratio controller NOx, CO ENG- 10CHMM4101 50017 022 Non-selective catalytic reduction (NSCR) and air/fuel ratio controller NOx, CO PW Tanks (LC22-B) 023 Enclosed Flare VOC and HAP TLO (LC22-B) 024 Enclosed Flare VOC and HAP Condensate Tanks (LC22- B) 025 Enclosed Flare VOC and HAP VRTELP (LC22B) 026 Emissions are routed to an enclosed flare during Vapor Recovery Unit (VRU) 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 ENG- R6S04244 001 Consumption of natural gas as fuel 10.96 MMscf ENG- R6SO4206 002 Consumption of natural gas as fuel 10.96 MMscf COLORADO Air Pollution Control Division =ftwx,v d.,;f Public t?eti':th b Efwirdetniel;t Page 7 of 25 Facility Equipment ID AIRS Point • Para er An Limi ENG- 10CHMM5030 90035 005 Consumption of natural gas as fuel 7.25 MMscf ENG- 10CHMM5030 60080 006 Consumption of natural gas as fuel 7.25 MMscf ENG- 10CHMM5020 5001 007 Consumption of natural gas as fuel 7.25 MMscf ENG- N6W00224 009 Consumption of natural gas as fuel 99.81 MMscf PW Tanks (LC22-A) 010 Produced Water Throughput 1,109,907 barrels TL0 (LC22-A) 011 Condensate Loaded 170,765 barrels Condensate Tanks (LC22- A) 012 Condensate Throughput 1,800,000 barrels VRTaLP (LC22A) 013 Natural gas combusted during VRU downtime 11.76 MMscf VRTEtLP (LC22B) 026 ENG- R6S00892 017 Consumption of natural gas as fuel 10.96 MMscf ENG-R653102 018 Consumption of natural gas as fuel 10.96 MMscf ENG- N6W00251 020 Consumption of natural gas as fuel 99.81 MMscf ENG- 10CHMM5030 60026 021 Consumption of natural gas as fuel 7.25 MMscf ENG- 10CHMM4101 50017 022 Consumption of natural gas as fuel 7.25 MMscf PW Tanks (LC22-B) 023 Produced Water Throughput 737,400 barrels TL0 (LC22-B) 024 Condensate Loaded 110,000 barrels Condensate Tanks (LC22- B) 025 Condensate Throughput 1,200,000 barrels 'COLORADO Air Pollution Control Division Heat 1 lS En irov ef:t. Page 8 of 25 Compliance with the annual through •; limlts s : }' be d j rmm •n a r• ng twel total. By the end of each month -monts csed 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. Point 001, 002, 005, 006, 007, 009, 017, 018, 020, 021, 022: Fuel consumption shall be measured by one of the following methods: individual engine fuel meter; facility -wide fuel meter attributed to fuel consumption rating and hours of operation; or manufacturer -provided fuel consumption rate. 11. Point 011, 024: Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation Number 3, Part B, III.E) 12. Point 013, 026: The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from the LP separators and Vapor Recovery Towers (VRT) to the Enclosed Flares using flow meters. 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. Compliance with the process limits shall be demonstrated based on the sum of the metered volume for Point 013 and the metered volume for Point 026. STATE AND FEDERAL REGULATORY REQUIREMENTS 13. Point 001, 002, 005, 006, 007, 009, 010, 012, 013, 017, 018, 020, 021, 022, 023, 025, 026: 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) 14. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 15. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. Et 4.) 16. Point 010, 012, 013, 023, 025, 026: The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2. General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. This flare must be equipped with an operational auto -igniter upon installation of the combustion device. 17. Point 010, 012, 023, 025: The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons except where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. 18. Point 010, 012, 023, 025: The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Section XVII.C.2. COLORADO Air Pollution Control Division £^x ^t of Public E ea, n 6 enviror;r:w :t Page 9 of 25 19. Point 011, 024: All hydrocarbon liq loadm �y=ratio v reg ss of e, shal operated and maintained so as :��,srsz�.�, £ eaka la � = corn atmosphere to the maximum extent practicable. 20. Point 011, 024: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2): • The owner or operator shall inspect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. • All compartment hatches at the facility (including thief hatches) shall be dosed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. • Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. • Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. • Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. 21. Point 011, 024: For this controlled loading operation, the owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2): • Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. • Include devices to prevent the release of vapor from vapor recovery hoses not in use. • Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. • Operate all recovery and disposal equipment at a back -pressure less than the pressure relief valve setting of transport vehicles. 22. Point 013, 026: The separators covered by this permit is subject to Regulation 7, Section XVII.G. (State Only). On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the date of first production by air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. OPERATING Et MAINTENANCE REQUIREMENTS 23. Point 001, 002, 005, 006, 007, 009, 010, 011, 012, 013, 017, 018, 020, 021, 022, 023, 024, 025, 026: Upon startup of these points, the owner or operator shall follow the mast 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 COLORADO Air Pollution Control Division S tsivo9^.f- t if Z?ubfr Neu'." 6 F_::-rU lrr l Page 10 of 25 24. Point 009, 020: A source initial co ;'ante tee "hall • Fond -d on ch emis measure the emission rate(s) for t isted nstr with the emission limits in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. 25. Point 010, 012, 013, 023, 025, 026: 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 26. Point 001, 002, 005, 006, 007, 009, 017, 018, 020, 021, 022: 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 27. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or 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 COLORADO Air Pollution Control Division rtrv_rl,y fk bt Hetahh 6 E.^i°irorr er;t Page 11 of 25 • No later than 30 days before • Within 14 calendar days o 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. 28. The requirements of Colorado Regulation No. 3, Part D shall apply at such time that any stationary source or modification becomes a major stationary source or major modification solely by virtue of a relaxation in any enforceable limitation that was established after August 7, 1980, on the capacity of the source or modification to otherwise emit a pollutant such as a restriction on hours of operation (Reference: Regulation Number 3, Part D, VI.B.4). GENERAL TERMS AND CONDITIONS 29. 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. 30. 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. 31. 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. 32. 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. 33. 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. 34. 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 wilt terminate. 35. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal COLORADO Air Pollution Control Division -- 2U T .`^M.'✓';C ;Jf ufYPi� b1C'Ca .^.. s ivi erie t Page 12 of 25 enforcement actions under Section penalties), -122.1 (criminal penal By: Bradley Eades Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Noble Energy, Inc. Synthetic Minor facility -wide permit OLORADO Air Pollution Control Division fyuh4t. Flee€ 3t v G':,uaril=tez:t Page 13 of 25 Notes to Permit Holder at the time of this 1) The permit holder is required to pay fees or e processing °me"` or t'"is permi' ` An invoice '"or ese 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 (lb/yr) Controlled Emissions (Ib/yr) ENG- R6S04244 001 Formaldehyde 50000 756 308 Acetaldehyde 75070 31 31 Acrolein 107028 29 29 Methanol 67561 34 34 ENG- R6504206 002 Formaldehyde 50000 756 308 Acetaldehyde 75070 31 31 Acrolein 107028. 29 29 Methanol 67561 34 34 ENG- 10CHMM5030 90035 005 Formaldehyde 50000 149 149 Acetaldehyde 75070 20 20 Acrolein 107028 19 19 Methanol 67561 22 22 ENG- 10CHMM5030 60080 006 Formaldehyde 50000 149 149 Acetaldehyde _ 75070 20 20 Acrolein 107028 19 19 Methanol 67561 22 22 ENG- 10CHMM5020 5001 007 Formaldehyde 50000 149 149 Acetaldehyde 75070 20 20 OLORADO Air Pollution Control Division Pub{"Hea₹V1 eriirortrner;t Page 14 of 25 Acrolein 1 8 F 1 Methanol 67561 22 22 ENG- N6W00224 009 Formaldehyde 50000 11,460 5,730 Acetaldehyde 75070 834 834 Acrolein 107028 513 513 Methanol 67561 250 250 PW Tanks (LC22-A) 010 Benzene 71432 7,769 388 n -Hexane 110543 24,418 1,221 TLO (LC22-A) 011 Benzene 71432 62 3 Toluene 108883 53 3 Ethylbenzene 100414 7 <1 Xylenes 1330207 19 1 n -Hexane 110543 310 16 2,2,4- Trimethylpentane 110543 36 2 Condensate Tanks (LC22- A) 012 Benzene 71432 809 40 Toluene 108883 693 35 Ethylbenzene 100414 107 5 Xylenes 1330207 270 14 n -Hexane 110543 4115 206 2,2,4- Trimethylpentane 110543 470 24 LP-VRT (LC22-A) 013 Benzene 71432 2,320 116 Toluene 108883 1,423 71 Ethylbenzene 100414 425 21 Xylenes 1330207 664 33 n -Hexane 110543 16,631 832 2,2,4- Trimethylpentane 110543 212 11 ENG- R6S00892 017 Formaldehyde 50000 756 308 Acetaldehyde 75070 31 31 Acrolein 107028 29 29 Methanol 67561 34 34 ENG-R653102 018 Formaldehyde 50000 756 308 Acetaldehyde 75070 31 31 Acrolein 107028 29 29 COLORADO { Air Pollution Control Division Depar rkm ui PubL. )-f,n ".tv E-ra mrrnent Page 15 of 25 Methanol 6 3 ENG- N6W00251 020 Formaldehyde 50000 11,460 5,730 Acetaldehyde 75070 834 834 Acrolein 107028 513 513 Methanol 67561 250 250 ENG- 10CHMM5030 60026 021 Formaldehyde 50000 149 149 Acetaldehyde 75070 20 20 Acrolein 107028 19 19 Methanol 67561 22 22 ENG- 10CHMM4101 50017 022 Formaldehyde 50000 149 149 Acetaldehyde 75070 20 20 Acrolein 107028 19 19 Methanol 67561 22 22 PW Tanks (LC22-A) 023 Benzene 71432 5,162 258 n -Hexane 110543 16,223 811 TL0 (LC22-B) 024 Benzene 71432 56 3 Toluene 108883 37 2 Ethylbenzene 100414 33 2 Xylenes 1330207 19 1 n -Hexane 110543 284 14 2,2,4- Trimethylpentane 110543 33 2 Condensate Tanks (LC22- B) 025 Benzene 71432 1222 61 Toluene 108883 809 40 Ethylbenzene 100414 719 36 Xylenes 1330207 293 15 n -Hexane 110543 6241 312 2,2,4- Trimethylpentane 110543 732 37 LP-VRT (LC22-B) 026 Benzene 71432 1,568 78'. Toluene 108883 962 48 Ethylbenzene 100414 287 14 Xylenes 1330207 448 22 n -Hexane 110543 11,238 562 2,2,4- Trimethylpentane 110543 143 7 'COLORADO Air Pollution Control Division Depart '.t Hou;''n Ervv6r,rn_nt Page 16 of 25 Note: All non -criteria reportable pollutants i per year (lb/yr) are reportable and may r Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 001, 002, 017, 018: CAS Pollutant Units Emission Factors - Uncontrolled Emission Factors - Controlled Emission Factor Source NOx g/bhp-hr 13.47 2.00 CO g/bhp-hr 13.47 2.00 Manufacturer 50000 Formaldehyde g/bhp-hr 0.27 0.11 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 8,625 Btu/hp-hr, a site -rated horsepower value of 145 bhp, and a fuel heat value of 1,000 Btu/scf. Point 005, 006, 007, 021, 022: CAS Pollutant Units Emission Factors - Uncontrolled Emission Factors - Controlled Emission Factor Source NOx g/bhp-hr 14.00 1.00 Manufacturer CO g/bhp-hr 11.00 2.00 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 9,000 Btu/hp-hr, a site -rated horsepower value of 92 bhp, and a fuel heat value of 1,000 Btu/scf. Point 009, 020: CAS Pollutant Units Emission Factors - Uncontrolled Emission Factors - Controlled Emission Factor Source N0x g/bhp-hr 0.70 0.70 Manufacturer CO g/bhp-hr 2.43 1.00 V0C g/bhp-hr 0.70 0.70 50000 Formaldehyde g/bhp-hr 0.43 0.21 75070 Acetaldehyde lb/MMBtu 0.0836 0.0836 AP -42 107028 Acrolein lb/MMBtu 0.0514 0.0514 67561 Methanol lb/MMBtu 0.0250 0.0250 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 8,256 Btu/hp-hr, a site -rated horsepower value of 1,380 bhp, and a fuel heat value of 1,000 Btu/scf. Point 010, 023: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source N0x 0.0037 0.0037 AP -42 Ch. 13 CO 0.0167 0.0167 V0C 0.2620 0.0131 CDPHE 71432 Benzene 0.0070 0.0004 110543 n -Hexane 0.0220 0.0011 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Emissions of N0x and CO are based on a gas -to -water ratio of 36 scf/bbl and waste gas heating value of 1,496 btu/scf. !COLORADO Air Pollution Control Division iYUE,rE';:'r CF 3 ?`. J E':'rir-prstr.,C Page 17 of 25 Point 011: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 0.1398 0.0070 AP 42 Chapter 5.2 110543 n -Hexane 0.0018 9.1E-5 Note: The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46*S*P*M/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 3.4 psia M (vapor molecular weight) = 68 lb/lb-mol T (temperature of liquid loaded) = 512 °R The uncontrolled non -criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the stabilized oil by the VOC emission factor. Controlled emissions are based on the flare control efficiency of 95%. Point 012: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 0.0003 0.0003 AP -42 Ch. 13 CO 0.0012 0.0012 VOC 0.2339 0.0117 HYSYS Version 9 71432 Benzene 4.5E-04 2.2E-05 108883 Toluene 3.9E-04 1.9E-05 1330207 Xylene 1.5E-04 7.5E-06 110543 n -Hexane 2.3E-03 1.1E-04 540841 2,2,4 Trimethylpentane 2.6E-04 1.3E-05 Note: The controlled emissions factors for this point are based on the enclosed flare control efficiency of 95%. Emissions of NOx and CO are based on a gas -to -oil ratio of 1.39 scf/bbl and waste gas heating value of 2,693 btu/scf derived from the HYSYS process model. Point 013, 026: CAS # Pollutant Uncontrolled Emission Factors (lb/MMSCF) Controlled Emission Factors (lb/MMSCF) Source NOx 180.06 180.06 AP -42 Ch. 13.5 CO 820.88 820.88 VOC 106, 899.31 5,344.97 Extended gas analysis 71432 Benzene 330.73 16.54 108883 Toluene 202.88 10.14 100414 Ethylbenzene 60.56 3.03 1330207 Xylene 94.58 4.73 110543 n -Hexane 2,370.85 118.54 Note: The controlled emissions factors for this point are based on the enclosed flare control efficiency of 95%. The emission factors listed above are based on the LC22-B Econode VRT extended gas analysis. This is the most conservative (i.e. highest VOC content) of four (4) respective samples from the COLORADO Air Pollution Control Division _PcsCr-x::1 r P it }tea.N:r.+� €-;asararner Page 18 of 25 LC22-A Econode low-pressure sepa .rs, LC . Eco `..e li cress separ Econode VRT, and LC22-B Econod missi rs e ab representative of each vapor stream associated with these emission points. Limits are based on an estimated 500 hours per year of VRU downtime for each Econode (i.e. LC22-A Et LC22-B). Point 024:. CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 0.1398 0.0070 AP -42 Chapter 5.2 110543 n -Hexane 0.0026 1.5E-5 Note: The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46*S*P*M/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 3.4 psia M (vapor molecular weight) = 68 lb/lb-mol T (temperature of liquid loaded) = 512 °R The uncontrolled non -criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the stabilized oil by the VOC emission factor. Controlled emissions are based on the flare control efficiency of 95%. Point 025: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 0.0002 0.0002 AP 42 Ch. 13 CO 0.0010 0.0010 VOC 0.2405 0.0120 HYSYS Version 9 71432 Benzene 1.0E-03 5.1E-05 108883 Toluene 6.7E-04 3.4E-05 100414 Ethylbenzene 6.0E-04 3.0E-05 1330207 Xylene 2.4E-04 1.2E-05 110543 n -Hexane 5.2E-03 2.6E-04 540841 2, Trimethylpentane 6.1E-04 6.1E-04 3.1E-05 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Emissions of NOx and CO are based on a gas -to -oil ratio of 1.27 scf/bbl and waste gas heating value of 2,674 btu/scf derived from the HYSYS process model. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) Point 001, 002, 005, 006, 007, 009, 017, 018, 020, 021, 022: 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). COLORADO Air Pollution Control. Division PtF z t eatt & E.vir-tn-rei",t Page 19 of 25 This rule has not yet been incorporated o Color+ Air lity trot C misslo No. 6. A copy of the com.}_₹. is le EPA ,t http://www.epa.Rovittn/atw/area/fr18ia08.pdf 9) Point 001, 002, 005, 006, 007, 009, 017, 018, 020, 021, 022: 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/fr18ja08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html 10) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, CO, HCHO, benzene, n -hexane, Total HAP PSD Synthetic Minor Source of: VOC MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Not Applicable NSPS JJJJ Applicable MACT ZZZZ Major Source Requirements: Not Applicable Area Source Requirements: Applicable 11) 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 Pollutionf Control Division $ '- ;;Y;,3YM,nt is Pubk b!Eh a J "rV"�YVT12f Page 20 of 25 A A MENT 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. OLORkDO Air Pollution Control Division Lie otmer4 Pubt'_ Hearth , Envier J'Le t Page 21 of 25 2.1.2 The owner or operator may permanen ' replace = - exis i eng with other e same manufacturer, model, and horsepwithmit 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 www.colorado.gov/cdphe/air/AOS. 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: www.colorado.gov/cdphe/portable-analyzer-monitoring-protocol Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd ® 15% O2) that the existing unit is currently subject to or the replacement COLORADO Air Pollution Control Division of lila,. Health.'J "rU"9X'33Sc't,C Page 22 of 25 engine will be subject to, the results of the in the above -mentioned Portable Analyze 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 S 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 5O2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ 5O2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (5 60.331) and 40 CFR Part 72 (5 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 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. COLORADO Air Pollution Control Division Depart --Ant- PuMit fr?e£uzit*r E:;vvorimert Page 23 of 25 The above emission control equipment shall and maintained according to manufacture = = •"'s. 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 July 1, 2007 2.0 4.0 1.0 500≤Hp July 1, 2010 1.0 2.0 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, § 1.6 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 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 requirements for the permanent engine replacement shall be included in the Applicability Reports COLORADO Air Pollution Control Division rtepertneent C%r. Pu6Eic I (mien & Environment Page 24 of 25 required under Condition 2.1.2. Any testing e MAC is m +ition that re AOS. Note that the initial test required by sery .�� .._ tes--d by 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. ICOLORADO Air Pollution Control Division '.7tY'fFIY('Y: d':J PCiW = Nei sth. J EYV rtnrr1eflt Page 25 of 25 Reciprocating Internal Combustion Engine APEN Form APCD-201 lAir Pollutant Emission, Notice (APEN) and Application for Construction Permit Alt 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 atz www. c o lorad o. gov f c d phe l a pcd, 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, (I.C. for revised APEN requirements, Permit Number: AIRS ID Number: 19_2,,/ f [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: Site Name: Site Location: Noble Energy Inc. LC22 - A ECONODET9N-R59W-S22 L01 NWNE SEC22 T09 R59 Mailing Address: tlndudd Zip code) 1625 Broadway, Suite 2200 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAiCS or SIC Code: Permit Contact:. Phone Number: €-Mail Addressz: 311 Gabriela Vega (303) 228-4475 Gabriela,Vega@nbienergy,cam 'Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork, ?Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Fofir. APCD-20.1 lved 0117-11w ati9 g internal Glinbustiort Engine r-.PEii i ;on l 2:1 Permit Number: AIRS ID Number: / [Leave blink unless APCD has already assigned a permit k and AIRS ID] Section 2 - Requested Action NEW permit OR newly -reported emission source (cheek one below) ❑ STATIONARY source 0 PORTABLE source ® Request coverage under a Construction Permit ❑ Request coverage under General Permit GP02' (Natural Gas Only) if coverage under General Permit GP02 is requested, an additional fee of $1,50x.00 is required In lieu of hourly fees. -OR- ❑ MODIFICATION to existing permit (check each bay below that applies) ❑ Change fuel or equipment 0 Change company name ❑ Add point to existing permit o Change permit limit ❑ Transfer of ownership' 0 Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - Additional Permit Actions - ❑ APEN submittal for perm;t-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: 3anly one engine maybe reported per APEN for @02 coverage. Coverage under GP02 is voluntary. 'For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 'GP02 fee is not required, but APEN filing fee is required, 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- R6504244 General description of equipment and purpose: Compression Engine For existing sources, operation began on: 12/11/2017 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? ❑ Yes ® No jhttp: //www.colorado.gov/cdphe/attainment) 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 Furun \, ._D•2iL P,'' jpr. c .ire If L:ci 1'.01 i:r bt tL.sr _>rii i7.fI • ;ielii 4;120;6 2 COial 401/ Permit Number: AIRS ID Number: 1 [Leave blank unless APCD has already assigned a permit g: and AIRS ID] Section 4 - Engine Information Engine Function: O Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back -Up ▪ Other: ® Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Caterpillar Engine Model: G3306 NA hours/year Serial Number6:-P4501206 (2 �5 1�u17 1 What is the maximum designed horsepower rating? 145 hp What is the engine displacement? l/cyl What is the maximum manufacturer's site -rating? 145 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8625 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ® 4 -Stroke Combustion: ❑ Lean Bum ® Rich Bum. Ignition Source: ® Spark ❑ Compression Aspiration: ® Natural ❑ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ® Yes ❑ No If yes, what type of AFRC is in use? ® Oz Sensor (mV) ❑ NOx Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOx design? ❑ Yes ❑ No Engine Dates: What is the manufactured date of this engine? 10/31/2014 What date was this engine ordered? What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an A0S replacement engine? ❑ Yes O No If yes, provide the make, model, and serial number of the otd engine below: Engine Make: Engine Model: °The serial number must be submitted if coverage under GPM is requested. Serial Number: (\S�.. C O L O R A oo Form APCD•201 Recipiocnt!n I litl i nal Cnolhi >I,i=:n Erulline APEli - Revision I I /7_i?I6 3 f Permit Number; AIRS ID Number: / [Leave blank untess.APCD has already assigned a permit. € and MRS ID] Section 5 - Stack Information Geographical Coordinates (LatitudelLengitude or UTM) 40.7396/-103.9691 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. (.F) Flow Rate (ACFM) Velocity (ft/sec) Indicate the direction of the Stack outlet: (check one) ® Upward O Horizontal D Downward 0 Other (describe): Indicate the stack opening and size: (check one) ® Circular ❑ Square/Rectangle ❑ Other (describe): 0 Upward with obstructing raincap Interior stack diameter (inches): Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate ® 100% Load (SCR hour) Actual Annual Fuel Use (MMSCF/year) Requested Annual Permit Limit' (MMSCF! year) 1250.63 10.96 From what year is the actual annual amount? Indicate the type of fuel used°: Pipeline Natural. Gas (assumed fuel heating value of 1,020 BTU/scf) Field Natural Gas Heating value: 1000 BTU/scf Propane (assumed fuel heating value of 2,300 BTU/scf) Landfill Gas Heating value: BTU/scf Other (describe): Heating value (give units): 1Requested values will become permit limitations. Requested limit(s) should consider future process growth. "lf'fuel heating value is different than the listed assumed value, provide this information in the "Other" field. F{rIcrn r. D C., I lZ016 ;t c�,oNaoa 4� Permit Number: AIRS ID Number: ((_cage blank unless-APC0 has already a igned a permit # and AIR5 ID) Section 7 - Emission inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. is any emission control equipment or practice used to reduce emissions? O Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction In emissions) TSP (PM) PMxo PM2.5 SOx NOx NSCR & AFRC 'J7(i1 •9` VOC CO NSCR Et AFRC. 85,152 Other: Formaldehyde - NSCR & AFRC 45()I t3 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? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emission? Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons//year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) PM,o 0,01941 lb/mmBtu AP -4Z 0.10632 0.10632 PM2.s 0,01941 lb/mmBtu AP -42 0.10632 0.10632 SOx 0.000588 lb/mmBtu AP•42 0.00322 0.00322 NOx 13.47 g/hp•hr Mfg/Reg71JJJJ 18.8602 -1.40060 VOC 0.7 g/hp'hr Mfg/Reg 7/JJJJ 0.98011 0.98011 CO 13.47 g/hp'hr Mfg/Reg 7/JJJJ _ 18.8602 2.80033 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250'lbs/year? ® Yes O No If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions inventory Chemical Name Chemical Abstract (CAS) Service CAS Number Emission Factor Actual Annual Emission? Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Poundslyear) Controlled Emissions (Pounds/ ear) Formaldehyde 50000 0.27 g/hp-hr Mfg. 756 `? _ Acetaldehyde 75070 Acrolein 107028 Benzene 71432 Other: 'Requested values will become permit limitations. Requested limits) should consider future process growth. °Annual emissions fees will be based on actual controlled emissions reported. if source has not yet started operating, leave blank. 5I 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 Authorized Person,(adi vendor or consultant) Gabriela Vega Name (please print) Date Environmental Engineer Title Check the appropriate box to request a copy of the: ® Draft permit prior to issuance ® Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 (if applying for GP02 For more information or assistance call: submit with an additional $1500), to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit APCD website at: Denver, CO 80246-1530 Make check payable to; https;//www.colorado.gov/cdphe/aped Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Form <,PCD-201 R cipi:cat.witsi Internai Coinbustion c r4in'? HPEll - ie,isioo i 1121)I6 6) Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit Alt 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.flov/cdohefalocd. 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: IgAIU 021 CI AIRS ID Number: l f [Leave blank unless APCD has already assigned a permit # and AIRS ID) Section i - Administrative Information Company Namet: Site Name: Site Location: Noble Energy inc. LC22 - A ECONODE T9N-R59W-522 Lot Site Location NWNE SEC22 T09 R59 County: Weld Mailing Address: (Include zip Code) 1625 Broadway, Suite 2200 Portable Source Home Base: Denver, CO 80202 NAICS or SIC Code: 1311 Permit Contact: Phone Number: E -Mail Address2: Gabriela Vega (303) 228-4475 Gabriela,Vega®n blenergy. corn '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. o•o Form APCD-201 - Reciprocating internal Combusticit Engine APEN - ,, is on 11 /2016 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 O PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If coverage under General Permit GP02 is requested, an additional fee of $1,500.00 is required in lieu of hourly fees. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name O Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' 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 E Notes: 'Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 'For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5GP02 fee is not required, but APEN filing fee is required. 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-R6504206 General. description of equipment and purpose: Compression Engine For existing sources, operation began on: 12/11/2017 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? ❑ Yes ® No (http: //www.colorado.gov/cdphe/attainmentl 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 1112:,x16 2 oloa ADO Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump O Water Pump ❑ Emergency Back -Up O Other: ® Compression What is the maximum number of hours this engine wilt be used for emergency hours/year back-up power? Engine Make: Caterpillar Engine Model: G3306 NA Serial Number6: R6504206 What is the maximum designed horsepower rating? 145 hp What is the engine displacement? t/cyl What is the maximum manufacturer's site -rating? 145 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8625 BTU/hp-hr Engine Features: Cycle Type: , ❑ 2 -Stroke ® 4 -Stroke Combustion: O Lean Burn ® Rich Burn Ignition Source: ® Spark ❑ Compression Aspiration: ® Natural ❑ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ® Yes O No If yes, what type of AFRC is in use? ® Oz Sensor (mV) ❑ NOx Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑ Yes O No Engine Dates: What is the manufactured date of this engine? 10/27/2014 What date was this engine ordered? O Other: What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? O Yes ❑ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6The serial number must be submitted if coverage under GP02 is requested. Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 11 /2016 I cocoa.00 Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit t and AIRS 10] Section 5 - Stack Information Geographical Coordinates (LatitudetLongitude or UTM) 40.7396/-103.9691 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. CF:,(ACFM) Flow Rate Velocity (ft/sec) Indicate the direction of the Stack outlet: (check one) El Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ® Circular Q Square/ Rectangle ❑ Other (describe): O Upward with obstructing raincap Interior stack diameter (inches): Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load (SC1•-lhour) Actual Annual Fuel Use (MMSCFIyear) ' Requested Annual Permit Limit? (MMSCF/year) 1250,63 10.96 From what year is the actual annual amount? Indicate the type of fuel used8: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTUIscf) ❑ Field Natural Gas Heating value: 1000 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating value: ❑ Other (describe): BTU / scf Heating value (give units): 'Requested values will become permit limitations. Requested limit(s) should consider future process growth. elf fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating internal Combustion Engine APEN - Revision 11/2016 II' C4 LOA A0zJ Permit Number: AIRS ID Number: i [Leave blank unless APCD has already assigned a permit ft and MRS ID] Section 7 - Emission 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 Q No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction 3n emissions) TSP (PM) PMio PM2.3 SOx NOx NSCR & AFRC , VOC Co NSCR & AFRC 85.152 Other: Formaldehyde - NSCR & AFRC SIa1 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? Criteria Pollutant Emissions inventory Pollutant Uncontrolled Basis Emission Factor lb/mmBtu Source (AP -42, Mfg. etc) Actual Annual Emissions9 Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Requested Annuat Permit Emission i_irnit(s)7, Uncontrolled Emissions (Tons/year) Controlled Emissions (rolls/year) TSP (PM) PMio PM2.5 0.01941 0.01941 AP -42 0.10632 0.10632 lb/mniBtu AP -42 0.10632 0.10632 Sox NOx VOC 0.000588 Ib/mm8tu AP -42 0.00322 0,00322 13.47 g/hp-hr g/hp.hr g/hp-hr Mfg/Reg 71JJJJ Mfg/Reg 7/JJJJ Mfg/Reg 7/JJJJ 18.8602 0.98011 0.7 0.98011 Co 13.47 18.8602 2.80033 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 lbstyear? Yes ❑ No If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract (CAS) service CAS 'Number Emission Factor Actual Annual Emissions9 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0.27 g/hp-hr Mfg. 756 3°1 Acetaldehyde 75070 Acrolein 107028 Benzene 71432 Other: 'Requested values will become permit limitations. Requested limit(s) should consider future process growth. 'Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank, i err � APCD-201 - Reciproc- lirng l ternal Combustin phi Re n ion 11 /'_016 5i r 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. If this is a registration for coverage under general permit GP02, I further certify that this source is an wilt b operated in f !l compliance with each condition of general permit GP02. Xath 05/08/2018 Signature of Legally Authorize(not a vendor or consultant) Date Gabriela Vega Name (please print) Environmental Engineer Title Check the appropriate box to request a copy of the: ® Draft permit prior to issuance ® Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, ILC. for revised APEN requirements. Send this form along with $152.90 (if applying for GP02 For more information or assistance call: submit with an additional $1500), 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 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-201 - Rc-ciprocetinsi Internal Combustion Engine APEN - Revision 11 /2016 6 I 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 fitted 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-280) 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.govicdphe/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: Vte AIRS ID Number: illilfrifzi [Leave blank tin ess APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: Noble Energy inc. LC22 A ECONODE Tai-R59W-S22 L01 NWNE 5EC22 T09 R59 Mailing Address: (Include Zip Code) 1625 Broadway, Suite 2200 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Phone Number: E-Ma`il Address2: Gabriela Vega 303-228-4475` Gabriela,Vega®nblenergy.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. Fa". .,P U -Z 1 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 J Request coverage under a Construction Permit ❑ Request coverage under General. Permit GP023 (Natural Gas Only) If coverage under General Permit GP02 is requested, an additional fee of $1,500.00 is required in lieu of hourly fees. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name O Add point to existing permit ❑ Change permit limit ❑ Transfer of ownerships 0 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 E Notes: 3Onty one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 'For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted, 5GP02 fee is not required, but APEN filing fee is required. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? if yes, provide the Company Equipment Identification No. ENG-10CHMM503090035 Yes General description of equipment and purpose: Compression Engine For existing sources, operation began on: 12/11/2017 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? ❑ Yes ® No (http: //www.colorado.aov/cdphe/attainment) 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 'nn 4.PCD-20I Inten131 COrnbti-.�tic,t En , APF_ i r._', pt+�t� � 1'20'16 tcEo o.t, Permit Number: AIRS ID Number: / [Leave blank unless .APCD has already assigned a permit # and AIRS ID) Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump O Water Pump ❑ Emergency Back -Up ❑ Other: ® Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: GM hours/year Engine Model: 5.7L Serial Number6: 10CHMM503090035 What is the maximum designed horsepower rating? 92 hp What is the engine displacement? l/cyt What is the maximum manufacturer's site -rating? 92 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 9000 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ® 4 -Stroke Combustion: O Lean Burn ® Rich Burn Ignition Source: ® Spark O Compression Aspiration: ❑ Natural O Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ® Yes O No If yes, what type of AFRC is in use? ® O2 Sensor (mV) ❑ NOx Sensor (ppgn) Is this engine equipped with a Low -NO% design? O Yes ❑ No Engine Dates: What is the manufactured date of this engine? 03/09/2015 What date was this engine ordered? O Other: What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes O No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 'The serial number must be submitted if coverage under GP02 is requested. Form APCD-2O i ReReciprocaiting I!7" ei a:,ii t_! i b ,Jo APEIl Revision 11)20 i 6 3 ADO Permit Number: AIRS ID Number: [Leave blank finless APCD has already assigned a permit # and AIRS 101 Section 5 - Stack Information eographical Coordinates (Latitude/Longitude or UTM) 40.7396/-103.9691 Operator. Stack ID No. Discharge Height " Above Ground Level (Feet) . 'Temp'Flow F) "Date (1CFM) Yelocaty' (ftlsec) Indicate the direction of the Stack outlet: (check one) Upward O Horizontal ❑ Downward ❑ Other (describe): O Upward with obstructing raincap Indicate the stack opening and size: (check one) ► Circular Interior stack diameter (inches): ❑ Square/Rectangle Interior stack diameter (inches): Interior stack depth (inches): ❑ Other (describe): Section 6 - Fuel Data and Throughput Information Fuel' Use Rate ® 100% Load (SCE/hour), ... Actual Annual Fuel Use .. ,,,(/riMSCFlyear) `' Requested Annual Permit Limit? ' (M SCF/year) 828 <, From what year is the actual annual amount? Indicate the type of fuel useda: o Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) 18 Field Natural Gas Heating value: 1000 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 limits) should consider future process growth. 81f fuel heating value is different than the listed assumed value, provide this information in the "tither" field. ForLia ,n, ixf2)1. 4l Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emission 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? 0 Yes 0 No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant TSP (PM) PMio PM2.5 Primary Control Equipment Description Overall Repuested_Control" Efficiency (% reduction. In emissions) SOX NOx VOC NSCR Et AFRC 92.9 CO NSCR 8: AFRC 81.8 Other: Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? ;Pollutant• .. TSP (PM) PMio PM2.5 .ritena Pollutant`Emissions Inventory mission Factor=. Uncontrolled Basis 0.01941 lb/mmBtu Source (AP -42, Afg. etc) AP -42 ctualAnnual Emissions' Uncontrolled Emissions • {Tons/year) Controlled• emissions (Tons)year) :Requested Annual Permit , ". Emission Lmit(s)7 = Uncontrolled Emissions (lonslyear) 0.07039 ontrolled missions Lonsiyear) 0.07039 SOx NOx VOC 0.01941 lb/mmBtu AP -42 0.07039 0.07039 0.000588 lb/mmBtu AP -42 0,00213 0.00213 14 g/hp•hr g/hp•hr g/hp•hr Mfg/Reg 7/JJJJ 12.43731 0.62187 0. 88837 0.7 Mfg/Reg 7/JJJJ Mfg/Reg 7/JJJJ 0.62187 CO 11. 9.77217 1.77675 Does the emissions source have any uncontrolled actual emissions of non -criteria ❑ Yes ® No 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: Formaldehyde Acetaldehyde Acrolein Benzene oh Criteria Reportable Pollutant Emissions inventory heroical Abstract Service (CAS) :'Number. 50000 75070 107028 mission Factor Source (A� 42, Mfg.' etc) ctual•Annual'Emissions9 Uncontrolled €missions (Poundslyear) Controlled Emissions (Poundslyeor) Other: 71432 'Requested values will become permit limitations. Requested limit(s) should consider future process growth. 'Annual emissions fees will be based on actual controlled emissions reported. if source has not yet started operating, leave blank. Form APCD-2.01 R.e.:i . ,:•3C ng intern?l. Combustion Engine APEN Revision 7112,016 51 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 furC rnpliancwith each condition of general permit GP02. ,\6 _ Si ture of Legally Authorized Personot a vendor or consultant) 07/12/2018 Gabrieta Vega Date Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: ® Draft permit prior to issuance O Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) 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 (if applying for GP02 For more information or assistance call: submit with an additional $1500), 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 Small Business Assistance Program (303) 692-3175 or (303) 692.3148 Or visit APCD website at: https://www.colorado.gov/cdphe/apcd F'Drm 42O1'201 RaciPro-atmf. Inter it Con b..i..,. n Engin.? APE i R i ioo i;'2016 45-1 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 forums can be found on the Air Pollution Control Division (APCD) website at: www.cotorado.govicdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised ADEN 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: VV 60 11 AIRS ID Number: 11, [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Namel: Site Name: Site Location: Noble Energy Inc. LC22 - A ECONODE T9N-R59W-522 L01 Site Location NV/NE SEC22 T09 R59 County: Weld Mailing: Address: (include Zip Code) 1625 Broadway, Suite 2200 Portable Source Home Base: Denver, CO 80202 NAILS or SIC Code. 1311 Permit Contact: Gabriela Vega Phone Number: 303-228-4475 E -Mail Addressl: Gabriela.Vega@nblenergy.comn '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. i:.o. T: APCD COI - Re,:ipDcat APEN 1 1 Permit Number: AIRS ID Number: P23 / CIFsr`tq / COP [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 2 - Requested Action • NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source O PORTABLE source El Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If coverage under General Permit GP02 is requested, an additional fee of $1,500.00 is required in lieu of hourly fees. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name O Add point to existing permit ❑ Change permit limit O Transfer of ownership'' 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: 3Oniy one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 'For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5GP02 fee is not required, but APEN filing fee is required. 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-10CHMM503060080 General description of equipment and purpose: Compression Engine For existing sources, operation began on: 12/11/2017 For new or reconstructed sources, the projected start-up date is: Witt this equipment be operated in any NAAQS nonattainment area? ihttp: //www. colorado. gov/cdphe /attainment) Normal Hours of Source Operation: 24 hours/day 7 ❑Yes ElNo days/week 52 Seasonal use percentage: Dec_Feb: 25 Mar -May: 25 weeks/year June_Aug: 25 Sept -Nov: 25 ,)PC �•2� 1 R,eci rucat.ing Internal Combustion Engine A?El•I - Revision 1112016 • `JI ill r•: Li. _ •.� �� Ola ADO Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump O Water Pump ❑ Emergency Back -Up ❑ Other: ® Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: GM hours/year Engine Model: 5.7L Serial Number6: 10CHMM503060O8O What is the maximum designed horsepower rating? 92 hp What is the engine displacement? What is the maximum manufacturer's site -rating? 92 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 900O BTU/hp-hr Engine Features: Cycle Type: O 2 -Stroke ® 4 -Stroke Ignition Source: ® Spark O Compression 1/cyl Combustion: O Lean Burn ® Rich Burn Aspiration: ❑ Natural ❑ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ® Yes ❑ No If yes, what type of AFRC is in use? ® OZ Sensor (mV) O NOx Sensor (ppm) ❑ Other: is this engine equipped with a Low-NOx design? ❑ Yes O No Engine Dates: What is the manufactured date of this engine? 03/06/2015 What date was this engine ordered? What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? O Yes ❑ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6The serial number must be submitted if coverage under GP02 is requested. ft r1 APCD-2O1 Recipro,tatini. int .nab Col .,s.i n 1P ,i Revision i1 f 201 3 I rs�issgao Permit Number: AIRS ID Number: r [Leave blank unless APCD has already assigned a perr tit, t and AIRS ID).. Section 5 w Stack Information Geographical Coordinates {LafitudelLot situde or LJTM) 40.7396/-103.9691 Operator Stack ID No Discharge Height, Above Ground Level Temp {•F) � Flow ate CACF,N) Velocity (filsec)(Feet) Indicate the direction of the Stack outlet: (check one) ►Z4 Upward O Horizontal Downward ❑ Other (describe): Indicate the stack opening and size: (check one) Circular Interior stack diameter (inches): O Square/Rectangle O Other (describe): 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/yea€) ' ':.. Requested Annual Permit Limit? (MMSCF1year) 828 From what year is the actual annual amount? Indicate the type of fuel used8: El Pipeline Natural. Gas (assumed fuel heating value of 1,020 BTU/set) Field Natural Gas Heating value: `Ot., BTU/scf • Propane (assumed fuel heating value of 2,300 BTUlscf) 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. 811 fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Permit Number: AIRS ID Number: 1 / [Leavµ btank unless APCD has already assigned a permit and AIRS ID] Section 7 - Emission 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 0 No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant TSP (PM) PMio PM2.5 Primary Control Equipment Description Overall Requested. Control' Efficiency (% reduction in emissions).. SOx NOx VOC NSCR Et AFRC 92.9 CO Other: NSCR a AFRC 81.8 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? Criteria Pollutant Emissions Inventory Pollutant TSP (PM) PMio PM2.a Emission Factor Uncontrolled Basis lb/mmBtu Source (AP -42, Mfg. ett) `Actual Annual.Emissions9 Uncontrolled . . Emissions (Tonslyear) Controlled Emissions (rons/yror) Requested Annual Permit: . Emission Limit(s)7 Uncontrolled Emissions {Tons/year) Controlled. Emissions (ronslyear) 0.01941 AP -42 0.07039 0.07039 Sox NOx VOC 0,01941 0.000588 lb/mmBtu AP -42 0.07039 0.07039 lb/mmBtu AP -42 0.00213 12.43731 0.00213 14 0.7 g/hp-hr g/hp•hr g/hp-hr Mfg/Reg 7/JJJJ Mfg/Reg 7/JJJJ 0. 88837 0.62187 0.62187 CO 11 Mfg/Reg 7/JJJJ 9.77217 1.77675 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 Chemical Name Formaldehyde Acetaldehyde Acrolein Benzene Non Criteria Reportable Pollutant Emissions Inventory Actual Annual Emission s9 Chemical . _ Abstract Service (CAS) Number 50000 75070 107028 •Emission.Factor • Uncontrolled Basis' Units. Source OP -42). Mfg etc) Uncontrolled •Emissions • (Pounds/year) Controlled Emissions (Pound /ear). 71432 Other: 'Requested values will become permit limitations. Requested limit(s) should consider future process growth. 'Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Ftiim APCD-201 . cdt 1,":ternal Combustion En-s2.iiie ADEN P. . ice i ' t .. 5 I 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 ,lilt be operated in full compliance with each condition of general. permit GP02. 07/12/2018 Si' ature of Legally Authorized\Person (not a vendor or consultant) Gabriela Vega Name (please print) Date Environmental Engineer Title Check the appropriate box to request a copy of the: ® Draft permit prior to issuance O Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, ll.C. for revised APEN requirements. Send this form along with $152.90 (if applying for GP02 For more information or assistance call: submit with an additional $1500), to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.cotorado,gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 PCD 1 r, '. swa Internal.COrnbusIonEFT Small Business Assistance Program (303) 692-3175 or (303) 692-3148 AP_;; • Re ii 11./2016 6j ask _j 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 wilt not satisfy your reporting needs. A list of atl available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/edphe/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, WC. for revised. APEN requirements, Permit Number: N O AIRS ID Number: 12.3 lolF449 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: Noble Energy inc. LC22 - A ECONODE T9N-R59W-S22 L01 Site Location NWNE SEC22 T09 R59 County Weld Mailing Address: linclude Zip Code) 1625 Broadway, Suite 2200 Portable Source Home Base: Denver, CO 80202 NAICS or SIC Code: 1311 Permit Contact: Phone Number: E -Mail Address2: Gabriela Vega 303-228-4475 Gabriela.Vega®nblenergy.com "Use the full, legal company name registered wih 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 email to the address provided. /WEN 3 .°tt 11/2016 1I ip Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 2 - Requested Action NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source O PORTABLE source 454_ —Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If coverage under General Permit GPOZ is requested, an additional fee of 51,500.00 is required in lieu of hourly fees. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name O Add point to existing permit ❑ Change permit limit O Transfer of ownerships O 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 Ft Notes: 'only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 'For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5GP02 fee is not required, but APEN filing fee is required. Section 3 - General Information Does this engine have a Company Equipment Identification No, (e.g. ENG-1, Engine 3, etc)? If yes, provide the Company Equipment Identification No. ENG-1DCHMM50205001 Yes General description of equipment and purpose: Compression Engine For existing sources, operation began on: 03/05/2018 For new or reconstructed sources,the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: //www.coloraclo.gov/cdphe/attainment) Normal Hours of Source Operation: 24 hours/ day 7 ❑ Yes ® No days/week 52 Seasonal use percentage: Dec_Feb: 25 Mar -May: 25 weeks/year June_Aug: 25 Sept -Nov: 25 _ _ . _ . _, c. APCD-2O1 : �' _._lp-:fir ., l „ lt:.._ ..c. +_.;! __ .„ f'i- '.?I( t :`.l.l .. ^�,.,,.,...�t 11./71016 coLuwt cs 2 all Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit .# and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back -Up ❑ Other: ® Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: GM hours/year Engine Model: 5.7L Serial Number6: 10CNMM50205001 What is the maximum designed horsepower rating? 92 hp What is the engine displacement? l/cyl What is the maximum manufacturer's site -rating? 92 hp kW What is the engine Brake Specific Fuel. Consumption at 100% Load? 9000 BTU/hp-hr Engine Features: Cycle Type: O 2 -Stroke ® 4 -Stroke Combustion: ❑ Lean Burn ® Rich Burn Ignition Source: ® Spark O Compression Aspiration: ❑ Natural O Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ® Yes O No If yes, what type of AFRC is in use? ® 02 Sensor (mV) ❑ NOx Sensor (ppm) O Other: Is this engine equipped with a Low -11/410x design? O Yes O No Engine Dates: What is the manufactured date of this engine? 02/05/2015 What date was this engine ordered? What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? O Yes O No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: The serial number must be submitted if coverage under GP02 is requested. r i.. _ Revision �:� ._� �:.:� �i .i;.3f l r? z� � S:'C..., j C<) -i � ;i..Et}i't t.fi 9i:7°' 1�YC) 1 . ?ii 1 I't' 1i AyCOLORADO Permit Number: AIRS ID Number: fUeave blank unless APCD has already assigned a permit and AIRS ID) Section 5 - Stack information Geographical Coordinates (Latitude/Longitude or!l3hl) 40.73961-103..9691' Operator Stack ID No. - Discharge Hei•ght Levl Above d e Groun (Feet) Temp.Flow ('N Rate (ncE,M) Velocity (ftisec')' Indicate the direction of the Stack outlet: (check one) Upward ❑ Horizontal. El 0 Downward Other (describe): Indicate the stack opening and size: (check one) Circular Interior stack diameter (inches): ❑ Square/Rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 Fuel Data and Throughput Information Fuel Use Rate ;100% Load (SCFlhour)' Actual Annual Fuel,Use (MMSCF(year) Requested Annual Permit Limit? {MMSt F/yeah) 828 From what year is the actual annual amount? Indicate the type of fuel used': ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) 0 Field Natural Gas Heating value ‘W) BTUlscf [j Propane (assumed fuel heating value of 2,300 BTllscf) ❑ Landfill Gas Heating value: BTU/scf ❑ Other (describe): Heating value (give units): ?Requested values wilt become permit limitations. Requested limit(s) should consider future process growth. 'If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. 4I Permit Number: AIRS ID Number: / (Leave blank unless APCD has already assigned a permit # and AIRS ID) Section 7 - Emission 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): TSP (PM) PMi o PM2.s Primary Control Equipment Description .;. Overall Requested `Controi Efficiency ;' (%reduction in emrssionsj SOx NOx voC NSCR Et AFRC 92:8 CO Other: NSCR & AFRC 81.8 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? Criteria Pollutant Emissions Inventory Pollutant TSP (PM) PMto PM2.s Emission Factor Uncontrolled -_ Basis 0.01941 Ib/mmBtu Source (AP -42, Mfg. etc) AP -42 ctual Annual Emissians9 Uncontrolled r. Emissions (Tons/ year) Controlled • ;Emissions (Tonslyear) Requested Annual Permit Emission Liinit(s)? Uncontrolled Emissions (Tonsl:year) 0.07039 Controlled Emissions (Tons/year) 0.07039 SOx NOx vOC 0,01941 lb/mmBtu AP -42 0.07039 0.07039 0.000588 Ib/mmBtu AP -42 0.00213 0.00213 14 g/hp'hr g/hp-hr g/hp-hr Mfg/Reg 7/JJJJ 12.43731 0. 88837 0.7 Mfg/Reg 7/JJJJ 0.62187 0.62187 CO 11 Mfg/Reg 7/JJJJ 9.77217 1.77675 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 on -Criteria -Reportable pollutant -Emissions Invent° Formaldehyde Acetaldehyde Acrolein Benzene Chemical Abstr-act Service (CAS) Number` _ 50000 75070 107028 Uncontrolled_ Basis mission Factor Source (AP 42, Mfg etc), ctuai Annual Etnissions4' Uncontrolled Emissions APijah'sfi,6241. • Controlled Emissions .(Pounds/year) Other: 71432 'Requested values will become permit limitations. Requested limit(s) should consider future process growth. AAnnual emissions fees wilt be based on actual controlled emissions reported. If source has not yet started operating, leave blank. QtoRApt? -F:.. 5APCD-20.I V: ?,_,a s. nte+tr:2l C:;rt +;, - - , iAPE.:..-1 • I I 2016 5 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 alt 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 an will be operated in full compliance with each condition of general permit GP02. Signature of Legally Auted Person (not a vendor or consultant) Gabriela Vega Name (please print) Environmental Engineer Title Check the appropriate box to request a copy of the: ® Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, Ii.C. for revised APEN requirements. Send this form along with $152.90 (if applying for GP02 submit with an additional $1500), 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 APCD website at: https://www.cotorado.gov/cdphe/apcd APCO.2O1 fir- i ri_. ,as Ccinbusticki E ₹i: A .tI Rovisicin 1 1120 6 6l GLOR400 Received 7/9/18 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/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/ear term, or when a reportable changeis 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: 4g E- 0'2-,'70 AIRS ID Number: 1 2„' j / t [heave blank unlelss APCD hasalready assigned a permit it and AIRS ID] / 009 Section '- Administrative Information Company Name' Noble Energy Inc. Site Name: LC22 A ECONODE T9N-R59W-522 L01 Site Location: NWNE SEC22 109 R59 Mailing Address: (include Zip Code) Portable Source Home Base: 1625 Broadway, Suite 2200 Denver, CO 80202 Site Location County: Weld NAILS or SIC Code: 1311 '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. 2Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 11/2j)14:, 1 I Permit Number: AIRS ID Number: / 009 (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 O PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GPO23 (Natural Gas Only) if coverage under General Permit 01,02 is requested, an additional fee of $1,500.00 Is required in lieu of hourly fees. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name O Add point to existing permit ❑ Change permit limit O Transfer of ownership4 ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - Additional Permit Actions - ID APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: 'Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. SGPO2 fee is not required, but APEN filing fee is required. 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-N6W00224 General description of equipment and purpose: Compression Engine For existing sources, operation began on: 12/13/2017 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: //www. colorado. qov/ cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 ❑ yes ® No days/week 52 Seasonal use percentage: Dec^Feb: 25 Mar -May: 25 weeks/year June_Aug: 25 Sept -Nov: 25 cnioaruo 2I F" Permit Number: AIRS ID Number: / 009 [Levee blank unless APCD has already assigned a permit f; and AIRS ID Section 4 µ Engine Information Engine Function: ❑ Primary and/or Peaking O Pump O Water Pump ❑ Emergency Back -Up ❑ Other: I1 Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make Caterpillar Engine Model: 03516 Serial Numbers: N6W00224 hours/year What is the maximum designed horsepower rating? 1380 hp What is the engine displacement? t/cyl What is the maximum manufacturer's site -rating? 1380 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8256 BTU/hp-hr Engine Features: Cycle Type: Ignition Source: Is this engine equipped with an Air/Fuel ratio controller (AFRC)? isj Yes ❑ No ❑ 2 -Stroke 4 -Stroke Combustion: 13 Lean Burn ❑ Rich Burn ►.1 Spark ❑ Compression Aspiration: O Natural A Turbocharged if yes, what type of AFRC is in use? O 02 Sensor (mV) ® NOx Sensor (ppm) O Other: Is this engine equipped with a LoW-NOx design? ❑ Yes ❑ No Engine Dates: What is the manufactured date of this engine? 06/08/2017 What date was this engine ordered? What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an ADS replacement engine? ❑ Yes O No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 5The serial number must be submitted if coverage under GPM is requested. i"t IT. pc() L�: ! Permit Number: AIRS ID Number: / / 009 tleave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude ar;UTM) 40/396/-103.9691 Operator Stack ID No. ' - Discharge Height Above Ground Level. e. (Feet) Temp. O Floyv Rate (ACFM) Velocity (ftlsec) Indicate the direction of the Stack outlet: (check one) D Downward 0 Other (describe): ® Upward ❑ Horizontal Indicate the stack opening and size: (check one) ® Circular ❑ Square/Rectangle ❑ Other (describe): 0 Upward with obstructing raincap Interior stack diameter (inches): Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate 100°6 Load (SCF/ hour•) Actual Annual Fuel Use (MMSCF/ year,) Requested Annual Permit Limit '. (MMSCF'/year) _ 11393.28 99.81 From what year is the actual annual amount? Indicate the type of fuel used8: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ® Field Natural Gas Heating value: 1000 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTUlscf) ❑ Landfill Gas Heating value: BTU/scf ❑ Other (describe): Heating value (give units): 'Requested values will become permit limitations. Requested limits) should consider future process growth. 8If fuel. heating value is different than the listed assumed value, provide this information in the "Other" field. o«saa.r,n Form APCD-2O.1 Permit Number: AIRS ID Number: {000 [Leave blank unless APCD has already assigned a permit ' and AIRS ID] Section 7 - Emission 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? ►:� Yes [] No if yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emis;iags) TSP (PM) PMau PhiLs SOx NOx VOC CO t ) Et AFRC 58,848 Other: Formaldehyde - NSCR £t AFRC 014 Cry 5O 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? Criteria Pollutant Emissions Inventory Pollutant Emission Factor ` Actual Annual Emissions9 ' R questedAnnual Emission ,Permit Limit(s)� Controlled Emissions (Tons /year) UncontrolledUnits Basis Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions ,. (Tons/year) Uncontrolled, Emissions . .. (Tons/year) TSP (PM) PMio 0.0099871 lb/rnmetu AP -42 0.54329 0.54329 PM2.5 0.0099871 Ib/mmBtu AP -42 0.54329 0.54329 SOx 0.000588 lb/mmBtu AP -42 0.03199 0,03199 NOx 0.7 g/hp•hr Mfg/Reg 7/JJJJ 9.32798 9.32798 VOC 0.7 glhp•hr Mfg/Reg 7/JJJJ 9.32798 9.32798 CO 2,43 g/hp•hr Mfg/Reg7/JJJJ 32.38143 13.32569 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?21 Yes 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 Emissions9 Uncontrolled Basis Units Source (AP -42, . ( Mfg, etc) Uncontrolled Emissions Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0,43 g/hp-hr Mfg. 11460 5730 Acetaldehyde 75O7O 0.0084 lb/AVASTU AP -42 834 834 Acrolein 107028 0.0051 lb/MMBTU AP -42 513 513 Benzene 71432 Other: 7Requested values will become permit limitations. Requested limits) should consider future process growth. 'Annual emissions fees will be based on actual controlled em'ssions reported. if source has not yet started operating, leave blank. '' 5 Permit Number: AIRS ID Number: / 009 [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, 1 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. Via07/09/2018 Signalt� Bally Authorized P (not a vendor or consultant) Date Gabriela Vega Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: ® Draft permit prior to issuance ® Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No, 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 (if applying for GP02 For more information or assistance call: submit with an additional $1500), 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 APCD website at: Make check payable to: https://www.cotorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 f' _.,n APCD.20.f C ribus ._`4 1_' :•' -,PE i . _..:6 l colocl,Uo 6 Produced Water Storage Tank(s) APEN - Form APCD-207 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 on additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store produced water associated with oil, and gas industry operations. If your emission source doesnot fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, condensate storage tanks, hydrocarbon liquid loading, etc:). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.eov/pacific/cdrihe/air-permits. This emission notice is valid for five (5) yearn. 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: lirt3E02.1 AIRS ID Number: 123 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 Administrative Information Company Name1: Noble Energy, Inc. Site Name: LC22-A ECONODE Site Location: NWNE SEC22 TORN R59W Mailing Address: (Include ZIP code) 1625 Broadway, Suite 2200, Denver CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Gabriela Vega Phone Number: 303-228-4475 E -Mail Address2: Gabriela,Vegga@nbienergy,com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that wilt appear on all documents issued by the APCD; Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices wilt be issued by APCD via a -mail to the address provided. COLORADO Form APCD-207 - Produced Water Storage Tanks) APEN - Revision 02/2017 Permit Number: AIRS ID Number: 123 / 7 TBD [Leave blank unless ARCD has already assigned a permit itt and AIRS ID] Section 2 - Requested Action D NEW permit OR newly -reported emission source p Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP05 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. - OR - O MODIFICATION to existing permit (check each box below that applies) O Change in equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit exempt/grandfathered source Additional Info a 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: Produced Water Storage For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 hours/day 7 Storage tank(s) located at: 12/11/2017 Q Exploration & Production (E&P) site days/week 52 weeks/year ❑ Midstream or Downstream (non E&P) site Will this equipment be operated in any NAAQS nonattainment area? ■ Yes O No Are Flash Emissions anticipated from these storage tanks? O Yes ■ No Are these storage tanks located at a commercial facility that accepts oil production wastewater for processing? Yes No II 0 Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? ® Yes ❑ No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No 0 O Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr. (per storage tank)? Yes No 0 ■ Form APCD-207 - Produced Water Storage Tanks) APEN • Revision 02/2017 2 I f ® COOR ADO n.n!irtrr.:e_.�:ae Permit Number: AIRS ID Number: 123 / I TBD [Leave blank unless APCD heas already assigned a permit # and AIRS IDI Section 4 - Storage Tank(s) information [ Produced Water Throughput: Actual Annual Amount (bbtlyear) 1,109,907 From what year is the actual annual amount? N/A Tank design: 0 Fixed. roof O Internal floating roof Requested Annual Permit Limit4 (bbtlyeor) I,)O`i,V©? { vr`04'I O External floating roof Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (monthlyear) 4 2000 12/2017 Wells Serviced by this Storage Tank or Tank Battery5 (E&P Sites On y) API Number Name of Well Newly Reported Well. 05 -123.429a BENELLI FEDERAL LC22-755 05 -123- 429E BENELLI FEDERAL LC22-760 ✓� 05 - 123- 429k BENELLI FEDERAL LC22-785 ✓O 05 - 123- 429$ DIAMONDBACK FEDERAL LC22-770 I 05 - 123- 429$ DUKES FEDERAL LC10-735 CI 4 Requested values wilt become permit limitations. Requested limit(s) should consider future growth. 5 The E&P Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (LatitudelLongitude or UTM) 40.7396, -103.9691 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. CT) Flow Rate (ACFhi) Velocity (ft/sec) Indicate the direction of the stack outlet (check one) ❑ Upward O Horizontal O. Downward ❑ Other (describe): Indicate the stack opening and size: (check one) O Circular o Square/ rectangle O Other (describe): O Upward with obstructing raincap Interior stack diameter (inches): interior stack width (inches): Interior stack depth "(inches): COLORADO Form APCO-207 Produced Water Storage Tank(s) APEN - Revision 02/2017 Permit Number: AIRS ID Number: 123 / I TBD [Leave `tank unless APCD has already assigned a permit It and AIRS ID] Section 6 - Control Device Information 0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: Make/Model: VRU Downtime or Bypassed (emissions vented): ❑ Combustion Device: Pollutants Controlled: Rating: MMBtu/hr Type: Enclosed Burner Make/Model: Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 95 Minimum Temperature: Waste Gas Heat Content: Constant Pilot Light ❑✓ Yes ❑ No Pilot. Burner Rating: I 1 ggte Btu/scf MMBtu/hr ❑ Closed Loop System Description of the dosed loop system: O Other: Pollutants Controlled: Description: Control Efficiency Requested.: Section 7 -Gas/Liquids Separation Technology information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 40 psig Describe the separation process between the welt and the storage tanks: Liquids from well to HP separator, then to LP separator, then produced water to the produced water storage tanks. LCto 8004 Form APCD-207 -'Produced Water Storage Tankisi APEFI - Revision 02/2017 Permit Number: AIRS ID Number: 123 t 1 TBD ye blank unless APCO has already assigned a permit -II- and AIRS 10] Section 8 - Emissions inventory Information Attach alt emissions calculations and emission factor documentation to this APEN form6. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall ( Benzene Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) VOC Enclosed Butner 95 NCx - Co HAPs Other: Benzene: N -Hexane 95 From what year is the following reported actual annual emissions data? N/A Pollutant Criteria Pollutant Emissions Inventory Emission Factors Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled Basis.. Units Source (AP -42, Mfg, etc) Uncontrolled Emissions (fonslyear) Controlled Emissions? irons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tonslyear) vac. No, 02620 co Ify, ib/BBL CDPHE AP -42- 145.4 A 7.27 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Abstract Service (CAS) Number Emission Factor° Actual Annual Emissions Uncontrolled Basis Unit; Source (AP -42,' Mfg. etc) Uncontrolled Emissions (Poundslyear) Controlled Emissions? (Poundslyear) 71432 0;007 1b/BBL CDPHE 7769 388 Toluene 108883 Ethylbenzene Xylene 100414 1330207 n -Hexane 110543 0.022 ib/BBL CDPHE 24418 1221 2,2,4- Trimethylpentane 540841 4 Requested values willbecomepermit limitations. Requested limit(s) should consider future growth. 6 Attach produced water laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 7 Annual emissions fees will be based on actual controlled emissions reported. if source has not yet started operating, leave blank, Form APCD-207 - Produced Water Storage Tank(sl APEN - Revision 02/2017 5 i V ra o;a Sao . _ Permit Number: AIRS ID Number: 123 I / TBD [Leave blank unless APCD has already assigned a permit and AIRS lot Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP05 or GP08, I further certify that this source is and wit be operated iqfull compliance with each condition of the applicable General Permit. 5/8/2018 gnature of Legally AuthorizedPcrson (not a vendor or consultant) Gabriela Vega`' Environmental Engineer Date Name (print) Title Check the appropriate box to request a copy of the: ✓� Draft permit prior to issuance El Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, ii.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control. Division APCD-SS-Bi 4300 Cherry Creek Drive South Denver, CO 80246-153O For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692.3148 Or visit the APCD website at: _ Make check payable to: https://www.colorado.gov/cdphe/aped Colorado Department of Public Health and Environment Telephone:. (303) 692-3150 Form APCD-207 Produced Water Storage Tank(si APEN - Revision 02/2017 �� COLORADO Hydrocarbon Liquid Loading APEN - Form APCD-208 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 inay 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 Hydrocarbon Liquid Loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options wilt not satisfy your reporting needs. A list of alt available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.cotorado.gov/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: V 02-141 [Leave blank unless APCD has already assigned a permit # and AIRS 10] Company equipment Identification: TLC AIRS ID Number: 123 / F 1 / B (Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Noble Energy, Inc. Site Name: LC22-A Econode Site Location: Mailing Address: Site Location NWNE SEC22 TO9N R59W County: Weld (lnclUde Zip Code) 1625 Broadway, Suite 2200,. Denver CO 80202 E Mail Address: Gabriela.Vega@nblenergy.com NAICS or SIC Code: 1311 Permit Contact: Gabriela Vega Phone Number:. 303-228-4475 1Use.the full, legal company name registered with the Colorado Secretary of State. This is the company name that wilt appear on all documents issued by the APCD. Any changes will require additional paperwork 2 Permits, exemption €etters, andany processinginvoices will be issued by APCD via e-mail to the address provided. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev. 02/2017 1 I AyCr:it,Olisi,,D.17 N?dSir4 iprattx-+ Permit Number: AIRS ID Number: 123/ 7 TBD [Leave blank unless APCD has already assigned a permit u and AIRS ID] Section 2- Requested Action O NEW permit OR newly -reported emission source 0 Request coverage under construction permit ❑ Request coverage under General. Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN Filing fee. -OR- ❑ MODIFICATION to existing permit (check each bar below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership3 O Other (describe below) OR ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADOmoNAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Truck load -out of condensate For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 12/ 09 /2017 / / 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? Does this source load gasoline into transport vehicles? Is this source located at an oil and gas exploration and production site? If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Does this source splash fill less than 6750 BBL of condensate per year? Does this source submerge fill less than 16308 BBL of condensate per year? Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 2 I ❑ Yes L1 No ❑ Yes (] No ❑ Yes 0 No ❑ Yes ❑ No ❑ Yes Q No ❑ Yes EJ No ❑ Yes El No ,� COLORADO �,:'� Permit Number: AIRS ID Number: 123 / I TBD [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: Condensate ❑ Crude Oit ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded4: 170,765 Bbt/yr Actual Volume Loaded: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth This product is loaded from tanks at this facility into: Tank trucks (eg, "rail tank cars" or "tank trucks") If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: 0.6 Average temperature of bulk liquid loading: 52.45 <F True Vapor Pressure 3.3552 Psia @ bQ •F Molecular weight of displaced vapors 6 V Lb/lb mot If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: Bbl/yr Actual Volume Loaded: Bbl/yr 4 Requested values will become permit limitations. Requested limits) should consider future process growth Product Density: Lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume ft'/truckload Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 3 I AV COLORADO Permit Number: AIRS ID Number: 1231 / TBD (Leave blank unless APCD has already assigneda permit # and AIRS ID} Section 5 - Geographical Information Geographical Coordinates (Latitude/Longitude or UTM) 40.7396, -103.9691 Operator . •Stack ID No, Discharge Height l Above Ground Lev_e! = (Feet) Temp. (.F) Flow Rate (AcFM)' Velocity (f₹isec) Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward withobstructing raincap Section 6 - Control Device Information ❑ Loading occurs using a vapor balance system: Requested Control Efficiency ❑ Combustion Device: Pollutants Controlled: Rating: MMBtu/hr Type: Enclosed Burner Make/Model: Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency Minimum Temperature: 95 % Waste Gas Heat Content Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating Btu/scf MMBtu/ hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLOR ADO 4I � PM Permit Number: AIRS ID Number: 123/ /TBD [Leave blank unless ARCD has already assigned a permit " and AIRS ID] Section 7 Criteria Pollutant Emissions information Attach ail emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? Q Yes 0 No If yesdescribe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions). PM SOX NO„ CO VOC Enclosed Burner 95 HAPs Enclosed Burner 95 Other: ❑ Using State Emission Factors (Required for GP07) VOC Condensate 0 Crude Benzene n -Hexane 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 .bs/BBL 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? N/A Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Annual Emissions Requested Annual Permit Emission: Limit(s)s. Uncontrolled, (Tans/year) Controlled5 (Tons/year) Uncontrolled (Tons/year) controlled. (Tonslyear) SOX NO, VOC 0.1398 Ib/bbl Hysys 11.94 O:60 CO Benzene Toluene Ethytbenzene Xylenes n -Hexane 0,001 ib/bbl AP -42 31O _ 2,2,4- Trimethytpentane Other: 4Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees wilt be based on actual controlled emissions reported If source has not yet started operating, leave blank. Form APCD-208' -Hydrocarbon. Liquid Loading APEN - Rev 02/2017 • t ccLottxoo Permit Number: AIRS ID Number: 123/ / TBD [Leave blank unless APCD has already assigned a permit k 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 GP07, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. 05/08/2018 Signature of Legally Au Gabriela Vega horiz Person (not a vendor or consultant) Date Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, changein fuel type, etc). See Regulation No. 3, Part: A, II.C. for revised APEN requirements. Send this form along with S152.90 and the General Permit registration fee of $250 as 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/aped Form APCD-208 -Hydrocarbon Liquid Loading APEN - Ray 02/20.17 Avcy COLORADO- Condensate Storage Tank(s) APEN - Form APCD-205 Air Pollutant Emission Notice (ADEN) and Application for Construction Permit Alt sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc. ). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options wilt not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.cotorado.govfpacific/cdphefair-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, iI.C. for revised APEN requirements.. Permit Number: AIRS ID Number: 123 Ai F' lr, l 0 [Leave blank unless APCD has already assigned a permit h' and AIRS ID] Section"! - Administrative Information company Name1: Noble Energy, Inc. Site Name: LC22-A ECONODE Site Location: NWNE SEC22 T09N R59W Mailing Address: (include Zip Code) 625 Broadway, Suite 2200, Denver CO 80202. Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Gabriela Vega Phone Number: 303-228-4475 E -Mail Address? GabrielaNegaanblenergy.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 a -mail to the address provided. Form APC.D-205. Condensate Storage Tank(s) APEN - Revision 07/2017 C06Aaaoo l c r2. i Permit Number: AIRS ID Number: 123 / / TBD [Leave blank unless APCO has already assigned a permit # and AIRS ID] Section 2 - Requested Action Q NEW permit OR newly -reported emission source 0 Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP01 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $25O must be submitted along with the APEN filing fee. -OR - ❑ MODIFICATION to existing permit (check each bac below that, applies) ❑ Change in equipment 0 Change company name ❑ Change permit limit ❑ Transfer of ownership3 0 Other (describe below) OR ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info 6t 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: Condensate Tanks For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 12/2017 hours/day 7 days/week 52 Storage tank(s) located at: (] Exploration a Production (EDP) site weeks/year 0 Midstream or Downstream (non E&P) site Will this equipment be operated in any NAAQS nonattainment area? ■ Yes O No Are Flash Emissions anticipated from these storage tanks? ID Yes ■ No Is the actual annual average hydrocarbon liquid throughput a 500 bbl/day? ■ Yes IS No If "yes", identify the stock tank gas -to -oil ratio: m3/titer Are these storage: tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes ® No • Are you requesting a 6 ton/yrVOC emissions (per storage tank), or are uncontrolled actual emissions a 6 ton/yr (per storage tank)? yes. ❑ No O Form APCD-205 - Condensate Storage Tanks) APEN - Revision 07/2017 �YCOLORADO ❑ Upward [] Horizontal Permit Number: AIRS ID Number: 123 / / TBD [Leave blank unless APC4 has already assigned a perrr.:t fl and AIRS iii] Section 4 Storage Tank(s) Information Condensate Throughput: Actual Annual Amount (bbl/year) 1,800,000 Requested Annual Permit Lintit4 Obit year) From what year is the actual annual amount? Average API gravity of sates oil: 58.7 degrees ❑ Internal floating roof Tank design: 0 Fixed roof RVP of sates oil: 6.364 Q External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) 12 e- 12/09/2017 Wells Serviced by this Storage Tank or Tank Battery5 (E&P Sites Ony) API Number Name of Well Newly Reported Well 05 - 123 - 42973 BENELLI FEDERAL LC22-755 0 05 - 123 - 42977 BENELLI FEDERAL LC22-760 0 05 - 123 - 42975 BENELLI FEDERAL LC22-765 rA 05 - 123 - 42970 DIAMONDBACK FEDERAL LC22-770 0 05 - 123 - 42982 DUKES FEDERAL LC10-735 2 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The E&P Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 Stack Information Geographical Coordinates (Latitudeltongitude or UTM) 40.7396, -103.9691 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ftlsec) indicate the direction of the stack outlet: (riled( one) Q Downward O.0ther (describe): Indicate the stack opening and size: (check me) ❑ Circular [I Square/rectangle ❑ Other (describe) 0 Upward with obstructing raincap interior stack diameter (inches): Interior stack width (inches): interiorstackdepth (inches): Form APCD-2O5 Condensate Storage Tanlci.s APEN - ReAsion 07/2017 cacao sao 3 l Permit Number: AIRS ID Number: 123 / / TBD (Leave blank untess APCD has a'ready assigned a permit # and AIRS 101 Section 6 Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor El Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: Combustion Device: Pollutants Controlled: Rating: MMatu/hr Type: Enclosed Burner Make/Model: Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 95 Minimum Temperature: Waste Gas Heat Content: •269, Btu/scf Constant Pilot Light: ❑r Yes 0 No Pilot Burner Rating:. MMBtu/hr 0 Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: % Section 7 Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 12 psig Describe the separation process between the well and the storage tanks: Liquids from well to HP separator, then to LP separator. Liquids from LP separator then to VRT. VRT liquids to tanks. Form APCD-205 - Condensate Storage Tank's) APEN - Revision 07/2017 COLORADO 4 I to ,:., Permit Number: AIRS ID Number: 123 ! l TBD ve blank unless APC0 has already assigned a permit # and AIRS iO Section 8 - Emissions inventory information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency l% reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions). VOC Enclosed Sinner 95 NOx Co HAPs Enclosed Burner 95 Other: From what year is the following reported actual annual emissions data? Criteria.. Pollutant Emissions Inventory Pollutant Emission Factor' Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled Basis VOC NOx CO Units lbfbbi Uncontrolled Emissions (ronslyear) Hysys Controlled Emissions lTanslyeor) Uncontrolled Controlled Emissions Emissions (Tons/year) (rms./year) 1, Lfg I Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor6 Actual Annual Emissions Uncantro#led Basis Units Source '(AP -42,- Mfg, etc) ) Uncontrolled Emissions ,: (Pounds/year) Controlled Emissions x (FoundsJyLar); Benzene 71432 t- lb/bbl Hysys 9't Toluene 108883 ' Ib/bbl Hysys brIZ. 49 Ethyibenzene 100414 1. (tft} li Xylene 1330207 1_j i*t / I n -Hexane 110543 60:)2,c1 Ib/bbi Hysys f i481 X& Trimethylpentane 540841 ' IbfbbI Hysys act 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 4 Attach condensate liquid laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. T Annual emissions fees wilt be based on actual controlled emissions reported. If source has not yet started operating, leave blank: Form APCD-205 Condensate Storage Tank(s) APEN - Revision 07/2017 Ayea aR as a Permit Number: AIRS ID Number: 123 / / TBD [Leave blank unless APCD has already assigned a permit P, and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that this source is and w/ilk be operated in full compliance with each condition of the applicable General Permit. 518/18 Signature of Legally Arfthor/ized Person (not a vendor or consultant) Date Gabriela Vega Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance ID Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No: 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, Co 80246-1530 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/cdohe/apcd Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 Awt COLORADC Received 8/24/18 Natural Gas Venting APEN — Form APCD-211 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this ADEN 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 Gras 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,govicdohe/aocd. 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. 0( Permit Number: I y u 021 AIRS ID Number:. 123 /qF / [Leave blank unless APCD has already assigned a permit it and AIRS ID] Company equipment Identification: LC22 A - VRT&LP [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 Administrative Information Company Name': Site Name: Site Location: Noble Energy, Inc. LC22-A & B ECONODE Site Location SEC22 T09N R59W county: Weld Mailing Address: 1625 Broadway, Suite 2200 (Include Zip code) NAICS or SIC Code: 1311 Denver CO 80202 Permit Contact: Gabriela Vega Phone Number: 303-228-4475 E Mail Address': gabriela.vega@nblenergy.com 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on alt 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. 0105500 form APCD-205 - Natural Gas Venting APEN - Rev 03/2017 1 I 3S14144- Permit Number: AIRS ID Number: 123 r rTBD [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 0 Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) OR ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 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: VRT & LP Streams at the LC22A For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 12 / 09 / 2017 / / O Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 24 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-2O5 -Natural Gas Venting APEN Rev 03.2017 7 days/week ❑ Yes ❑ Yes 52 weeks/year El No o No f OLOR Aaa 2 Permit Number: AIRS ID Number: 123 / / TB D [Leave blank unless APCD has already assigned a permit f; and AIRS ID] Section 4 - Process Equipment Information D Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: ❑ Other Description: Serial #: Capacity: Gal/min # of Pistons: Leak Rate: Scf/hr/pist Volume per event: MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? [] Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: 801 SCF/hr Vent Gas Heating Value: 2648 BTU/SCF Requested: 7.015 MMSCF/year Actual: MMSCF/year -OR- Requested: Bbt/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 %) 76.05 V0C (Weight %) 85,73 Benzene (mole %) 0.16 Benzene (Weight %) 0.27 Toluene (mole %) 0.08 Toluene (Weight %) 0.16 Ethylbenzene (mole %) 0.02 Ethylbenzene (Weight %) 0.05 Xylene (mole %) 0 03 Xylene (Weight %) 0.08 n -Hexane (mole %) 1.04 n -Hexane (Weight %) 1.9 2,2,4-Trimethylpentane (mole %) 0.01 2,2,4 7rimethylpentane (weight%) 0.02 Additional Required Information: El Attach a representative gas analysis (including BTEX li 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 0312017 31 :COLORADO : Ne��.a• ar rA�,e aj�� _ ❑ Upward ❑ Horizontal Permit Number: AIRS ID Number: 123 / / TB D [Leave blank unless APCD has already assigned a permit # and AiPS IDI Section 5 - Stack Information Geographical Coordinates (LtrtitudeiLangitude or.UTM) 40.7381 , -103.9692 Oper; [or Stack ID No -, Discharge- Height Above Ground Level deer). Temp ( F} k FIovQ Rate )ACFM) Y locityr (fr/see) Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): O Upward with obstructing raincap Section 6 - Control Device Information O VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed ❑ Combustion r Device: Pollutants Controlled: VOC, Benzene, Hexane, Toluene, Xylenes, 224-Mpentane Rating: MMBtu/hr Type: VOC Burner Make/Model: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: 95% Waste Gas Heat Content Constant Pilot Light: O Yes O No Pilot burner Rating Btu/scf MMBtu/ hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested 0 Form APCD-205 -Natural Gas Venting APEN Rev 03;20`7 coioexnn 4 Permit Number: AIRS ID Number: 123 / / TB D [Leave blank unless APCD has already assigned a permit // and AiRS 1D) 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? El Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Pollutant .. Control Equipment Description Overall Requested Control Efficiency (% reduction iit emissions) PM SOS No. VOC VOC Burner 95% CO HAPs VOC Burner 95% Other: From what year is the following reported actual annual emissions data? N/A Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission _,Factor Emission Factor `. : Units Emission Factor Source (e.41 'Mfq: etc)( requested' -.014 Permit Errtissibn t;1mit(sjs : n _ ��4 Actua•l AnnUal - Emissions '- ` Uncontrolled ' (Tans/year) Controlled'', (Tonslyear) `+ Uncontrolled (Tonslyear) ._ ;Controlled.' (Tonsly"eor) PM 7.60 Ib/mmscf HYSYS/AP42 0.00 0.00 SO,, 0.60 Ib/mmscf HYSYS/AP42 0.00 0.00 NO), 0.068 Ib/MMscf HYSYS/AP42 0.668 0.668 VOC 106.899 lb/mscf HYSYS/AP42 374.94 18.75 CO 0.310 lb/MMscf HYSYS/AP42 2.91 2.91 Benzene 0.3310 lb/mscf HYSYS/AP42 1.16 0.06 Toluene 0.2029 lb/mscf HYSYS/AP42 0.71 0.04 Ethylbenzene 0.0605 lb/mscf HYSYS/AP42 0.21 0.01 Xytenes 0.0947 lb/mscf HYSYS/AP42 0.33 0.02 n -Hexane 2.3724 lb/mscf HYSYS/AP42 8.32 0.42 2,2,4 Trimethytpentane 0.0302 lb/mscf HYSYS/AP42 0.11 0.01 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 APC0-205 Natural Gas Venting APEN Rev 03/2017 5 I A COLORADO '• padaalalit1•Jx Permit Number: AIRS ID Number: 123 / / TBD [Leave blank unless APCD has already assigned a permit and AIRS ID[ Section 8 - Applicant Certification I hereby certify that alt information contained herein and information submitted with this application is complete, true and cord ect. 8/24/2018 Signature of Legally Authorized Pern (not avendor or consultant) Date Gabriela Vega Environmental Engineer 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-S5-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-205 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 co�oanao Reciprocating Internal Combustion Engine APEN - Form APCD-2O1 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.Rov/cdohe /a pcd. 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: 12,s/ / ei7 [Leave blank unless A CD has already assigned a permit ff and AIRS ID] Section 1 - Administrative Information Company Name' Site Name: Site Location: Noble Energy Inc. LC22 - B ECONODE T9N-R59W-S22 L01 Mailing Address: (Include Zip Code) 1625 Broadway, Suite 2200 Denver, CO 80202 Permit Contact: Gabriela Vega Phone Number: (303) 228-4475 Portable Source E -Mail Address? Home Base: Gabrieta.Vega@nblenergy.com Site Location County: Weld NAICS or SIC Code: 1311 '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. 377820 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 1 ] Permit Number: GPM 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 l Request coverage under General Permit GP023 (Natural Gas Only) If coverage under General Permit GPOZ is requested, an additional fee of $1,500.00 is required in lieu of hourly fees. 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 (Blank APENs will not be accepted) - Additional Permit Actions - El APEN submittal for permit-exemptlgrandfathered source • Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info & Notes: 3only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. "For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5GP02 fee is not required, but APEN filing fee is required. Section 3 General Information Does this engine have a Company Equipment identification No. (e.g. ENG-1, Engine 3, etc)? Yes 1f yes, provide the Company Equipment Identification No. ENG-R6S00892 General description of equipment and purpose: Compression Engine For existing sources, operation began on: 01/12/2018 For new or reconstructed sources, the projected start-up date is: Witt this equipment be operated in any NAAQS nonattainment area? ❑ Yes No (http://www.cotorado.gov/ccipheiattainmenti 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 11/2016 2 I 0 00 Permit Number: GPQ2 AIRS ID Number: j [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump O Water Pump ❑ Emergency Back -Up ❑ Other: ® Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Caterpillar Engine Model: G3306 NA Serial Number6: R6S00892 hours/year What is the maximum designed horsepower rating? 145 hp What is the engine displacement? What is the maximum manufacturer's site -rating? 145 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8625 BTU/hp-hr Engine Features: Cycle Type: O 2 -Stroke ►:i 4 -Stroke Ignition Source: ® Spark O Compression Aspiration: Natural O Turbocharged Combustion: O Lean Burn ® Rich Burn ►�I Is this engine equipped with an Air/Fuel ratio controller (AFRC)? Yes O No If yes, what type of AFRC is in use? ® O2 Sensor (mV) O NOx Sensor (ppm) O Other: Is this engine equipped with a Low-NOx design? O Yes ❑ No Engine Dates: What is the manufactured date of this engine? 06/26/2013 What date was this engine ordered? 1/cyl What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? O Yes O No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: °The serial number must be submitted if coverage under GP02 is requested. Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 Permit Number: GP02 AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographic• al Coordinates tttude/Langitude or UTM) (La 40.7381/-103.9692 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp, ('f) Flow Rate (ACFM) Velocity (ft/sec); Indicate the direction of the Stack outlet: (check one) Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ►4 Circular Interior stack diameter (inches): 0 Upward with obstructing raincap ❑ Square/Rectangle Interior stack diameter (inches): Interior stack depth (inches): ❑ Other (describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load (SCF/ hour) Actual Annual Fuel Use (MMSCFl year) Requested Annual Permit Limit? (MMSCF/ year) 1250.63 10.96 From what year is the actual annual amount? Indicate the type of fuel used8: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑ Field Natural Gas Heating value: 1000 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTUIscf) ❑ Landfill Gas Heating value: BTU/scf ❑ Other (describe): Heating value (give units): 'Requested values wilt become permit limitations. Requested limit(s) should consider future process growth. 81f 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 11/2016 4 Permit Number: GP02 AIRS ID Number: [Leave blank unless APCD has already assigned a permit i= and AIRS ID] Section 7 - Emission 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 O No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (96 reduction in emissions) TSP (PM) PM10 PM2.5 SOx NOx NSCR Et AFRC 6 ci 9-2:5 ( aoi VOC CO NSCR Et AFRC 85.152 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? TSP (PM) PM10 PM2.5 Uncontrolled Basis 0.01941 Criteria Pollutant Emissions Inventory Emission Factor lb/mmBtu Source (AP -42, Mfg. etc) AP -42 Actual Annual Emissions9 Uncontrolled Emissions (Tonslyear) Controlled Emissions (Tons/year) Requested Annual Permit Emission Limit(s)7 Uncontrolled Emissions (Tons/year) 0.10632 Controlled Emissions (Tons/year) 0,10632 0.10632 0.01941 Ib/mmBtu AP -42 0.10632 SOx NOx VOC 0.000588 ib/mmBtu AP -42 0.00322 0.00322 4:4%440.3 0.98011 13.47 0.7 g/hp•hr g/hp•hr g/hp•hr Mfg/Reg 7/JJJJ Mfg/Reg 7/JJJJ 18.8602 0.98011 CO 13.47 Mfg/Reg 7/JJJJ 18.8602 2.80033 Does the emissions source have any uncontrolled actual emissions of non -criteria ® yes ❑ No 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: 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 0.27 g/hp-hr Mfg. 756 756 Acetaldehyde 75070 Acrolein 107028 Benzene 71432 Other: 'Requested values will became permit limitations. Requested iimit(s) should consider future process growth. 'Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Oft ADO Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11 /2016 5 I Name (please print) Permit Number: GPQ2 AIRS ID Number: [Leave blank unless APCD has already assigned a permit It 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 wil,l be operated in full compliance yIith each condition of general permit GP02. 04/05/2018 ignature of Legally Authorized Pers of a vendor or consultant) Date Gabriela Vega Environmental Engineer Title Check the appropriate box to request a copy of the: Draft permit prior to issuance ® Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 (if applying for GP02 submit with an additional $1500), 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 APCD website at: https: //www.cotorado.gov/cdphe/apcd Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 6 Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit Alt 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.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, I1.C. for revised APEN requirements. Permit Number: GPO2, I VJEQZ G1 AIRS ID Number: 12.S / el FAT I aie [Leave blank unless APCD has already assigned a permit N and AIRS ID] Section 1 - Administrative Information Company Namet: Site Name: Site Location: Mailing Address: (Include Zrp Code) Portable Source Home Base: Noble Energy Inc. LC22 - B ECONODE T9N-R59W-522 L01 1625 Broadway, Suite 2200 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Phone Number: E -Mail Address2: Gabriela Vega (303) 228-4475 Gabriela.Vega@ribtenergy.com 'Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that wilt 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. 377821 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 4 IA Permit Number: GP02 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 YAA 0A1 -k Request coverage under a Construction Permit Request coverage under General Permit GP023 (Natural Gas Only) If coverage under General Permit GP02 is requested, an additional fee of $1,500.00 is required in lieu of hourly fees. - OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name O Add point to existing permit ❑ Change permit limit O Transfer of ownership4 O Other (describe below) - OR - O 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 a Notes: 3Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. °For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. °OP02 fee is not required, but APEN filing fee is required. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? If yes, provide the Company Equipment Identification No. ENG-R6S03102 Yes General description of equipment and purpose: Compression Engine For existing sources, operation began on: 01 /12/2018 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? O Yes ® No (http: //www.colorado.gov/cdphe/attainment) 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 Farm APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 2 Permit Number: GPO2 AIRS ID Number: [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking 0 Pump 0 Water Pump ❑ Emergency Back -Up 0 Other: ►SS Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Caterpillar Engine Model: G3306 NA Serial Number6: hours/year R6S03102 What is the maximum designed horsepower rating? 145 hp What is the engine displacement? What is the maximum manufacturer's site -rating? 145 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8625 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke 4 4 -Stroke Ignition Source: ►i4 Spark 0 Compression Aspiration: Combustion: 0 Lean Burn ►4 Rich Burn k1 V cyl Natural O Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? El Yes 0 No If yes, what type of AFRO is in use? ►'t OZ Sensor (mV) 0 NOx Sensor (ppm) 0 Other: Is this engine equipped with a Low-NOx design? 0 Yes ❑ No Engine Dates: What is the manufactured date of this engine? 06/17/2014 What date was this engine ordered? What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? 0 Yes ❑ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: 6The serial number must be submitted if coverage under GP02'is requested. Serial Number: APCD-201 - Reciprocating internal Combustion Engine APEN - Revision 11/2016 3 Permit Number: GP02 AIRS iD Number: / / [Leave blank unless APCO has already assigned a permit # and AIRS ID] Section 5 - Stack. Information Geographical Coordinates (Lotitude/Longitude or UTM) 40.7381/-103.9692 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. ('F) Flow Rate (ACFM) Velocity (fttsec) Indicate the direction of the Stack outlet: (check one) ►�/ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): indicate the stack opening and size: (check one) Circular ❑ Square/Rectangle ❑ Other (describe): 0 Upward with obstructing raincap Interior stack diameter (inches): Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate a 100% Load (SCF l hour) '' Actual Annual Fuel Use (MMSCFI year) Requested Annual Permit Limit' (MMSCFI year) 1250.63 1O.96 From what year is the actual annual amount? Indicate the type of fuel used$:. ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTUIscf) in Field Natural Gas Heating value: 1000 BTU/scf ❑ Propane {assumed fuel heating value of 2,300 BTUIscf) ❑ Landfill Gas Heating value: BTU/scf ❑ Other (describe): Heating value (give units): 'Requested values wilt become permit limitations. Requested limit(s) should consider future process growth. 8If 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 11/2016 4 Permit Number: X102 AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emission 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? 0 Yes 0 No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant TSP (PM) PMio PM2.5 Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) Sox NOx VOC NSCR Et AFRC CO NSCR a AFRC 85.152 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? Criteria Pollutant Emissions Inventory Pollutant.. TSP (PM) PMio PM2.5 Emission Factor Uncontrolled Basis 0.01941 ibfmmBtu Source (AP -42, Mfg. etc) AP -42 Actual Annual Emissions9 Uncontrolled Emissions (Tons/yea?) Controlled Emissions `(Tonslyear) Requested Annual Permit Emission Limit(s)7 Uncontrolled Emissions (Tons/year) 0.10632 Controlled Emissions" (Tonss%year) ' 0.10632 0.10632 0,01941 1b/mmBtu AP -42 0.10632 0.00322 SOx NOx VOC 0.000588 lb/mmBtu AP -42 0.00322 13.47 g/hp•hr g/hp•hr g/hp•hr Mfg/Reg 7/JJJJ Mfg/Reg 7/JJJJ 18.8602 1.41.11110 U ' 0.7 0.98011 0.98011 CO 13.47 Mfg/Reg 7/JJJJ 18.8602. 2.80033 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? ® Yes Q No If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions inventory Formaldehyde Acetaldehyde Acrolein Chemical Abstract Service (CAS) Number 50000 75070 107028 71432 Uncontrolled Basis 0.27 Emission Factor 'Units'• g/hp-hr Source (AP -42, Mfg. etc) Mfg. Actual Annual Emissions9 Uncontrolled Emissions (Poundslyear) 756 Controlled Emissions (Pounds/year) 756 Benzene Other: 'Requested values will become permit limitations. Requested limit(s) should consider future process growth. 'Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. A6© Form APED -201- - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 5 Permit Number: GP02 AIRS ID Number: [Leave blank unless APCD has already assigned a permit n" and AIRS ID] / Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is ar}fi will be operated ip full compU ice with each condition of general permit GP02.. j Signature of Legally Authorize Per +n (not a vendor or consultant) Gabriela Vega Name (please print) Title 04/05/2018 Date Environmental Engineer 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) 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 (if applying for GP02 For more information or assistance call: submit with an additional $1500), 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 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit APCD website at: https://www.colorado.govicdphe/apcd AGO Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 11/2016 6 l Reciprocating Internal Combustion Engine APEN - Form APCD-2O1 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 notfall 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. Colo redo. gov/cdohe/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: Y U EO21 1 AIRS ID Number: [Leave blank unless APCD has already assigned a permit , and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: Noble Energy inc.. LC22 - B ECONODE T9N-R59W-522 L01 Mailing Address: (Include Zip Code) 1625 Broadway, Suite 2200 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Phone Number: E -Mail Address2: Gabriela Vega (303) 228-4475 Gabrieta.Vega@nbtenergy,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. 5Permits, exemption letters, and any processing invoices will be issued by APCD via email to the address provided.. 1 ,)_3 .,. .1.. i fi 3+ Permit Number: AIRS ID Number: [Leave blank, unless APCD has already assigned a permit # aad AIRS ID] Section 2 - Requested Action igi 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 coverage under General Permit GP02 is requested, an additional fee of 51,500.00 is required in Lieu of hourly fees. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment 0 Change company name 0 Add point to existing permit ❑ Change permit limit 0 Transfer of ownerships 0 Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - Additional Permit Actions - ID APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional info £t Notes: lOnly one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5GP02 fee is not required, but APEN filing fee is required. 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-N6W00251 General description of equipment and purpose: Compression Engine For existing sources, operation began on: 01/12/2018 For new or reconstructed sources, the projected start-up date is: Wilt this equipment be operated in any NAAQS nonattainment area? 0 Yes ® No (http: //www.cotorado.gov/cdphe/attainment) 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 ADO Permit Number: AIRS ID Number: I [Leave btanh unless APCD has already assigned a permit and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump 0 Water Pump ❑ Emergency Back -Up ❑ Other, ® Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: ' it Engine Model: 61351 (.Q r 1 Serial Number6: N6W00251 What is the maximum designed horsepower rating? 1380 hp What is the engine displacement? l/cyt What Is the maximum manufacturer's site -rating? 1380 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8256 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ® 4 -Stroke ignition Source: ® Spark 0 Compression Aspiration: ® Natural is this engine equipped with an Air/Fuel ratio controller (AFRC)? E Yes 0 No If yes, what type of AFRC is in use? ❑ Oz Sensor (mV) ® NOx Sensor (ppm) 0 is this engine equipped with a Cow-NOx design? ❑ Yes ❑ No Engine Dates: What is the manufactured date of this engine? 07/06/2017 What date was this engine ordered? hours/year Combustion: ►ar Lean Burn ❑ Rich Bum Turbocharged -IA of What is the date this engine was first located to Colorado? What is the date this engine was first placed In service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an ADS replacement engine? ❑ Yes ❑ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 'The serial number must be submitted if coverage under GP02 is requested. Fd m.APCD-20I 1?_�;.ti)i%a s l":',�' tt=1t-. �: , l Co 7t1_u.Ciim En.g.ige r,. al. ' tft ': it' TU��T IMtce 4an�;s 3 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit n and AIRS iDI Section 5 - Stack Information Geographical Coordinates (Latitude/to 'Longitude or,UTM1 40.7381/-103.9692 Operator Stack ID NO. Discharge. Height.: Above. Ground Level (feet) Temp CF)- Flow Rate (siCFM) Velocity (ft/sec) 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): 0 Upward with obstructing raincap Interior stack diameter (inches): Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate e:...100% Load (SCFlhour) Actual _ Annual Fuel Use : '' (MMSCF/year}- Requested •Annual Permit Limit? (MMSChlyear) 11393.28 99.81 From what year is the actual annual amount? Indicate the type of fuel useda: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTUIscf) ❑ Field Natural Gas Heating value: 1000 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 timit(s) should consider future process growth. elf fuel heating value is different than the listed assumed value, provide this information in the "Other" field. z.. I 1 .,' _.. 1 . 41 coLonaao Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit and AIRS1D) Section 7 - Emission 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? 0 Yes 0 No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.s SOx NOx VOC CO Oxidation Catalyst £t AFRC 58.848 Other: Formaldehyde - Oxidation Catalyst E AFRC 50 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? Criteria Pollutant Emissions Inventory Pollutant Emission Factor '' Actual Annual Emissions' Requested n Limitl;Permit, Emission urnit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tonslyear) Controlled - Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) PM10 0.0099871 Ib/mmBtu AP -42 0.49838 0.49838 PM2.5 0.0099871 Ib/mmBtu AP -42 0.49838 0.49838 SOx 0.000588 lb/mmBtu AP -42 0.02934 0.02934 NOx 0.7 g/hp-hr Mfg/Reg 7/JJJJ 9.32798 9.32798 VOC 0.7 g/hp•hr Mfg/Reg7/JJJJ 9.32798 9.32798 CO 2.43 g/hp•hr Mfg/Reg7/JJJJ 32.38143 13.32569 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: 0 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 0.43 glhp-hr Mfg. 11460 5730 Acetaldehyde 75070 0.0084 lb/MMBTU AP -42 834 834 Acrolein 107028 0.0051 lb/MMBTU AP -42 513 513 Benzene 71432 Other: 'Requested values will become permit limitations. Requested limits} should consider future process growth. 'Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Cr>toaAt,o 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, l further certify that this source is and wiop rated in fi lk-compliance 1ith each condition of general permit GPOZ. ti 07/09/2018 Signature of Legally Authorized Perso (not a vendcr or consultant) Date Gabriela Vega Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: ® Draft permit prior to issuance ® Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing'time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 (if applying for GP02 For more information or assistance call: submit with an additional $1500), 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 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit APCD website at: https: //www.colorado.gov/cdphe/aped 6 6 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-20O) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.cotorado.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/ear 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: 6 O2. K UJ E O21 AIRS iD Number IV) / 4Fkgi / 0 Z, (Leave blank unless APCD has already assigned a permit r+ and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: Noble Energy Inc. LC22 B ECONODE T9N-R59W-S22 L01 Mailing Address: (Include Zip Code) 1625 Broadway, Suite 2200 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Phone Number: E -Mail Address2: Gabrieta Vega (303) 228-4475 Sabriela. Vega®nblenergy,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 wilt require additional paperwork.. 7Permits, exemption letters, and any processing invoices wilt be issued by APCD via e-mail to the address provided. Re(Rt.Vai Of' rCq APCD-1.01 Combuitier En-.i;f-;'_ APEN Reviliion I /2 lb 1 Permit Number: GP02 AIRS ID Number: [Leave blank unless APCO has already assigned a permit I 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 coverage under General Permit GP02 is requested, an additional fee of $1,500.00 is required in lieu of hourly fees. - OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment 0 Change company name 0 Add point to existing permit ❑ Change permit limit 0 Transfer of ownership's ❑ 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 £t Notes: 3On1y one engine may be reported per APEN for GP02 coverage. Coverage under GP0Z is voluntary. ^For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5GP02 fee is not required, but APEN filing fee is required. 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-10CHMM503060026 General description of equipment and purpose: Compression Engine For existing sources, operation began on: 01/12/2018 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: / /www.cotorado.gov/cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 Seasonal use percentage: Dec_Feb: 25 ❑Yes ®No days/week 52 weeks/year Mar -May: 25 June_Aug: 25 Sept -Nov: 25 r `rra: c intern.al. cr... _vj ticil _ gin:_ ?E • R...;5'.3a? 11 231 6 2 O.O5A OO Permit Number: GP02 AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump O Water Pump ❑ Emergency Back -Up ❑ Other: ® Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: GM hours/year Engine Model: 5.7L Serial Numberb: 10CHMM503060026 What is the maximum designed horsepower rating? 92 hp What is the engine displacement? l/cyl What is the maximum manufacturer's site -rating? 92 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 900O BTU/hp-hr Engine Features: Cycle Type: O 2 -Stroke ® 4 -Stroke Combustion: O Lean Burn ® Rich Burn Ignition Source: ® Spark O Compression Aspiration: ® Natural ❑ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ® Yes ❑ No If yes, what type of AFRC is in use? ® O2 Sensor (mV) ❑ NOx Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOx design? O Yes O No Engine Dates: What is the manufactured date of this engine? 03/06/2015 What date was this engine ordered? What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? O Yes ❑ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 'The serial number must be submitted if coverage under GP02 is requested. Form APCD2,. • .p....i.J l.]F.i-i €i�,i Cc bus;ia ;4;E AP iiI i7_ .:in I i /20 J}A� K9lO!apQ `..ti." CIF ., ,:.. w 1., Permit Number: GP02 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit .11 and AIRS ID) Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or (1TM) 40.7381/-103.9692 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. p. F (''..) Flow ; Rate (ACFM) Velocity (ft/sec) Indicate the direction of the Stack outlet: (check one) ® Upward ❑ Horizontal. ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ® Circular ❑ Square/Rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load (SCE/hour) Actual Annual Fuel Use : (MMSCF/yearr Requested Annual Permit Limitz (MMSCF/ year) 828 7.25 From what year is the actual annual amount? Indicate the type of fuel used8: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) <zga' Field Natural Gas Heating value: 1000 BTU/scf D Propane (assumed fuel heating value of 2,300 BTUIscf) ❑ 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. 81f fuel heating value is different than the listed assumed value, provide this information in the "Other" field. DO i 1, 4 Permit Number: - GP02 AIRS ID Number: [Leave blank unless APCD has already assigned a permit H and AIRS ID] Section 7 - Emission Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PMio PM2.s SOx NOx NSCR Et AFRC 8G OrL-d1 voc CO NSCR & AFRC —5-674 —' 4ji , S 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? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions4 Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units - - Source (AP -42, - Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions - (Pons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) PMio 0.01941 Ib/mmBtu AP -42 0.07039 0.07039 PM2.s 0.01941 Ib/mmBtu AP -42 0.07039 0.07039 SOx 0.000588 lb/mmBtu AP -42 0.00213 0.00213 NOx 14 g/hp•hr Mfg/Reg 7/JJJJ 12.43731 0. 88837 VOC 0.7 g/hp-hr Mfg/Reg 71.111.1 0.62187 0.62187 CO 11 g/hp•hr Mfg/Reg 7/JJJJ 9.77217 1.77675 Does the emissions source have any uncontrolled actual emissions of non -criteria Yes ® No pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 ills/year? ❑ If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non Criteria Reportable Pollutant Emissions inventory Chemical. Name Chemical Abstract Service (CAS) Number - Emission Factor Actual Annual Emissions' Uncontroited Basis Units Source (AP -42, Mfg. etc) _ Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/war) Formaldehyde 50000 Acetaldehyde 75070 Acrolein 107028 Benzene 71432 Other: 'Requested values will become permit limitations. Requested limits) should consider future process growth. 'Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. r:, 5 Permit Number: GP02 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. 07/12/2018 Signature of Legally Aut Gabriela Vega Name (please print) zed Person (not a vendor or consultant) Date Environmental Engineer Title Check the appropriate box to request a copy of the: ® Draft permit prior to issuance ® Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 (if applying for GP02 For more information or assistance call: submit with an additional $1500), 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 F' I Cif Internal Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit APCD website at: https: //www.colorado.gov/cdphe/apcd APEN ._rl_'.on I1 )016 COLORADO 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 he 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: 011 AIRS ID Number: j ✓Ftrl / [Lave blank unless PLD has already assigned a permit h and AIRS ID] Section 1 - Administrative information Company Name: Site Name: Site Location: Noble Energy Inc. LC22 - B ECONODE T9N--R59W-522 L01 /viailing Address: (Include Zip Code) 1625 Broadway, Suite 2200 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Phone Number: E -Mail Address: Gabriela Vega (303) 228-4475 Gabriela.Vega@nblenergy.com 'Use the full, legal company name registered with the Colorado Secretary of State. This is thecompany 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. APCD ' i i'2M841 t _g, austO [ F! fit#v;i-nn?I; Permit Number: GP02 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 coverage under General Permit GP02 is requested, an additional fee of $1,500.00 is required in lieu of hourly fees. -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 ❑ Transfer of ownership4 0 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 & Notes: 'Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. "For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5GP02 fee is not required, but APEN filing fee is required. 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-10CHMM410150017 General description of equipment and purpose: Compression Engine For existing sources, operation began on: 01/12/2018 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? 0 Yes ® No (http: //www.colorado.qovicdpheiattainment) 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 0 Form A`•: D•3•0I Ro _ _ ..__.1 •PEd - 2 yi 'f I/2016 2 1 Permit Number: GP02 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump O Water Pump ❑ Emergency Back -Up ❑ Other: ® Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: GM hours/year Engine Model; 5.7L Serial Number(); 10CHMM410150017 What is the maximum designed horsepower rating? 92 hp What is the engine displacement? t/cyt What is the maximum manufacturer's site -rating? 92 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 9000 BTU/hp-hr Engine Features: Cycle Type: O 2 -Stroke ® 4 -Stroke Combustion: O Lean Burn ® Rich Burn Ignition Source: ® Spark O Compression Aspiration: ® Natural ❑ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ® Yes O No If yes, what type of AFRC is in use? ® 02 Sensor (mV) O NOx Sensor (ppm) O Other: Is this engine equipped with a Low-NOx design? O Yes O No Engine Dates: What is the manufactured date of this engine? 10/15/2014 What date was this engine ordered? What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? O Yes O No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6The serial number must be submitted if coverage under GP02 is requested. Form PC ti -n, 'iP nrnaiCo?lt..i; io[ Engine A?Ei' Revision 1112016 C0tO . vO 3 1 r " ;. Permit Number: GP02 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID) Section 5 - Stack Information Geographical Coordinates (La titudelLonsitude or UTM) 40.7381/-1019692 Operator Stack ID No. Discharge Height., Above Ground Level (Feet} Temp ('F) Flow Rate dAtFM) Velocity tlsec (f ) Indicate the direction of the Stack outlet: (check one) ® Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ® Circular Interior stack diameter (inches): ❑ Square/Rectangle Interior stack diameter (inches): Interior stack depth (inches): ❑ Other (describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate C '100% Load ' ' (SCFl hour) : - Actual Annual.Fuel Use '.- _; ' (MMSCF/ year) . =_ Requested Annual Permit Limit' (MMSCF/ year) 828 7.25 From what year is the actual annual amount? Indicate the type of fuel used': ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTUIscf) 16 Field Natural Gas Heating value: 1000 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating value: BTU/scf O Other (describe): Heating value (give units): ?Requested values will become permit limitations. Requested limit(s) should consider future process growth. sir fuel heating value is different than the listed assumed value, provide this information in the 'Other" field. c4tnaaoo .. Y_1 t 1 Reciprocating Ip. .e1nai Co bu5t n 51,2i00 A PErI I'•.cf 1 �'_�� r 1.2.316 Permit Number: GP02 AIRS ID Number: [Leave blank w>Ress APCD has already assigned a permit # and AIRS ID] Section 7 - Emission 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): TSP (PM) Pollutant PMio PM2.s Primary Control Equipment Description Overall Requested Control Efficiency - (% reduction in emissions) SOx NOx VOC NSCR & AFRC 92.9 CO Other: NSCR Ft AFRC 81.8 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? riteria Pollutant?Emissions 1nVentory Pollutant TSP (PM) PM10 PM2.s Uncontrolled Basis 0.01941 ib/mmBtu mission Factor-- ' Source ,(AP -42, Mfg. etc) AP -42 dual Annual Emissions9 Uncontrolled Emissions (Tons/year) Controlled Emissions (Tonsl year) equested Annual Permit Emission Limit(s)7 Uncontrolled Emissions (Tons! 0.07039 0.07039 ontrolled `Emissions (Tons/year)'` 0.07039 SOx NOx VOC 0.01941 lb/mmBtu AP -42 0.07039 0.000588 lb/mmBtu AP -42 0.00213 0.00213 14 g/hp•hr g/hp•hr g/hp•hr Mfg/Reg 7/JJJJ Mfg/Reg 7/JJJJ 12.43731 0.88837 CO 0.7 11 Mfg/Reg 7/JJJJ Does the emissions source have any uncontrolled actual emissions of non -criteria 0.62187 9.77217 0.62187 1.77675 Yes ® No 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: on Criteria Reportable Pollutant EmissionsInventory Formaldehyde Acetaldehyde Acrolein Benzene Chemical Abstract Service (CAS) Number 50000 75070 107028 71432 mission Factor-; etual Ann Oat Ernissions9 Unconti oiled Basis Uncontrolled Ertiissians (Pounds/year) Con#rolled . Emissions. !(Pounds'/year) Other: 'Requested values will become permit limitations. Requested limit(s) should consider future process growth. 'Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. C 0LAS A2, rrn APCD-20' Rycipi'c=Iting IncernJi. Combust:OnAPEN . 112016 Permit Number: GP02 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. 07/12/2018 at-uof Legally Authorized, Person (not a vendor or consultant) Date Gabriela Vega Name (please print) Environmental Engineer Title Check the appropriate box to request a copy of the: ® Draft permit prior to issuance ® Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 (if applying for GP02 For more information or assistance call: submit with an additional $1500), to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form m. APCD-201 ipro _ -'� _'i n3 � �. lei .. �..:ii ..i APEN Revision I 1 /7016 YqD C64O�4 6I Produce. Water Storage Tank(s) APEN -- Form APCD-207 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged' an additional APEN fee if the APEN is fitted out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store produced water associated with oil and gas industry operations. If your emission source does not fall into this category; there may be a more specific APEN available for your source (e.g. crude oil storage tanks, condensate storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options wilt not satisfy your reporting needs. A list of alt available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.$ovipacific/cdphefair-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised. APEN requirements. Permit Number: 612.31 AIRS ID Number: 123 [Leave blank unless APCII has already assiggned a permit k and AIRS ID] Section 1 - Administrative Information Company Name: Noble Energy, Inc. Site Name: LC22-8 ECONODE Site Location: NWNE SEC22 T09N R59W Mailing Address: (Include Zip Code} 1625 Broadway, Suite 2200, Denver CO80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Gabriela Vega Phone Number. 303-228-4475 E -Mail Address"`: Gabrieia.Vega o@nbienergy,com I Use the full, legal company name registered with the Colorado. Secretary of State. This is the company name that will appear on all documents issued by the APCL. Any changes will require additional paperwork: Z Permits, exemption letters,and any processing invoices will be issued by APCU via e-mail to the address provided. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 02/2017 ¢ice<vtd 5IgEIT I COLORADO I tt:n tiro. N£�r, »nom Permit Number: AIRS ID Number: 123 / / TBD [Leave blank unless APCO has already assigned a permit and AIRS li)] Section 2 - Requested Action El NEW permit OR newly -reported emission source ❑ Request coverage under traditional construction permit. O Request coverage under a General Permit El GP05 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit (check each bat below that applies) O Change in equipment O Change company name. ❑ Change permit limit O Transfer of ownership3 D Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDrONAL PERMIT ACTIONS - • APEN submittal for permit exempt/grandfathered source Additional Info & 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: Produced Water Storage For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 hours/day 7 Storage tank(s) located at: 1/2018 0 Exploration Et Production (E&P) site days/week 52 weeks/year O Midstream or Downstream (non E&P) site Will this equipment be operated in any NAAQS nonattainment area? ■ Yes, i9 No Are Flash Emissions anticipated from these storage tanks? 0 Yes ■ No Are these storage tanks located at a commercial facility that accepts oil production wastewater for processing? Yes 0 No III Do these storage tanks contain less than 1% by volume crude oil on. an annual average basis? © Yes O No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105: Yes ❑✓ No IN Are you requesting a 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions a 6 ton/yr (per storage tank)? Yes No 0 ■ Form APCD-207 - Produced Water Storage Tank(s) APEN Revision 02/2017 2l COLOR ADO tl., MnitV Permit Number: AIRS ID Number: 123 1 / TBD 'Leave blank unless APC.t) has already assigned a permit # and MRS lD Section 4 - Storage Tank(s) Information I Produced Water Throughput; Actual Annual Amount (bbl/year) 737,400 From what year is the actual annual amount? N/A Tank design: 0 Fixed roof O Internal floating roof Requested Annual. Permit Limit4 (bbl/year) O External floating roof Storage. Tank Ie # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) 4 2000 1/2018 Welts Serviced by this Storage Tank or Tank Battery5 (EaP Sites Orly) API Number Name of Well Newly Reported Well 05 - 123- 426E CONSTITUTION FEDERAL LC21-655 0 05 - 123- 426aj CONSTITUTION FEDERAL LC21-660 CI 05 - 123- 428w FREEDOM FEDERAL LC21-630 IZI 05 -123- 428 ' FREEDOM FEDERAL LC21-635 0 05 - 123- 428( FREEDOM FEDERAL LC21-640 0 4 Requested values wilt become permit limitations. Requested limit(s) should consider future growth. 5 The E&P Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 401381, -103.9692 Operator Stack ID No. Discharge Height Above Ground Level(feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) Indicate the direction of the stack outlet: (check one) 0 Upward 0 Downward 0 Horizontal 0 Other (describe): Indicate the stack opening and size:: (check one) ❑ Circular 0 Square/rectangle 0 Other (describe): 0 Upward with obstructing raincap Interior stack diameter (inches): Interior stack. width (inches): Interior stack depth (Inches): Form APCD-207 - Produced Water Storage Tank's) APEN - Revision 02/2017 YCOLORADO Neil. St. Permit Number: AIRS ID Number: 123 / / TBD (Leave blank unless APCD hasatready assigned a permit r and AIRS IP] Section 6 - Control Device Information 0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section, Vapor O Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: l] Combustion Device: Pollutants Controlled: Rating: MMBtu/hr Type: Enclosed Burner Make/Model: Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 95 Minimum Temperature: Waste Gas Neat Content: Constant Pilot Light: 0 Yes ❑ No Pilot Burner Rating: Btu/scf MMBtu/hr • Closed Loop System Description of the closed loop system: O Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 -Gas/Liquids Separation Technology Information (EftP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 40 psig. Describe the separation process between the well and the storage tanks: Liquids from well to HP separator, then to LP separator,. then produced water to the produced water storage tanks. Form APCD-207 - Produced Water Storage Tank(sl APEN - Revision 02/2017 4 i COLORADO H .s (�vis mae. Permit Number: AIRS ID Number: 123 I l TBD [Leave blank unless APCD has already assisned a pernin ;' and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) VOC Enclosed Burner 95 NOx CO HAPs Enclosed Bumer 93 Other: From what year is the following reported actual annual emissions data? N/A Criteria Pollutant Emissions Inventory Pollutant Emission Factor' Actual Annual Emissions Requested Annual. Permit Emission Limit(s)4 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions ' .. (Tens/year)y Y Controlled Emissions? [fans/year} Uncontrolled Emissions (Tons/year) Controlled Emissions (fans/ ear J VOC 0.2620 lb/BBL CDPHE 96.60 4.83 NOx X76 .� "``_ 4. Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factory Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg, etc) ) Uncontrolled Emissions (Pounds/year) Controlled Emissions? (Pounds/year) Benzene 71432 0.007 lb/BBL CDPHE 5162 258 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 0.022 lb/BBL CDPHE 16223 811 2,2,4- Trimethylpentane 540841 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 Attach produced water laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-207 Produced Water Storage Tank(s) APED - Revision 02/2017 5I AVCOLQRh0O sVe.nft Permit Number: AIRS ID Number: 123 / / TBD [Leave blank unless APCD has already assigned a permit i1 and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP05 or GP0B, I further certify that this source is and will be operated in it compliance with each condition of the applicable General Permit. U � 5/08/2018 Signature of Legally Authorized Persoi (not a vendor or consultant) Date Gabriela Vega ' ' Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: Ej Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 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.gav/cdphe/apcd Form APCD-207 • Produced Water Storage Tank(s) APEN - Revision 02/2017 6 I A' C0LORA Oo. Hydrocarbon Liquid Loading APEN Form APCD-208 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 Hydrocarbon Liquid Loading only. If your emission unit does not fail into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APED -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.govicdohe/ancd. This emission notice is valid for five (5) years. Submission of.a revised APEN is required 30 days prior to expiration of the five/ear 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: 024 - AIRS ID Number: 123 /4M-4 [Leave blankunless APCD has already assigned a permit ff and AIRS 1D( Company equipment identification: TLO (Provide Facility Equipment ID to identify how this equipment is referenced within your organization( Section 1 - Administrative Information Company Name': Noble Energy, Inc. Site Name: LC22-B Econode Site Location: NWNE SEC22 TO9N R59W Mailing Address: (Include zip tide} 1625 Broadway, Suite 2200, Denver CO 80242 E -Mail Address': Gabriela,Vega@nblenergy.com. Site Location County: Weld NAILS or Sic Code: 1311. Permit Contact: Gabriela Vega Phone Number: 303-228-4475 'Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD, Any changes will require additional paperwork. Permits, exemption letters, and any processing invoices wilt be issued by APCD via e-mail to the address provided. Form APCD-208 - Hydrocarbon Liquid. Loading APEN - Rev 02/2017 i catoaAoa i Permit Number: AIRS ID Number: 123/ / TBD [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ID NEW permit OR newly -reported emission source ❑✓ Request coverage under construction permit O Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN Filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name ❑ Change permit limit El Transfer of ownership3 O Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) ADDITIONAL PERMIT ACTIONS - 111 Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable lint on Potential To Emit (PTE) Additional. Info Et Notes: For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Truck load -out of condensate For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 11 07 /2018 / / 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? Does this source load gasoline into transport vehicles? Is this source located at an oil and gas exploration and production site? If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Does this source splash fill less than 6750 BBL of condensate per year? Does this source submerge fill less than 16308 BBL of condensate per year? ❑ Yes ❑i No ❑ Yes El No El Yes El No ✓❑ Yes ❑ No ❑ Yes El No ❑ Yes ❑+ No ❑ Yes ❑✓ No Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 2 I Ai/ 4:7;71m,` ". COLORA DO Permit Number: AIRS ID Number: 123 / / TBD (Leave blank unless APCD has already assigned a permit ' and AIRS ID] Section 4 - Process Equipment Information Product Loaded: 0 Condensate 0 Crude Oil 0 Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded4: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Bbl/yr 110,000 Bbl/yr This product is loaded from tanks at this facility into: (eg, "rail tank cars" or "tank trucks") Actual Volume Loaded: Tank Wdcs If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: 0.6 Average temperature of bulk liquid loading: G 2 5.45 -F True Vapor Psia @ 60 ° F Molecular weight of Q 68 Lb/lb-mot mol Pressure 3.3552displaced vapors If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: Bbl /yr Actual Volume Loaded: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Product Density: Lb/ft3 Load Line Volume: f13/truckload Vapor Recovery Line Volume ft3/truckload Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO Drarnrvtarkzeit ❑ Upward ❑ Horizontal Permit Number: AIRS ID Number: 123/ / TBD [Leave blank unless APCD has already assigned a permit # and AIRS 10] Section 5 - Geographical Information Geographical Coordinates (latitude/Longitude or UTM) 40.7381, -103.9692 Operator stack ID No. 'Discharge Height , Above Ground Level (Feet) Temp (f Flow Rata (ACFM). Velocity (ft(sea) Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): 0 Other (describe): El Upward with obstructing raincap Section 6 - Control Device information ❑ Loading occurs using a vapor balance system: Requested Control Efficiency ❑ Combustion Device: Pollutants Controlled: Rating: Type: Enclosed Burner Requested Control Efficiency:. Manufacturer Guaranteed Control Efficiency Minimum Temperature: MMBtu/hr Make/Model: 95 % 95 % Waste Gas Heat Content Constant Pilot Light: 0 Yes El No Pilot burner Rating Btu/scf MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02!2017 AviN COLORADO 4 I4€1.2-^r,anm mr.aK Permit Number: AIRS ID Number: 123/ /TBD [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach alt emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes O No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SOS NOS CO VOC Enclosed Burner 95 HAPs Enclosed Burner 95 Other: ❑ Using State Emission Factors (Required for GP07) VOC 0.236 Lbs/BBL 0.104 Lbs/BBL O Condensate O Crude Benzene n -Hexane 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? N/A Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission: Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions' Requested Annual Permit =: Emission Limit(s)5 Uncontrolled (Tons/year) Controlled5 (Tons/year) Uncontrolled (Tons/year) Controlled (Tonslyear) PM SOS NOS V0C 0.1398 lb/bbl Hysys 7.69 0.38 CO Benzene Toluene Ethytbenzene Xylenes n -Hexane 0.0026 lb/bbl Hysys 0.14 0.01 2,2,4- Trimethytpentane Other: 4 Requested values will become permit limitations. Requested Limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 5 I ACOLORADO - Vf-,11 a..� Permit Number: AIRS ID Number: 123/ /TBD [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 GP07, I further certify that this source is and wilt be op . ted in full compliance with each condition of the applicable General Permit. ��' ` 1"J(\ 05/08/2018 gnature of Legally Authori}ed rson (not a vendor or consultant) Gabriela Vega Name (print) Date Environmental Engineer Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250 as 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.govicdphe/apcd Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 6 iWWll CD HE Condensate Storage Tank(s) APEN Form APCD-205 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN Updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. if your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs, A list of alt available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/pacific/cdphe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements, Permit Number: AIRS ID Number;` 123 (Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 1 Administrative Information Company Name': Noble Energy, Inc, Site Name: L022 -B ECONODE Site Location: NWNE SEC22 TO9N R59W Mailing Address: (Include Zip Code) 625 Broadway, Suite 2200, Denver CO 80202 Site Location County: Weld NAILS or SIC Code: 1311 Permit Contact: Gabriela Vega Phone Number: 303-228-4475 E -Mail. Address2: Gabriela.Vega@nblenergy,com i Use the full, legal company name registered with the Colorado Secretary of State. This is ibe 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. Alt Form. APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 A,OVW OLOHA0d 1 I Crn.+a. •i t^adz Permit Number: AIRS ID Number: 123 / / TBD [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action • NEW permit OR newly -reported emission source O Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP01 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment O Change company name O Change permit limit ❑ Transfer of ownership3 O Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info £t 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: Condensate Tanks For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 01/2018 Normal Hours of Source Operation: 24 hours/day 7 days/week 52 Storage tank(s) located at: ❑✓ Exploration Ft Production (ErtP) site weeks/year O Midstream or Downstream (non EEP) site Will this equipment be operated in any NAAQS nonattainment area? ■ Yes GI No Are Flash Emissions anticipated from these storage tanks? © Yes ■ No Is the actual annualaverage hydrocarbon liquid throughput a 500 bbt/day? IN Yes 12 No If "yes", identify the stock tank gas -to -oil ratio: m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation. Commission (COGCC) 805 series rules? If so, submit Form APCD-105. O Yes O No Are you requesting a 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions z 6 ton/yr (per storage tank)? Yes No O I Form APCD-205 - Condensate Storage Tankis) APEN - Revision 07/2017 2 I EV ^ , NeiikSCn.-_- COLORADO Permit Number: AIRS ID Number: 123 / ) TBD ILeave blank unless APCD has already assigned a permit # and A1115 ID) Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/year) Condensate Throughput: From what year is the actual annual amount? Average API gravity of sates oil: 58.5 degrees 0 Internal floating roof Tank design: El Fixed roof Requested Annual Permit Limit4 (bbflyear) 1,200,000 RVP of sales oil: 6.544 0 External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) 12 IMMO tae 1/07/2018 Wells Serviced by this Storage Tank or Tank Battery5 (EEtP Sites Only) API Number Name of Well :; Newly Reported Well 05 - 123 - 42632 CONSTITUTION FEDERAL LC21-655 0 05 - 123 - 42633 CONSTITUTION FEDERAL LC21-660 0 05 - 123 - 42803 FREEDOM FEDERAL LC21-630 IZI 05 - 123 - 42805 FREEDOM FEDERAL LC21-635 Q. 05 =123 - 42804 FREEDOM FEDERAL LC21-640 0 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The EftP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Laeiwdell ongitude'or (1Thi) 40.7381, -103.9692 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. : (°F):_ Flow Rate ' . (ACFhi) Velocity (ft/sec) Indicate the direction of the stack outlet: (check one) 0 Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size,. (check one) ❑ Circular Interior stack diameter (inches): o Square/rectangle Interior stack width (Indies): anterior stack depth (inches): ❑ Other (describe): Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 0712017 3 I A COLORADO. itt.16 Rr YbiF `. ist Permit Number: AIRS ID Number: 123 / t TBD (Leave blank unless APCD has already assigned a permit i and AIRS ID] Section 6 - Control Device Information 0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor El Recovery Unit (VRU): Pollutants Controlled: Size: Make/Model: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): 0 Combustion Device: Pollutants Controlled: Rating: Type: MMBtu/hr Enclosed Burner Make/Model: Requested Control. Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 95 Minimum Temperature: Waste Gas Heat Content: :2 ,.9.'4 Btu/scf Constant Pilot Light: 0 Yes ❑ No Pilot Burner Rating: MMBtu/hr 0 Closed Loop System Description of the closed loop system: 0 other:. Pollutants Controlled: Description: Control Efficiency Requested: Section 7 -Gas/Liquids Separation Technology information (EftP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 12 psig Describe the separation process between the well and the storage tanks: Liquids from well to HP separator, then to LP separator. Liquids from LP separator then to VRT. VRT liquids to tanks. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/20'17 COLORADO 4 1 ri.nt }tovsncr :• Permit Number: AIRS ID Number: 123 / / TBD [Leave blank unless APCD has already assigned a permit # and AIRS 101 Section 8 Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN forms. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) VOC Enclosed Burner 95 NOx Co HAPs. Enclosed Burner . 95 Other: From what year is the following reported actual annual emissions data? Criteria. Pollutant Emissions inventory Pollutant Emission Factors Actual Annual Emissions Requested An unit Permit Emission Limits) Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled .. Emissions? (Tonslyear) Uncontrolled Emissions (tons/year) Controlled Emissions (Tons/year) VOC 0.240 lb/bbl hiysys 144.28 7.21 NOx (10114 3 Lia. 0 6C). 1 O=It{ CO r a *S - ,_ 0.,11.tS -X4,(,3 ' +Q.irii Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) ) Number : ` Emission Factors Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg. etc). Uncontrolled Emissions (Pounds/year) Controlled £missions' (Pounds/year) Benzene 71432 0.00102 lb/bbl Hysys 1222 61 Toluene 108883 0.00067 lb/bbl Hysys 809 36 Ethylbenzene 100414 0.000599 lb/bbl Hysys 719 36 Xylene 1330207 0.000244 Ib/bbi Hysys 413 21 n -Hexane 110543 0.005201 lb/bbi Hysys 6241 312 2,2,4- Trimethyipentane 540841 0.000610 Ibibbl Hysys 732 37 4 Requested values wilt become permit limitations. Requested limit(s) should consider future growth_ 6 Attach condensate liquid laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-205 Condensate Storage Tank(s) APEN - Revision 0712017 CotoRAUo 5 I ==, Permit Number: AIRS ID Number: 123 / / TBD [Leave btank unless APCD has already assigned a permit II and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that this source is and wif4- e operated in fut,l compliagce with each condition of the applicable General Permit. 0510812018 Signature of Legally Authorized Pe son (not a vendor or consultant) Date Gabriela Vega Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance ID Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General. Permit registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment. Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 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 - Condensate Storage Tanks) APEN - Revision 07/2017 • COLORADO 6 � U. 1fib Pty:eenrc.m! Natural Gas Venting APEN - Form APCD-211 Air Pollutant Emission Notice (APEN) and Application fox 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 alt 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, ILC. for revised APEN requirements. 024 Permit Number: IS AIRS ID Number: 123 /4 / IBD [leave blank unless APCD has already assigned a permit # and AIRS ID) Company equipment Identification: L022 B - VRT&LP [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Noble Energy, Inc. Site Name: LC22-A & B ECONODE Site Location: SEC22 T09N R59W lu Address: Cde1625 Broadway, Suite 2200 (include Zip [ode} Y� Denver CO 80202 E-mail Address' gabriela.vega@nblenergy.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Gabriela Vega Phone Number: 303-228-4475 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption Letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-205 - Natural Gas Venting APEN - Rev 03/2017 315 ... ....... capoAAflo u �a Permit Number: AIRS ID Number: 123 i /TBD [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action D NEW permit OR newly -reported emission source - OR - O MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name O Add point to existing permit ❑ Change permit limit O Transfer of ownership' O Other (describe below) OR ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info E Notes: For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: VRT & LP Streams at the LC22B For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 1 /07 / 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: 24 hours/day 7 days/week 52 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 O Yes ❑ Yes Form APC0-205 Natural Gas Venting APEN Rev 03/2017 2 weeks/year 0 No No OLORADO Permit Number: AIRS ID Number: 123 / / TB D [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Ei Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: ❑ Other Description: Serial #: # of Pistons: Volume per event: Capacity: Leak Rate: Gal/min 5cf/hr/pist MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? [j Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: 541 SCF/hr Vent Gas Heating Value: 2648 BTU/SCF Requested: 4..739 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 %) 76.05 VOC (Weight %) 85.73 Benzene (mote %) 0 ( Benzene (Weight %) 0.27 Toluene (mole %) 0.08 Toluene (Weight %) 0.16 Ethylbenzene (mole %) 0.02 Ethylbenzene (Weight %) 0.05 Xylene (mole %) 0.03 Xylene (Weight %) 0.08 n -Hexane (mole %) 1 .Q4 n -Hexane (Weight %) 1.9 2,2,4 Trimethylpentane (mole %) 2,2,4-Trimethylpentane 0.01 (Weight %) 0.02 Additional Required Information: El El Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX & n -Hexane, temperature, and pressure) Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 �jw cotoRAoo pee�fie Leatt_f;N ❑ Upward ❑ Horizontal Permit Number: AIRS ID Number: 123 / / TB D [Leave blank unless APCD has already assigned a permit # and AIRS ID; Section 5 - Stack Information Geographical Coordinates (Latitude Longitude or UTM) 40.7381, -103.9692 Operator Stack 1D No Discharge Height /Lbove Ground Level Temp f) z otCFM) f/M) .'e Ye7ac�t t (Feet) Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): 0 Upward with obstructing raincap Section 6 - Control Device Information O VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed a, ❑ Combustion Device: Pollutants Controlled: VOC, Benzene, Hexane, Toluene, Xylenes, 224-Mpentane Rating: MMBtu/hr Type: VOC Burner Make/Model: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: 95% Waste Gas Heat Content Constant Pilot Light: 0 Yes 0 No Pilot burner Rating Btu/scf MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested 0 Form APCD-205 -Natural Gas Venting APEN Rev 03/2017 4 I Y COLORA00 Permit Number: AIRS ID Number: 123 / / TB D [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? 0 Yes O No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): • Pollutant Control Equipment Description _ _ Overalr Requested Control Efficiency (% reductionin emissions) PM SOx NO VOC VOC Burner 95% CO HAPs VOC Burner 95% Other: From what year'is the following reported actual annual emissions data? N/A Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant 'Uncontrolled Emission Factor_ . - Emission. : a =actor ' • Units ;,...pp-4-2,:.;_Uncontrolled Emission Factor ` SourEe Mfg:..etc) -, ; At a -a nnuat ErnissiOPs =� - . • µ- Rec(i etp. —fifi dal Per i z EissionL�rtiits�5 (Tons/year) Controlled!: • (Tonslyear) = Uncontr olled (Tonslyeor) Controlled (Tons/year) PM 7.60 lb/mmscf HYSYS/AP42 0.00 0.00 SO,, 0.60 lb/mmscf HYSYS/AP42 0.00 0.00 NO,, 0.068 lb/MMscf HYSYS/AP42 0.463 0.463 VOC 106.899 lb/mscf HYSYS(AP42 253.29 12.67 CO 0.310 ID/MMscf HYSYSIAP42 1.98 1.98 Benzene 0.3310 lb/mscf HYSYSIAP42 0.78 0.04 Toluene 0.2029 lb/mscf HYSYSIAP4Z 0.48 0.02 Ethytbenzene 0.0605 lb/mscf HYSYS/AP42 0.14 0.01 Xylenes 6.0947 lb/mscf HYSYSiAP42 0.22 0.01 n -Hexane 2.3724 lb/mscf HYSYSIAP42 5.62 0.28 2,2,4- Trimethylpentane 0.0302 lb/mscf HYSYSIAP42 0.07 0.00 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6Annuat emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. ....................... CDLDR&OD Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 5 1 Permit Number: AIRS ID Number: 123 / / TBD [Leave blank unless ARCO 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. Li 8/24/2018 Signature of Legally Authorized Person (not a vendor or consultant) Gabriela Vega Date Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance Ei Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Mr Pollution Control Division (303) 692-3175 or (303) 692-3148 APCD-SS-81 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 https://www.colorado.gov/cdphe/apcd Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 x1 Form APCD-205 Natural Gas Venting APED! Rev 03/2017 6 I Elk+ COLORADO Hello