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Home My WebLink About20183623.tiff rnaHE COLORADO Department of Public Health ES Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 O St RECEIVED PO Box 758 Greeley, CO 80632 NOV 0 8 2018 November 5, 2018 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On November 8, 2018, the Air Pollution Control Division will begin a 30-day public notice period for DCP Operating Company, LP - Bighorn Natural Gas Processing Plant . A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe u` (( John W. Hickenlooper, Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer , Pohl iG f V�2w cc: PLCTP.I HL(3T) I t / 19/I 8' ► e/Rg K/3M cis) 2018-3623 coPrE Air Pollution Control Division CO ,' Notice of a Proposed Project or Activity Warranting Public Comment Website Title: DCP Operating Company, LP - Bighorn Natural Gas Processing Plant - Weld County Notice Period Begins: November 8, 2018 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: DCP Operating Company, LP Facility: Bighorn Natural Gas Processing Plant natural gas processing plant Section 2, T3N, R65W LaSalle, CO 80645 Weld County The proposed project or activity is as follows: Source proposes to construct a 930 million standard cubic feet per day (MMscfd) natural gas processing plant consisting of two (2) 350 MMscfd gas processing trains and one (1) 230 MMscfd plant bypass train. Source is requesting synthetic minor limits for Title V, Nonattainment New Source Review (NANSR), and Prevention of Significant Deterioration (PSD) 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 18WE0465 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Bradley Eades Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us 1 I , Colorado Air Permitting Project PRELIMINARY ANALYSIS-PROJECT SUMMARY Project Details Review Engineer: 6Fadl y Ead s _ Package#. 38009„s:;€t_;"€'�€,;;s`. .s4iy;••� Received Date: Review Start Date: Section 01-Facility Information Company.Name 0503 355 terie P nv lP I Quadrant I` Section I Township I, Range County AIRS ID. 123" Plant AIRS ID: OFBI% ` ... eel Facility Name: tifgitprn Gas.Pknf(axigal lNsubm_itYed asSbelmn 5as Plant€ ;;.,;;,,, AM 11 n Physical Address/location: Section 2,Township 3N,Range 65W County: 'Weld County Type of Facility: 0 5 WTt� What industry segment? ; . we; Is this facility located in a NAAQS non-attainment area? If yes,for what pollutant? I Irarbaa NoeoOde(CO) Iaammiaze NaOO lPnl Elo.aae(Noxave l Section 02-Emissions Units In Permit Application AIRS Point u Emiissloes Source T Equipment Control? Issuance k Self Cert Action Engineering ineerin Remarks ype quipmen Name ContF+ Required? Reftnitinitia€. .... :: .. ,..,,:=- D-O1..,3,.:;a...5Qs '18WE0A65' 1�ira€pr -:�I:i ,.�, ssuance i 3soMMscFTraai 3 - _ ;;;_.- ,,, -- - 002- =Do}tydrator- D-02- - Yes .18W E0465 1 .Yas trammel,,,,-350MMSCFTrain 2 003 ZiDeleidrator -- 0-03 Yet 18WEQ465. 1 _ Yes issnaore_ 230MMSCE Bypass _— Permittaitiai'_.Train 1 Mal Sieve ; 004 - _ N€_Heater 33-1741 Na_ -- 18W50445 _ - 1"_ Yes-,_ tsuaare_ -_-Regen - sz = Aesmit=lntEra€ "€rain 2 Mot Sieve 001 N6 Heater 31 2741 Na 18WE0461 = 1 -q ,,.Yes tssnaace Regen 111 0: i x O;111 ".� Trauilstahurzer `v � _ , -�� - -__NHT3eater ";N 29DW:' .'Np =i8WE0461 T'3' - Yes'- eiance 'Frain 2 stab Ii_ee - Permit ltutfai 008- „-,-i; iN,H2atei t1-1781 _' FN€, _ -1535(445:, ,= i5Suati0e,;-.r'train 1 Demethanilel - /� A :. iii ..;y aim II•fuFia ft,":1t,� uF,. '3 Ji-278tii P€Iu i.,;,.1031E.0�385,,,- )S.�.S af'. ,Slain-2 Demethaoiierii `t*toilVV _'i'A.Mcs , T4N1CS.2....:t; leo =. 10W04465 -_1 You issuance' Trad"2Teriks =- - '.as.,r,- 3'eetniemiifai Stat€zed Come .: 012 .-ligadd Load€ng' - Lp - Yes.-' 28WF0405 -1 liYts1'1.-' 1173 Y s 18VVRE046511 f1 j 3 1 3 e Gni/a�uf� Ptessurzed FJn€oading 4 a x*v • , a 3 4r �....., Dermtt Weber'. esssF. PLAt�1 � S`esiwikko=idg 1 Yes fssuaFice: 7rmx1aod6yPass „i: Permit Initial 4 - . •.015r X31 ;3 ,Pru sf€are ELfSRE2 ,3::'• Yes AiiiiiiiiitifiW.60465, ,I ;Yes. -- 1sek nce:.- Tram-2 FA1Ss ;�' No ,"i814Ett465 -= 1 .. Padilitµwide 017 3dethanal TwoS METHANOL.: r Np�yI \=IBWE0465 S s: `� fl $ a _ t]filY1 5/- �Fta- \ ,�,/�'_'�� 3, i t v ai3 :t Air€f6RigvaeiJ 018: .IRiddHtes{;Wa trap I,;PW,Tarik's'j1 . °!i8WE0466,-.; ,,,XP'; Na' `i'ermtt Exexttpt - Section 03-Description of Project 00Pisp2raposmg teopetut ahg7, D3y3M5CF05 gilra1,g pro nsnngpfa t The pleptholl0 S stoftwo(2)processing-trains each with 350 MMSCFD cepaaty The piant-' ,. Wttafk6m¢ft�dg 230MKri6�p�lall'1��1Y.P7ssfot`witti4i"Ytse&6+Yrceisperm(CCIr>gasingluTEGdehydramr.pGPrequestedanamechangeoBCtefaetlFi�+ftolh S_R(rnNaeOral EQa;r roget'R pram t ,`oighata las,Dl"riteviaamaol on Aug 2 2D10Tife nesesa npdaS S were made to internal dootaba sandtheiAPEN;we ill 3� feflee/-the. 3 dpredjs(nDtname _'AA -. ry. �1 3 Ill3 ) 1 DC/provided appfication.rovisianram 9/14/18 upon review afthe'rkat pornsil[5riesting4it RtHedse in processingcapacity of the two(2)processing trairis'ftkm.55D MMSCFDto-305 MMSEFO In addttson the and teta k to dtexstoy pyodod4eandE,nsate'were increased from 4595 BPD to 5400 BPD throughput -"` - 3 3 3 I i.3 i1jgF 3 I I ' _ '....: '... Section 04-Public Comment Requirements Is Public Comment Required? If yes,why? Atgneitlnkthe{iNS4zaXko}i Section 05-Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? If yes,for what pollutants? If yes,attach a copy of Technical Services Unit modeling results summary. Section 06-Facility-Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? i 'Dyes,indicate programs and which pollutants: SO2 NOx CO VOC PM2.5 PM10 TSP HAPs Prevention of Sign cant Deterioration(P501 Title V Operating Permits(OP) I I Ti I I Non-Attainment New Source Review'INANSR) J ;iiiii WORM Is this stationary sources major source? ;,t�%., r�;,r��; If yes,explain what programs and which pollutants hen 502 NO% CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration(PSO) I I 1 Title V Operating Permits(OP) II Non-Attainment New Source Review lNAN5R) Glycol Dehydrator Emissions Inventory 001 Dehydrator facirity AIRS ID: Ma` yy ,.,;,,,.... „.9lant _ Dint ..i m ry Plant Point Sacdon Oz-Egnip nrent Deacrlptlnn oetollo. Dehydratorintormatlon Oehydretar Type: 38I3c- Model Senai Number 33 T6odl�j Design Capacity: -i44,•,,,< <, MMscf/daY ReccUt Don Pump Information Number of Pumps a Pump Type z 1i,$vi.vot Make: TBf3 Model: :COO Design/Max Recirculation Rate: ,,,,�00, ,gallons/minute -Flash Dehydrator Equipment tehoflank Kk andflash tank RebolerBumer YpY,C Stripping Gas One(1)Tdethylene glycol(TEC)natural gas dehydration unit(Make:TBD,Model:TBD,Serial Number.TBD)with a design capacity e0365 MMsct per day.This emissions unit piled with 2(Make:Teo,Model:Teo)elo Etc driven glycd pump with a design 001¢023 of 6o gailorns per minute.This dehydration unit a equipped with a still vent Dehydrator Equipment Description and Rash tank. EmisslonsframYnertlllventareooutedtoanafr<Ooled000denser,andthentothe Vapor Recovery Unit(VRUI.Asasecondarymn0oldevlce,enlll ventemisslonsarer0uted tethe Open Flare.Emlenianshomthetlashtankare routeddlrecttytothe Vapor Recovery UnR(VRU).Asaucondarycontroldevlce,OashtankemhNonsareroutedtothe Emission Control Device DCscriptlon: Open Flare. Section 03-Processing Rate Inormation far Emlssfors Estimates Primary Emissions-Dehydrator Stilloent and Flash Tank(Ifpresent) Requested Permit LmhThroughput 333,22SW j;._MMsd per year Requested Monthly Throughput= 1131500 MMscf per month Potential to Emit(PTE)Throughput= 133,225.00 MMscf per year Secondary Emissions-Comburtlon Devices)too Air Pollution Control 5 11 Venrt Cpmrol Dry Gas Throughput: Condenser: Y₹6" I au�' Still Vent Primary Control 130,560.5 MMscf/yr 11,0807 MMscf/month Condenser emission reduetlon clairred 2#¢- /f'�l/�..Requested Condenser OutletTemperature: ,``1 r to DegreesF Still Vent Secondary Control. 2,664.50 MMscf/yr Primary control devOn: V2pev fd00 'i 30011'Co[ lEfficie cy% West¢Gas Combusted: Primary control device operators 1 B5040h/y Re,u.tedloTemp x.. L/d,Degrees F Still Vent Primary Control 0.0-MMscf/Yr 0.0 MMscf/month Secondarymrrtrol devic .:OS%:Control Efficiency% Still Vent Secondary CnntroC - 0.4 MMsd/yr Secondary conntrol device operaton I P343 OEsDh/yr Sill Vent lee Heating Value: . 3 i yD Btu sd Still Verrt Waste Gee Vent Rate: --]j2D.sdh 'NOTE:PRIMARY STILL VENT SCENARIO I5 NOT CONSIDERED IN UNCONTROLLED EMISSIONS.SEE NOTES Flash tank Control Dry Gas Throuehpoe Primerycontrel dews: Cmc-t Sb lControl Efficiency% Flash Tank Primary Control 136560.5 MMscf/yr Primary control device operation: ;,.'fr.;I ar ;4544,4 hr/yr Flash Tank Secondary Central: 2,664,5 MMsd/yr Secondary control device: ®_. y'„'.1 -%%%^.006'.Control Efficienry% 15200000 Warts bas Combusted: L Secondary control deuce operation S75.TI hr/yr 364.8 Flash Tank Primary ContrgC 0.0 MMscf/yr Flash Tank Gas Heating Value 1410',.Btu/sd Flash Tank Secondary Control: 0.8 MMsd/yr Flash Tank Waste Gas Vent Rate: 44;0'sdh 'NOTE:PRIMARY STILL VENT SCENARIO IS NOT CONSIDERED IN UNCONTROLLED EMISSIONS.SEE NOTES Glycol Dehydrator Emissions Inventory Section 04-Emissions Factors&Methodologies 0 hyd to Th aunt df'Rl Gig 14 D₹a esUmai4 m:sio,u Wet gas composition,pressure and temperaturere based an a extended we gas analysis a 491LeetR#m/22/i6 in a47F n r'feeilfA 29 nod I a b d 4lrefallow ng Param ten . „,,,,,agip'., I )4. Input Parameters Inlet Gas Pressure li.628 ;,:04 Inlet Gas Temperature 80 ::degF Requested Glycol Recirculate Rate 60,,,, )-)gpnt Control Scenario STILL VENT Primary Secondary Pollutant Uncontrolled(lb/hr) Controlled(lb/hr) Controlled(lb/hr) VOC s)),§)).-.1.37)0.546,)..2, 0 6.89773 Benzene ,,...t)25A945,._.,.,% 0 1.254725 Toluene 'v.3S6204 0 0.80373 Ethylbenzene 1,..,',2,))).0)),&,,,,, 0 0 Xylenes 3?"•x,'629/H'29. 0 0.33765 n-Hexane )))q). -* 0 0.38867 224-TMP t',...)22..20'..8)22104,5 0 0.000435 H25 s "" 0CG!9__..' 0 0.00145 ControlScenado FLASH TANK Primary Secondary Pollutant I Uncontrolled(lb/hr) Controlled(lb/hr) Controlled(lb/hr) VOC :160.953 429 0 8.245265 Benzene 1°,,106669 :ig.: 0 0.033345 Toluene ,)).(22876ill.K 0 0.01438 Eth516enzene !":I 0_. 0 0 Xylenes -'00505 .tea 0 0.002525 ,Hexane 0 0.26576 224.TMP >-6.0059 0 0.000295 H25 - 0.0096 0 _ 0.00048 Emission Factors Glycol Dehydrator Uncontrolled Controlled Pollutant (lb/MMscf) (lb/MMscf) Emission Factor Source (Dry Gas Throughput) (Dry Gas Throughput) VOC 0.44 0.02 Benzene 0.032265806 P.C.'S.9 Toluene 0.0 23 669155 O.W1183458 Ethylbenzene 0 0 ,vi€ f Xylene 0.009843222 0ecosee161 � / ,59')5, , = , W mtlexane 0.018933646 O. 0946B92 �;, G � ,- 224 TMP 0.00002112 0.0.001056 '/ Fr. 5.58328E-05 229189E-0fi ,,jfi �'�/ Still Vent Secondary Control Device Uncontrolled Uncontrolled Pollutant (ib/MMBto) (Ib/MMscf) Emission Factor Source (Waste Heat (Waste Gas combusted) Combusted) PM10 00025 16.3325. '� _} PM25 0.0075 163325 NOx 00680 149.0560 r ...N CO 03300 629.5200 Flash Tank Secondary Control Device Uncontrolled Uncontrolled Pollutant )lb/MMBtu) )Ib/MMsct( Emission Factor Source (Waste Heat (Waste Gas Combated) Combusted) PM10 -6.0079 10.5655 PM2.5 00075 50.5655 _ A. y v�// 443x 40,oean 96.8840 ,/'M-s.'"'$r°a` S ri40ico; co .;25300..: 39sg9D a_-.4,42-ooMM34r53srr xsf4o/Ftrottt^Qk 3, Section OS.Emlsslons Inventory . Did operator request a buffer? s-„.., ,' - Requested Buffer(%): :;/ Potential to Emit Actual Emissicm Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tans/year) (tons/year) (tons/year) (tons/year) (tons/year) (Ibs/month) PM10 0.0 0.0 0.0 0.0 0.008 PM2.5 0.0 0.0 0.0 0.0 0.0 1 600 0.0 0.0 0.0 0.0 0.01 1 500 0.1 0.1 0.1 0.1 0.07 12 CO 0.3 0.3 0.3 0.3 0.33 56 - 3OC 29,2 29.2 1.5 29.18 1.46 248 Potential to Emit Actual Emissions Requested Permit Umits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Ohs/year) abs/year) (lbs/year) (lbs/year) (Ihs/year) Benzene 4965 4965 248 4965 248 Toluene 3153 3153 158 3153 158 Ethylhencme 0 0 0 %plena 1311 1311 66 1311 se n-Hexane 2522 2522 126 2522 126 224TMP 3 3 0 3 0 H2S 7 7 0 7 0 Section 06-Regulator,/Summary Analysis Regulation 3,Parts A,8 Source requires a permit Regulation 7,Section XVII.6,D Dehydrator is subject to Regulation 2.Section MI,B.0.3 Regulation 7,Section XVII.B2.e Theafntral device for this dehydrator is subject to Regulation 7.Section XVII.B.2.e Regulation 7,Section XII.H Dehydrator is subjectte Regulation 7,Section%II.H Regulation B,Part E,MACTSubpart HH(Area) The dehy unit meets the benzene exemption Regulation 8,Pan E,MACTSubpart HH(Melor) You have indicated that this facility b not subject to Major Source requirements of MACT,HH. Regulation B,Part E,MAC]Subpart HHH You have Indicated that this facility Is not subject to MACT HHH. (See regulatory applicability eeorksheatfor detailed analysis) Glycol Dehydrator Emissions Inventory Section 01-Initial and Periodic Sampling and Testing Requirements Was the extended wet gas sample seed n the GlyCak model/Process model sO-epecifr and collected wrtfin a y WSr7 of app rand aubmMaR �;> If no,the permit will contain en"Initial Compliance"testing requirement to demarsstrate compliance with emission limits Does the company request a control deuce efficiency greater than 95%for a flare or corn bunion device? p i__ a-.w w"be£D Dyes,the permit will contain end initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on Inlet and outlet concentration sampling If the company has requested a control device efficiency greater than 95%,is a thermal oxidizer or regenerative thermal oxidizer being used to achieve it?I No I It yes,the permit wfl contain a condition specifying the minimum combustion chamber temperature for the thermal axidher Is the company using a thermal oxidizer AND requesting a minimum combustion chamber temperature lower than 1,400 degrees F? f4fYC. is.t4 e If yes,the permit will contain an"Initial Compliance"testing requirement AND a permit condition specifying the minimum combustion chamber temperature for the thermal oxidizer. Section 0a Techniai Analysis Notes .,. 'Applicant has indicated thatxhe dehydrator stillyant gas Is routed boa co enserprior to Cfie Vldflorflare.DC?Ls n t takngemission reductioncredttrorn VOC and HAP removed in beoondenser The secondary combustion emission calculations are based on the post-condenser stream froni"GlyCalcsr ce it is more representative of actual operation Since primarily water is removed in the condenser,the bus/hr: flowto the flare does not changesignifisentfy sinaH2O has Hey oft).CC?used tidy in their emission calculatons as opposed to HHV,Ths is being accepted as the resulting emissions ry insignificantly, `The primary operating scenario,4i.e.identified as primary control scenario inanatyes above}is not considered in uncontrolled'emissions calculations.This is based an the fact that there are.redundant VRU's n place to nonpnie vapors in the event thatthe primary is down.Therefore,the VRU is not considereda control device for purposes of this analyse, 'The operator alculated SO2 emissions using a mass balance and theassumption that 100%of the H25 resulting from the dehydration unit(routed to the combustor)is convertedto502.The calculation is as follows- $02(lb/year)-u(5B lb H1S/yearr(84,0461b$02/Ib-molj/(a4,0ua9 lb#i35/Ib•mol)=1281ly02/yee;)14.016/yr with 1.0 bu€ferj This calculation isacoriserIzative estimate based on the representative H25 composition ant th reforeacceptable for permitting purposes. `An addition₹process limn-will be addedte address the volumeof gas that could be processed bythe dehydrator during VRU downtime.This process limn is based on 2%of the total gas that may be processed by the dehydrator.Asa result,the process limits in the pennie are now as fotiow:(i)Process 01-Total natural gas throughput 127,750MMsef/year and( ProcessA2-Natural gasthrougbput during VRU downtime =2,555 MMsef/Year. • "The permit wii£not include monthly emission limits forthissource.Aifhough this e a new source,the controlled emission rates are bused ono backup metro'scenarios.DC?hasindicatedthat the occurartaoe VRU downtime could potertiaiy occur all in one month and cannot beforseabiy broken dower,on a monthly keels.bteuOh,OCP need only comply with an anneal limit.I will maintain atnonthly,proeess limit for total gas processedsnce this is independent-of the monthly amount of primary control de lmedowni a However,there wilt not no a corresponding monthly emission limit since thew tolled emissions are based on atternateprocess scenarios. *The operator did not calculate PM emtssmns associated with the combustion of still vent and flaehtank emissions that arena uted to andcentrolled by the plant flare(point 125),The operator asserted that since the flare is designed to be-e smokeless combustion device,particulate matter is not expected to degenerated from the combustion of dehydraeorwaste gas routed to this device. in orderto eddressthis statement,the emtssionfatter source for combustion emissions(NOx and COL AP-02 Chapter 13,5,was reviewed.This document expresses the"emssions from flaring may includearbon particles(soot},unburned hydrocarbons,CO and partially burned and altered hydrocarbons.Afsn emitted are nitrogen ox desiNOx)and,If sulfur ceree nssg material such as hydrogen sulfide or mercaptans flared,sulfur dioxide(002)."based on the statement,the document does not provide information web regards toparticulate mower,except with regards to soot The document further provides that a smoking flare directlysesultsm soot formation when:i states'The tendencyof a fuel to smoke or make soot is influenced byfuel characteristics and by the amount and distribution ofoxygrn in the combustion zone!'This s further supported by footnote'ne beiowtabie 13,$.1 which providesthe following.'Soot in concentration values:nonsmbkingffares,0 microgram.pm-liter(pg/k);ightii smoking flares,40 u6/l;average smoking Hares;177 t$g/L,and heavily smokingflares,274pg/L"..At thineime;there is not aeutherucuree of data that quantifies P N11O or.PM2.5 from industrial flares and therefore,it:wilt be assumed that the onlyssurce of particulate matter from a flareissaot from smoke asexpressed in AP-42 Chepterl35 it should be mated that then&M plan requires that daily checks beconduaedto determine ifthefiareissmoking.If smoke is observed during the daily check the sourceisrequtredto ether conduct a method 27 or immediately shut in the equipment to investigate the cause of the smoke and conduct repairs as necessary.Based on this requirement for the flare and the manufacturer design fortiae flare to be smokeless if operated properly,it can safely be asumednbat the flare will eperatewtthout smoke on a regularhasin Also,if smoke a observed,the opeatorwgl be required to asses the problem and perform necessary mtenanceue prevent the flare from smoking.Assuch,l am comfortable assuming a soot concentration ofemicrograms per liter es provided in AP-42 Chapter 13.5 for nonsmoking flares. One other tent that should be consideredre that the source is permitted topmnanly mute still vent and flash tank essin ns tea VRU to be recycled.The VFW is only permittpermitted.,have eweu of 2%annual downtime during which emissions will be routed to the flare.It the total PM emission factor 007.6 ib/MMscffrom AP 42 Chapter 1.4 were used,the total PM emissions(for both PM 10 and 2.5)would only be 0008 toy ihisrs every small annount of emissions and would not result in permit limits for PM or'result in additional reyulitOry requirements. Ba ed onthessformeti on dis ed above,it was determined thatthe operator'se rtlen that a smokeless flare would not lye eadected to have PM:emissions was valid However,ifin the future betterdata P developed for estimating PMttemissions from industrial flares should be included ire future analysis. `Upon review of the draft permit,the eppkantsequested that the permit daffy that there areseparate dedicated YRUsfereach process vent(Le still vent and flashtank).Downtime will be trackedsaaprately for each VRU(Still vent VRU and Flash Tank VRU):Revisions were made toclanfy that up to 2%downtmeforsht Vent VRU and up to 2%downtime fez Flash Tank VFW is permitted. 'Upon review of the draft permit,applicant requested.modify permit iengaage taaeowfor flexibility in monroring either(i)wet eonnoiume at the dehydrator intet or fn)dry gas volume et the dehydrator outlet.It wer discussed and agreedthate order.allow thisflexibdity,DcP would assume that regatdiess of meter pl cem net(tea the inlet or outlet)the metered volume would he assumed equivalem tin the dry gas'volume for purposes o€input values to DI)Caic Appropriate revisions were made to the permit₹a sccenmdetethis twinest. I Section O9-inventory SCC Coding and Emissions Factors Uncontrolled AIRS Point O Process# SCC Cade "''�+�,' Pollutant Emissions Factor Control% Units 001 01 a1'.4(t-065A5O pppJ dp)jY ... sd'yang tr�gggj'�e ¢e 7,,.1l.-.,..S.... _,i//)$a,izu..s PM10 0.000 00 b/MMsef falPfS�?r>3an9nar.," PM2.5 0.000 00 b/MMscf 50x 0.000 0.0 b/MMsd NOx 0.001 00 b/MMscf VOC 0.4 95,0 b/MMsct CO 0.005 0.0 b/MMscf Benzene 0.037 95.0 b/MMscf Toluene 0,024 95.0 b/MMsd Xylene 0.010 95.0 b/MMscf n-Hexane 0.019 95.0 b/MMscf 224TMP 0.000 95.0 b/MMscf Dehydrator Regulatory Analysis Worksheet Colorado Re ulation 3 Parts A and B-APEN and Permit Requirements Source is in the Non-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)? f 'You have indicated that source is in the Non-Attainment Area NON-ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY(Regulation 3,Part A,Section ll.D.1.a(? - "r 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 ll.D.2)? ,_...« 'Source requires a permit Colorado Regulation 7,Section XII.H 1. Is this glycol natural gas dehydrator located in the 8-hr ozone control area or any ozone non-attainment area or attainment/maintenance area(Reg 7,Section XII.H.1 and 2)? Yes . 2. Is this glycol natural gas dehydrator located at an oil and gas exploration and production operation',natural gas compressor station,natural gas drip station or gas-processing plant(Reg 7 Section Yes 3. Is the sum of actual uncontrolled emissions of VOC from any single dehydrator or group of dehydrators at a single stationary source equal to or greater than 15 tpy(Reg 7,Section XII.H.3.b)? 4. Are actual uncontrolled emissions of VOC from the individual glycol natural gas dehydrator equal to or greater than 1 tpy(Reg 7,Section XII.H.3.a)? 'Dehydrator is subject to Regulation 7,Section XII.H Section Xll.H—Emission Reductions from glycol natural gas dehydrators MACT Analysis • 1. Is the dehydrator located at an oil and natural gas production facility that meets either of the following criteria: Yes a.A facility that processes,upgrades or stores hydrocarbon liquids'(63.760(a)(2));OR • 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 b.end user'(63.760(a((3))? 2. Is the dehydrator located at a facility that is a major source for HAPs? 'Go to MACT HH Area Source Requirement section to determine MACT HH applicability 40 CFR,Part 63,Subpart MACT HH,Oil and Gas Production Facilities Area Source Requirements 1. Is the dehydrator a triethylene glycol(TEG)dehydration unit(63.760(b)(2))? - Yes Exemptions • 2a. Is the actual annual average flowrate of natural gas to the glycofdehydration unit less than 3.001747 MMscf per day(63.764(e)(1)(i)? IYx3' 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 6/yr(63.764(e)(1)(ii)? You 3. Is the unit located inside of a UA plus offset and UC boundary area? The dehy unit meets the benzene exemption Subpart A,General provisions per§63.764(a)Table 2 - - 463.765-Emissions Control Standards Do Not Apply §63.773-Monitoring Standards Do Not Apply §63.774-Recordkeeping §63.775-Reporting Standards Do Not Apply Major Source Requirements 1. Does the facility have a facility-wide actual annual average natural gas throughput less than 0.65 MMscf/day AND a facility-wide actual annual average hydrocarbon liquid throughput less than 249.7 emu;' Small or Large Dehy Determination 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day(63.761)? 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr(63.761)? Small Dehv Requirements 3. Did construction of the small glycol dehydration unit commence on or before August 23,2011(63.760(b)(1)(i)(8)and(C)? , 4. For this small dehy,is a control device required to meet the BTEX emission limit given by the applicable equation? % kcal have indicated that this facility is not subject to Major Source requirements of MACT NH. Subpart A,General provisions per§63.764(a)Table 2 §63.765-Emissions Control Standards §63.773-Monitoring §63.774-Recordkeeping §63.775-Reporting 40 CFR,Part 63,Subpart MAR HHH,Natural Gas Transmission and Storage Facilities 1 Is the facility wide actual annual average natural gas throughput less than 0.9994051 MMscf/day and glycol dehydrators the only HAP emission source(63.1270(f))? Small or Large Dehv Determination 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 9.994051 MMscf per day(63.1270(b)(2))? 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr(63.1270(b)(2))? Small Dehy Requirements 3. Did construction of the small glycol dehydration unit commence on or before August 23,2011(63.1270(6)(2)and(3))? r 4. For this small dehy,is a control device required to meet the BTEX emission limit(standard?)given by the applicable equation? 'You have indicated that this facility is not subject to MACT HHH. Subpart A,General provisions per§63.1274(a)Table 2 §63.1275-Emissions Control Standards §63.1281-Control Equipment Standards 063.1283-Inspection and Monitoring §63.1284-Recordkeeping §63.1285-Reporting Colorado Regulation 7,Section XVII.D 1. Is the dehydrator subject to an emissions control requirement under MACT HH or HHH(Regulation 7,Section XVII.B.5)? No 2. Is this dehydrator located at a transmission/storage facility? No 3. Is this dehydrator located at an oil and gas exploration and production operation,natural gas compressor station or gas processing plant(Reg 7,Section XVII.D.3)? Yes 4. Was this glycol natural gas dehydrator constructed before May 1,2015(Reg 7 Section XVII.D.4.b)? +} • If constructed prior to May 1,2015,are uncontrolled actual emissions from a single glycol naturalgas dehydrator equal to or greater than 6 tons per year VOC or 2t VOC if the P g gY Y q g P Y tpy 4a. dehydrator is located within 1,320 feet of a building unit or designated outside activity area(Reg 7,Section XVII.D.4.b)? 5. If constructed on or after May 1,2015,are uncontrolled actual emissions from a single glycol natural gas dehydrator equal to or greater than 2 tpy VOC(Regulation 7,Section XVII.D.4.a)? ,,des, a 'Dehydrator is subject to Regulation 7,Section XVII,B,D.3 Section XVII.B—General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.D.3-Emissions Reduction Provisions• Alternative Emissions Control(Optional Section) 6. Is this glycol natural gas dehydrator 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 dehydrator is subject to Regulation 7,Section XVII.B.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 tenninology 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 Glycol Dehydrator Emissions Inventory 002 Dehydrator FatlIRy AIRS County Plant Paint Section 02-Eoulvmern oescriptlan Details Dehydrator lntprmatian Dehydrator Type: Make' s '3 CF� 33JPiBhS Model: 11?3je3 iii dE&I Serial Number: �jh, i i A ice, Design Capacity: ' 3�' .- MMscf/day Redro don Pump Information Numberof Pumps 2' 1��,, Pump Type 1 :s-,5,.=„✓SX Make: , L3 30 3 Model: YSinJ3�L33G AvE Design/Max RecirculNIon Rate: '' 'ja 13 rYn 31P�..xA.454 �.. ,dgailons/minme Dehydrator Equipment Flesh Tank " ".' Ya and flash tank Reboiler Burner Str PP nBGaz . One(1)Triethylene glycol(TEG)natural gag dehydration wit(Make:TBD,Model:TBD,Serial Number.TED)with a design opacity of 365 MMsd per day.This emissions umt is equipped with 2(Make:TEO,Model:TBO)electric driven glycol pump with a design capacity of 60 gallons per minute.This dehydration unit 5,g equipped with a still Vent Dehydrator Equipment Description and flash tank. Emisslorofrom the still vent are mined m an air-cooled condenser,and then to the Vapor Recovery UMt(VRU).Asa secondary wnhol devim,still vent emissions are rooted tothe Open Flare.Emissionstmmthe Rashtankarerooteddirectiytothe Vapor Recovery Unit(VRU).Asesemndarymnooldsolon,TeshtankemhNonsareroutedtothe Emesbn Control Devke Description: Open Flare. r Sectjon 03-Proceaine Rate Information for Emissions Estimates Primary Emialons-Dehydrator SUB Vent and Flash Tank(if present) Requested Permit limit Throughput -,-:;1S9,225;t36 .MMsd per year Requested Monthty Throughput= 11515.00 MMsd per month Potential to Emit(PIE)Throughput 133,225,00 MMsd Per fear Secondary Emissions-Combustion Device(s)for Alr Pollution Control Still Vent Control Dry Gas Throughput Condenser Still Vent Primary Control: 130.560.5 MMsd/yr 11,086]MMsd/month Condenser emission reductionclaimed '` i?e,99,-ted,Condenser Outlet T pro t Degrees Still Vent Secondary Control: 2,6605 MMsd/yr Printerycontroldevlm :,3 50005Cntml EfflcenW% Waste Gas Combusted: Prmary control devim operation: .'1 ,858a: hr/y Regsiezied TOT p �, � xA{.; DegreesF Still Vent Primary Control: 0.0 MNIscf/yr 0.0 MMsd/month Secondary control device: a..: - -% 05%ControlEHklenty% SUIT Vent Secondary Control: 0.4 MMscf/yr Secondary control device operation: ,;, :2_hr/yr Still Vent Gas Heating Value: ;'1195 Btu/sd Still Vern Waste Gas Vent Rate: r252V403 sdh 'NOTE:PRIMARY STILL VENT SCENARIO IS NOT CONSIDERED IN UNCONTROLLED EMISSIONS.SEE NOTES Flash tank Control Dry Gas Throughout Pdmery mrNol deWm: R aly.Ylp3Ct 1DO%:Control Efficiency% Flash Tank Primary Control: 130,560.5 MMsd/yr Primary control device operation 8584.8 hr/yr flash Tank5emndary Control: 2,664.5 MMscf/yr Secondary control daWce: 'k aZe- 95%:Control Efficiency% Waste Rat Combusted: Secondary control device aperat on, 115.2:hrlyr Flash Tank Primary Control: 0.0 MMsd/yr Flash Tenk Gea Heating Value I410'Onu/sd flash Tank Secondary Control: 0.0 MMsd/yr Flesh Tank Waste Gas Vent Rate: 4.47E+03'.sdh 'NOTE:PRIMARY STILL VENT SCENARIO IS NOT CONSIDERED IN UNCONTROLLED EMISSIONS.SEE NOTES Glycol Dehydrator Emissions Inventory • Section 04-Emissions Factors&Methodologies Dehydrator 777 "v 11 = -� nr �"�i zx Y "may 7r 0 ...it iGly 14Dmatknar- taste; Vvefgds p wapt ttra-arn7va yd04 :bazedaly eaery etgas Yyst g'1I i 8liecterr58/23}10*arrta 00 DGFfieoUty mamvd h[a915aeed A ire,A,,w Bg8a7aZe nte3 1j 3 f J I € ' 2 ....._._ ' 3 - Input Parameters Inlet Gas Pressure 3 pzig Inlet Gas Temperature - 80 13J7777(degF Requested Glycol Recirculate Rate - _80._......03H33 HPm Control Scenado STILL VENT Primary Secondary Pollutant Uncontrolled(lb/hr) Controlled(lb/hr) Controlled(lb/hr) VOC =S33 9546-"' 0 6.69773 _ Benzene -_..1250945 1.25472` Toluene ';.1620746 0 0.80333 Ethylbenzene0a-� 0 0 XYlenes : 0700 s'- 0 0.33765 n-Hexane 3.3734 0 0.38867 224-TMP 0.0087 0 0.000435 H25 ,.. 0024 0 0.00145 Control Scenario FLASH TANK Primary Secondary Pollutant Uncontrolled(Ib/hr) Controlled(Ib/hr) Controlled(lb/hr) , VOC 0004190 y- 0 8.245265 Benzene ---:U'6m'L'9:W,-: 0 02033345 Toluene 0,28364:6:; 0 . 0.01438 Ethylbenzene 0 0 o/010 r -: Xylenes -... _0100151 %%f 0 0.002575 n-Hexane --5.8350 0 0.26576 224-TMP 004$9 0 0.000295 H25 1-u3;9.80% 1/il 0 0.80048 Emission Factors Glycol Dehydrator Uncontrolled Controlled (Ib/MMsct) (lb/MMscf) Emission Factor Source Pollutant (Dry Gas Throughput) (Dry Gas Throughput) V. 21.91 0.02 .. 4jJ1II 'its 7 Benzene m037265806 0.00136329 /3 Toluene 0.023669155 0.001183458 Ethylbenzene 0 0 /; Xylene 0.009843222 0.00492161 rHiexane 0.018933646 0.000946682 224TMP 0.00002112 0.000001056 H25 5.58378E-05 279189E-06 ,,,, Still Vent Secondary Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) (Ib/MMsd) Emission Factor Source (Waste Heat (Waste Gas Combusted) Combusted) PM10 s.^81R000t6 16.3251 / P-32si'5 4 2 .&44Z--51 PM25 3..' 55 16.3251 2Ts67;L� 3Inn�bs t� NOx42.026.68-a33.3,-, 148.9880 3#5₹��✓v /)�44, y CO IX4160031,- 679.2100 .- e3..ii,flSt,N 'k5to*,, Flash Tank Secondary Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) )lb/MMscf) Emission Factor Source (Waste Heat (Waste Gas Combusted) Combusted) PM10 0/ 00075 10.5655 f4, °aj P.b12fl/P .5y'/ PM2 1�5 '9 8075 • 10.5655 --,I04.14:0#''. 1:41 .114f, NOs / 0.0680 96.4240 ',Id- CO 03100` 439.5800 .4 'Chapter..- '{GO5 c Section 05.Emissions Inventory Did operator request a buffer? Requested Buffer(0): ,,,,_,,. Potential to Emit Actual Emisslons Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (toro/year) (tons/year) (tons/year) (tons/year) (Ibs/month) PM10 0.9 0.0 0.0 0.0 0.0 1 PM25 0.0 0.0 0.0 0.0 0.0 1 500 0.0 0.0 0.0 0.01 0.01 1 NOx 0.1 0.1 0.1 0.1 0.07 12 CO 0.3 0.3 0.3 0.3 0.33 56 00C 1459.2 1459.2 1.5 1459.2 1.46 248 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ibs/year) (Ibs/year) (Ibs/year) (lbs/year) (Ibs/year) Benzene 4965 4965 240 4965 240 , Toluene 3153 3153 158 3153 158 Ethylbenzene 0 0 0 Xylene ]311 1311 66 1311 66 n-Hewn¢ 2522 2522 6 2522 126 224TMP 10 3 0 H2S 7 7 0 7 0 Section 06-Regulatory Sum-nogg Analysis Regulation 3,Parts A,B Source requiresa permit Regulation 7,Section XVII.B,D Dehydrator is subject to Regdation 7.Section XVII,0,0_3 Regulation 7,Section XVII.B.2.e The control device for this dehydrator is subject to Regulation 7,5ection XVII.0.2.5 Regulation 7,Section 011.0 Dehydrator is subject to Regulation 7,Section XII.H Regulation 8,Part E.MACr Subpart HH(Area) The deity unit meets the benzene exemption Regulation 8,Part E,MACT Subpart HH(Major) You have indicated that this facility Is not subject to Melon Source requirements of MACT HH. Regulation 8,Pan E,MALI-Subpart HHH You have indicated that this facility Is notsub(ect to MACTHH H. (See regulatory applicability worksheet for detailed analysis) • • • Glycol Dehydrator Emissions Inventory • Section e?-Intal and Periodic Sampling and Testing Requirements Was the extended wet gas sample used in the GlyCalc model/Process model site-specific and collected within a year of application submittal? If no,the permit will contain an"Initial Compliance"testing requirement to demonstrate compliance with emission limits Does the company request a control device effidency greater than 95%for a flare or combustion device? s '"-,_ If yes,the permit will contain and initial compllsnretest condition to demonstrate the destruction efficiency of de combustion device based on inlet and outlet concentration sampling lithe company has requested a control device effidency greater than 95%e a thermal neidher or regenerative thermal oxidizer being used to achieve h? No If yes,the permit will contain a conditlon specifying the minimum combustion chamber temperature for the thermal oxidizer la the company using a thermal oxidizer AND requesting a minimum combustion chamber temperature lower than 1,400 degrees F? If yes,the permit will contain en"Initial Compliance"testing requirement AND a permit condition specifying the minimum combustion chamber temperature for the thermal oxidizer,�b Sacd DO¢.Inv 1 A,: Nat _ Apt f t dth ttb d hyd ee at,vi tga tadM d'., p ioon Df flu tlGP' s:k n g d.ct...redrtf rff01 3YAP d rt 4he . Sec rid oY'�pmri'a[ion emi55te I i£f based th post'-4 ud se£strea ions!+,ycale_I ltidryyt r i p t t eof ct I pe atrou slh e3palhr.by-Watu Ts 9r'u kt -4)-a4tlseb„Y r ll0009 3h 6Are doe of k g tie t'gaDF1ys il2oh blue rA RCP d₹14 ",06(r g4P rigit],{, opposedt HHV.This being pond311h esuftmgam1 arynpslgmifirantly33 Tfhe pr ry p t g d ( d m tied p ry 4 f I'xe alypr"xb j pY d d t it d f t T 41.06P'' I d ih I cethm33t'I te're' d of YNtI -. Lela recycleV R In fi evam{tit txb o xyiadale t,.11r Isaatronsid d rtttOtdeywefarpux as Sdt"tble analysis. 1, " .. 3 awn There# ( ... 3P,. 3 �3 3. fihe operator calculalielii 5132 epnssion DSlog,,Dra bat n andth2esoecgttorsth t1D0"%afrll tt].5 resuftirfOqiibitie,dehyd ration - (routed toile busto l rtedtck 2,lfOeoaleufay&S aS " S02(lb(y j_160 ih if2S/y 'r)`v6056 IbS02/ib.m t!5t!i80b'tb2p 5jlbfiailj 1X,✓fi(t5O2fye tJ.#.Orb/yr itts105$buffer)This calculation is a consorvetive estimate based onth6Fpraen, eeeoe+42 mP t n nit titer f eacc@pt bt�tarpe Ittf gpptdi I- 0V, - . An ddu 7 b'II r gip th alp limypwigi>aadded#it'd e the wtam fga t!r x� dbe pP y3tfie-dahyd m d erngvH!�d come,rnsprgcaa limit based dn zb of the totalg 4�haEmayba processed k� 4₹(led iryd Y A yen,t(tapr 3mttr;th r`m3t' fosoxd'i`➢aglae02 Tdtal'lfatjtta11git'ait 'ghpdt 127,750 MM sof/fear and()P 02 Natural gnathro gthpu G in$UcUdo gbyu r g,S55 MMs f/y l 3 015,)11,911,: 333))3 v -- 3 tailliVaPlam *th permit will not' t dnc rdhly pnsaign imid₹ra to m ao lAiihli hi.i ne'^4oq p₹[n nt ofled'mbi { based on a backupic, C4.0enancfs,DCP has d catedthae9h vgdl capto ',Nall downtime clPp te OtfaiVolicafail h n ndsanob n oc GcfaIOlibwbmkedddhWrtopboescvilyb#sta✓svclvO!nile d'only'cmpywmanonan Ili oi will maintain total processaMairice Phis nit p d t rifth Chip mduniyofp any atr d,40,eY M Haw they O be corresoonclin04.hthly,ernission imitsnce the [ lied i lased On alternateRace 33713EMI -- €,L6 33 3 -.The oPR.ka!li'allidirk not aleulafPM [ss- as oW Ceti lllr emb sfia f?tkfS ccaridflashtnk emissions that ase ro utezim and controlled by the p1 (pone 125) The p a tgrasoe'itadthaeslpce3 the flarfklfgded orimbustiCiDaPi4NeTticluleternetteiliialiaced to be generated from the combustion of dehydrator weme gas ranted to this device, in ordettOraddressthis statement-the tbrtfactorsouitafp wmbostlbn einl on(NOxand eo).,1P4?Chapter 135.was reviewed.-hedocvmenf expresses the"emissions-rom raring may foe-10d e carbart particles(soot},unburned hydrocarbonoi.cDOWPfilailit,bumed and altered hyd rbons.blocemrcteo are nitrogen oxides(NOcl and,f sulfur cnnta'nmg materialsuchas hydrogen sulfide orhercepeans is e'.,...,, Tared sulfurdloxldo'(S02I'Eased onttia'statemattyttre document does not provide informet['aa with regards toparticrlaee mateer,except with regards to soot The document further prnvides that asmoking flare directly sre3ultsin soot formation.whet it states".Thetendency of fuel to smoke or make soot is influenced by foul characteristico and be the amount and distributiondf oryl¢n in thecombustion zone."This islortft.Taliiipoited by,footnote'•_"below tabie7,3*.iff ''l��pl1b provides the following;'Soot in concentration values.nonsmoking flares 0mcrograms par lifer(pg/i)t1gh1ly,sit10king Hares,40 pet,average smofddgrlafds,17T1tg/L;.end heavily smokfogfla 5274!IviJi.`.rAeth's time,therein not another source of data that qua ntifes PM5O or PM2.5 from 51dustrat Pares and theroloteitwli be assumed that the rdyoo'la'ceafparico tate Mattiefrome flare is soot t fr 'smoke es expressed in UU'-41fhapte r135. , .104Oilid be noted tli,fthnnd mA.pmun requires that dailynif erks he conducifpfOrnin.e.fthe flare-smoking,if smoke a chromed during the daily dieckthe source sregqtedt either conduct a method 22 ' fitaMeaTfataly but thas,aq4ritenlito investigate the. of the ok and conduct repairs as necessarh Based on the requirement for the flare an d the manufacturer design for the flareic be smokeless ff,:). peeocedp p lyitt emaeraki)liba:asumekilaqbeifla re will operate without smoke on a regular besisalso,fsmoke is observed th"operate rwill be required to assess the problem and perform necessary, ..f H tcA ey peyenttbe'f£a lf eo ikri't!Suvhi m comfortable as-sliming a Spot concerrr"tion of micrograms per iReresprovided to AP-42€hapter135nornonsmokingflares- .'._ " t still yens and flash tank's i-ians toe VRut II ttrerlt mthdtsF Idbe- ms derail lS}th tthesource re pem�cted:a pnnr Ty route qb recycled.The VRU is only permitted to have amax of 2%annual dewrnitgPiOi g,Ndtmchfitni55iatuyf7(bu;r+jue dto the lace If the total PM emissohfactor of76lbr,c Ms from AP-4P Chaplef31AWE ed,the total PM us,vulucco(for both PM 10 and .51 would only be_ p renpo , OAOg FpQ chic ry m Il'm £ot d Id t result n permit 1 colts fact PM of resurc n add Van I g 1 Cory regn emenis. N svinritheafaapati ¢'ws&d`above,it a deteuntiiithatthe operator'sassertion that mokeless nom-would oatexpedbcbto,have PM emissions was valid.However,if in the future better data d lopedtbnant t vP'Agrq3Y ynp fm d at l ll[ d ho idb Ida future analyse_ 333' l * 110 €{h dd parmrt 4h appRant emimI rely 111th p 4giapTyth t:th Fornt'idadcat dVRU ach process vent ll sill ce m fleshtank).Downtime wit,be tracked seaprately for hyRU(Stll iYRU ndUia hll 3]yii€lklia d tad Ty bee pt 2 claw con fur 5hldy3 ci d pt 2%d me for Plash Tank Vat.54e its d. ₹tpon ht''hl draftpc ie ppll' rrequestacl mpd{yp Obtang g rq l0,4 lllpt ..:[ gefthot(')wet g plume a£thed hydC t rinlet or{fdry gas volume at the aclehyd'ialor outlet;; Itto d ed and agreedtnel rd rdeallawimt Solo bitity BGF0 dmd 'd„athateea dl to pfac net fib.at the i nib-CUPmftlevj'Lhi 40,0bd usilurne.would be assumed equivalent toth dfy i a v l manor P'Poa oflDpal gip isdiyc IgAppi pnat0 ev madetuthep rm4S.{ago dateth q i • Section 119-Inventory SCC Coding and Emissions Factors Uncontrolled AIRS Poirrt# Process ft KC Code � Pollutant Emissions Factor Control% Units 002 01 'a,YICal ddlh ..�"w i 9;„LsF c'T.A`". ,.,,?„' .rG ,/„"d PM30 0.000 0.0 b/MMuf PM2.5 0.000 0.0 b/MMsd 900 0.000 0.0 b/Mhilscf NOx 0.001 0.0 b/MMsd VOC 219 99.9 b/MMsd CO 0.015 0.0 b/MMsd Benzene 0.037 95.0 b/MMscf Toluene 0.024 95.0 b/MMscf Xylene 0.010 95.0 b/MMscf n-Hexane 0.019 95.0 b/MMuf 224 TMP 0.000 95.0 b/MMsd • Dehydrator Regulatory Analysis Worksheet • Colorado Regulation 3 Parts A and B-APEN and Permit Re uirements - - Source is in the Non-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 greaterthan 10 TPY(Regulation 3,Part B,Section II.D.3)? 'You have indicated that source is in the Non-Attainment Area NON-ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greaterthan 1 TPY(Regulation 3,Part A,Section 2. Are total facility uncontrolled VOC emissions from the greater than 2 TPY,NOx greater than S TPY or CO emissions greater than 5 TPY(Regulation 3,Part B,Section 11.O.2)? 'Source requires a permit - Colorado Regulation 7,Section XII.H 1. Is this glycol natural gas dehydrator located in the 8-hr ozone control area or any ozone non-attainment area or attainment/maintenance area(Reg 7,.Section XII.H.1 and 2)? Yes 2. Is this glycol natural gas dehydrator located at an oil and gas exploration and production operation',natural gas compressor station,natural gas drip station or gas-processing plant(Reg 7 Section Yes, 3. Is the sum of actual uncontrolled emissions of VOC from any single dehydrator or group of dehydrators at a single stationary source equal to or greater than 15 tpy(Reg 7,Section XII.H.3.b)? 4. Are actual uncontrolled emissionsofVOC from the individual glycol natural gas dehydrator equal to or greater than 1 tpy(Reg 7,Section XILH.3.a)? 'Dehydrator is subject to Regulation 7,Section XII.H Section XII.H—Emission Reductions from glycol natural gas dehydrators MACT Analysis 1. Is the dehydrator located at an oil and natural gas production facility that meets ether of the following criteria: Yes a.A facility that processes,upgrades or stores hydrocarbon liquids'(63.760(a)(2));OR 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 b.end user'(63.760(a)(3))? 2. Is the dehydrator located at a facility that is a major source for HAPs? IGo to MACT HH Area Source Requirement section to determine MACT HH applicability 40 CFR,Part 63,Subpart MALI HH,Oil and Gas Production Facilities Area Source Requirements 1. Is the dehydrator a triethylene glycol(TEG)dehydration unit(63.760(b)(2))? Yes Exemptions 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day(63.764(e)(1)(i)? 26. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr(63.764(e((1)(6)? 3. Is the unit located inside of a UA plus offset and UC boundary area? The dehy unit meets the benzene exemption Subpart A,General provisionsper§63.764(a)Table 2 . §63.765-Emissions Control Standards Do Not Apply §63.773-Monitoring Standards Do Not Apply §63.774-Recordkeeping §63.775-Reporting Standards Do Not Apply Maior Source Requirements 1. Does the facility have a facility-wide actual annual average natural gas throughput less than 0.65 MMscf/day AND a facility-wide actual annual average hydrocarbon liquid throughput less than 249.7i. lJii,. Small or Large Dehy Determination 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day(63.761)? - � 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr(63.761)7 - / ._ Small Dehy Requirements 3. Did construction of the small glycol dehydration unit commence on or before August 23,2011(63.760(b)(1)(i)(B)and(C)? .'1//j 4. For this small dehy,is a control device required to meet the BTEX emission limit given by the applicable equation? Iyou have indicated that this facility is not subject to Major Source requirements of MACT HP. Subpart A,General provisions per§63.764(a)Table 2 §63.765-Emissions Control Standards• §63.773-Monitoring . §63.774-Recordkeeping §63.775-Reporting 40 CFR,Part 63,Subpart MACT HHH,Natural Gas Transmission and Storage Facilities 1 Is the facility wide actual annual average natural gas throughput less than 0.9994051 MMscf/day and glycol dehydrators the only HAP emission source(63.1270(f))? _ G4 Small or Large Dehy Determination 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 9.994051 MMscf per day(63.1270(b((2)(? 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr)63.1270(b)(2))? Small Dehv Requirements 3. Did construction of the small glycol dehydration unit commence on or before August 23,2011(63.1270(6)(2)and(3))? 4. For this small dehy,is a control device required to meet the BTEX emission limit(standard?)given by the applicable equation? You have indicated that this facility is not subject to MACT HHH. Subpart A,General provisions per 463.1274(a)Table 2 §63.1275-Emissions Control Standards §63.1281-Control Equipment Standards §63.1283-Inspection and Monitoring §63.1284-Record keeping §63.1285-Reporting Colorado Regulation 7,Section XVII.D 1. Is the dehydrator subject to an emissions control requirement under MACT HP or HHH(Regulation 7,Section XVII.B.5)? No 2. Is this dehydrator located at a transmission/storage facility? No 3. Is this dehydrator located at an oil and gas exploration and production operation,natural gas compressor station or gas processing plant(Reg 7,Section XVII.D.3)? Yes 4. Was this glycol natural gas dehydrator constructed before May 1,2015(Reg 7 Section XVII.D.4.b)7 If constructed prior to May 1,2015,are uncontrolled actual emissions from a single glycol natural gas dehydrator equal to or greater than 6 tons per year VOC or 2 tpy VOC if the 4a. dehydrator is located within 1,320 feet of a building unit or designated outside activity area(Reg 7,Section XVII.D.4.b)7 5. If constructed on or after May 1,2015,are uncontrolled actual emissions from a single glycol natural gas dehydrator equal to or greater than 2tpy VOC(Regulation 7,Section XVII.D.4.a)? 'Dehydrator is subject to Regulation 7,Section XVII,B,D.3 Section XVII.B—General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.D.3-Emissions Reduction Provisions Alternative Emissions Control(Optional Section) 6. Is this glycol natural gas dehydrator controlled by a back-up or afernate combustion device(i.e.,not the primary control device)that is not enclosed? I The control device for this dehydrator is subject to Regulation 7,Section XVII.B.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. Glycol Dehydrator Emissions Inventory 003 Dehydrator IFarllity AIRS ID: i'i',!:....TiLLT4.4LLLENLEMigniTiELTLLigi"iLLNOLLItg5IMaMi [o tV Plant Point Secston 02-Equipment Description Oetelis __ DehydrntorlMonnatlan Dehydrator Type: Make TEE)y� Model: - TED- 7 Senel Number. ' d 7 Design Caeadt)•. • C2T6 r,,.MMsd/daY • Reorculation Pump IMorma0on. NumberMPumps 4TH Pump Type Melee: LPN, 33 j TEFL � Model: rr` tu.}3733 TBti a Design/Mac Recrculation Rate; �:, i• 3d1,33.....M! , gallons/minute Deb./drat.'Equipment Flash Tank IMPOIIIVZI& and flesh tank Reborkr Burner �' Stripping Gas -0 ..t ne(11 Triethylene glycol(TED)000ccral gas dehydration urtit(Make:TOO,Model:TEO,Serial Number:TOO)with a desgn capacity at 230 MMsct perday.This emissions unit is equipped with 2(Make:TOO,Model:TED)electric driven glycol pump with design capacity of as gallons per minute.This dehydration unite equipped with a still vent Dehydrator Equipment Description and flash tank. Emisslors from the still vent are routed to an elr-cooled condenser,and then ro the Vapor Recovery Unit(000).Asa secnndary control device,still Vera emieslOno are routed tothe Open Flare.Emissionsfromthetazhtankarerouted direcdytothe Vapor Rec0.very Unit(VRU).Asa secondaryoontrol devim,Rashtankemissfore are roUtndtothe Emission Contra)Device Description: Open Flare. - - Section 03-Proressimt Rata IMermav'en for Emissions Estimates Primary Emissions-Dehydrator Still Vent and Flash Tank(If present) Requested Permit limn Throughpet '.'.83,950.00 MMsd peryeer Requested MonthNThraughput= 7130.00 MMsd per month I Potential to Emit IKE)Throughput= 83,950.00 MMscf per year Secondary Emissions-Com bustlo4 Devlra(s(for Alr Poll ud on Control Still Vent Control _ DryGas Throughout Condenser. -1,1018888a88888 Still Vent Primary Control: 82,271.0 MMsd/yr 6,087.4 MMsd/month Condenser emission reduction claimed: r Requested Condenser Outlet T pre ORM488 8R4& D grew F Still Vent Secondary Control: 1,679.0 MMsd/yr Primary control deNra: !2 }-,may. --#UDC tol Efficiecy% Wane Gas Combuted: Primary control device operation: ,;>i ,0584.8h/y Requested TO Temp .TT r✓ )f.iiG Degrees F Still Vent Primary Control: 0.0 MMscf/yr 0.0 MMsd/menth Secondarywntrol device ,V. ,.m•, F95%ControlERaienry% Still Vent Secondary Control: 0.2 MMsd/yr Secondary control deuce operatom ;'175,2't hr/yr• 511 Vent Gas Heating Value; '1478Bto/sd am Vent Waste Gas Vent Rate: "1:4504 8 sdh 'NOTE:PRIMARY STILL VENT SCENARIO IS NOT CONSIDERED IN UNCONTROLLED EMISSIONS.SEE NOTES Flash tank Control Dry Gas Throughout Primary control device: •, 2,555EASSOMiControl Efficiency% Flash Tank Primary Control 82,271.0 MMsd/yr Primary control device operation: RgilhlitlffSrlft4"75klks/Ts Flash Tank Secondary Cootaol: 1,679.0 MMsd/yr Secondary mntral deuce: I -95%Control ENicienry% Waste Gas Combusted: Secondary control device operation: 33 iii k3 1882 hr/yr Flash Tank Primary Control: 0.0 MMsd/yr Flash Tank Gas Heating Value l))'; 1173 3 254G_Etu/sd Flash Tank Secondary Control: 0.5 MMsd/yr Flash Tank Waste Gas Vent Rate: I,'TL;iij;�;d32348,EW9 adh 'NOTE:PRIMARY STILL VENT SCENARIO IS NOT CONSIDERED IN UNCONTROLLED EMISSIONS.SEE NOTES Glycol Dehydrator Emissions Inventory Section 04-Emissions Factors&Methodologies -* Dehydramr P ₹^- _ Po 3j3333 Th sad GR0 Gly 140t es0 to I t 0iW b Pas1t Jo4u�a'acvrnrota tm be�% 94ges� Lyd 77cted 10/27/16f 1 t OCPf ,01She mkiWa dP,POP Pkri.do'7ng7tatsmkoi ij) - ��aa33 y, P InPat Parameters ••• •• •.. ....im Inter Gas Pressure 67& Pie Inlet Gas Temperature 8D .'fiz"d g F Requested Glycol Recirculate Rate h`(&C 'I ;gpm Control Scenario STILL VENT Primary Secondary Pollutant Uncontrolled(Ib/hr) Controlled(lb/hr) Controlled(Ib/hr) Ib51 Ib/yr w/buffer VOC .;.000033,14?*`*., 0 4.595095 Benzene 3,3.x77/3780$ai ) 0 0.8339 146 161 Toluene N34 IA SS 31/3130' 0 0533425 93 103 Ethylbenzene /';: jr F 3 0 0 - 0 0 Xylenes 4,4Il 0 0.223 39 43 n-Hexane ," -.s,09404.44i,_ 4 0 0.2597 45 50 224-TMp 00058' Z'r1 0 0.00029 0 0 H21 h.10`U39`4tti)))) 0 000097 0 0 Control Scenario FLASH-TANK Primary secondary Pollutant Uncontrolled(ib/hr) Controlled(lb/hr) Controlled(lb/hr) Iblyr Ib/yrw/buffer VOC 130,0244 0 5.50122 Benzene _D 4430 0 0.02215 4 4 Toluene 10.1996 0 0.00953 2 2 Ethylbenzene - 0 _ 0 0 0 0 XYienes ' 0034:f.,:, 0 0.0017 0 0 n-Hexane 3.54033,33tt 0 0.177285 31 34 224-TMP =;000094//,'f5.',^. 0 0.000195 0 0 H25 ' 0"0064 /A. 0 0.00032 Emission Factors Glycol Dehydrator Uncontrolled Controlled Pollutant (Ib/MMsct) (lb/MNIscf) Emission Factor Solace Throughput) (Dry Gas Throughput) VOC _ o.w 0.02 8ensne 0.039303063 Ot%11965393 a Toluene 0.024931012 0.001246551 -t --. _ Ethyiberuene 0 0 Xylene 0.010316661 0.0005;5833 /f� n-Hvane 0.020063311 0.001003166 /;�/ - �/' Z24TMP 2.22678E-05 1.11339E-0fi t4A` ' H25 5.92278E-05 2.96139E-06 !. "*"/ 3 ktt_t';¢tW/.2: , SUIT Vent Secondary Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) (Ib/MMscn Emission Factor Source (Waste Heat (Waste Gas Combusted) Combusted) PM10 tl0075 11.0125 h t 3.4a'jfNdSOjP27 2g5":T* it 7 PM3.5 "0,1076 t' 11.0125 .5.f A*2(PG119J .5 1. NOx .00680E 100.5040 4.ThP TR5 f' CO ,..:`.0.1300 %?X;I. 45&1800 2 GT3.5Mdtwi af,F j¢ .." y. Flash Tank Secondary Control Device Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (Ib/MMscf) Emission Factor Source (Waste Heat (Waste Gas Combusted) Combusted) PM30 - 00075 11,5192 Sda42T 4F 1.AA� r1.-AM*"` r PM2.5 00075 11.5192 �'4' .42T Lie3.2 NOx .'.A 0680 105.1280 / T „53it{i cD 4.3100 479.2600 i 8P-424iiij' 118{} _ R Section 05-Emissions Inventory Did operator request a buffer? t' ;AO Requested Buffer(%): P'�./!./..`."H11.T_ Potential to Emit Actual Emissions Requested Permit LimOS Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled ltnns/year) (tans/year) (cons/year) (tans/year) (tons/year) (Ibs/month) PM10 0.0 0.0 0.0 0.0 0.00 1 Pk/a5 00 0.0 0.0 0.00 0.00 1 sox 00 0.0 0.0 o.00s O.00 1 NOx 0.0 0.0 0.0 0.04 0.04 7 CO 0.2 0.2 0.2 0.2 0.20 34 VOC 19.5 19.5 1.0 19.5 0.97 105 Potential to/m6 Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ibs/year) llbs/year) (l4s/year) •(Ibs/year) (Ibs/year) Benaene 3300 3300 165 3300 165 Toluene 2093 2033 105 2093 105 Ethylbenzene 0 0 0 0 %ylene866 866 43 866 43 nHexane 1684 1684 84 1684 84 224TMP 2 2 0 2 0 H2S S S 0 5 0 Section O6-Regulatory Summary Analysis Regulation 3,Parts A,B Source regwres a permit Regulation 7,Section 0011.0,0 Dehydrator's subject to Regulation 7.Section XVII,0,03 Regulation 7,Section XVII.B.2.e The control device for thA dehydrator is subject t0 Regulation 7,section XVII.B.2.e Regulation 7,Section Xll.H Dehydrator is subject to Regulation 7,Section 011.4 Regulation B,Part E,MACT Subpart HH(Area) The dehytalk meets the benzene exemptan Regulation B,Part E,MACr Subpart HH(Major) You have Indicated that this facillty A not subject to Major Source requirements of MACTHH. Regulation B,Part E,MACT Subpart HHH You have Indicated that this facility Is not subject to MAR HHH. (See regulatory applicability worksheet for detailed analysis) Glycol Dehydrator Emissions Inventory Section 07 Initial and Periodic Sampling and Testing Requirements Was the extended wet gas sample aced In the GlyCalc model/Process model site-speciflc and collected within a year of application submittal? If no,the permit will contain an"Initial Compliance"testing requirement to demonstrate compliance with emission limits Does the company request a control device effioency greater than 95%f ore flare or combustion device? If vim,the permit will contain and initial compliance cost condition to demontrate the destruction eRldenry ofthe combustion device based on Inlet and outlet concentration sampling lithe company has requested a control deviceeffidency greater than 95%,isa thermal oxidzer or regenerative thermal oxidlzer being used to achieve R? No If yes,the permit will contain a condition specifying-he minimum combustion chembertemperature for the thermal oddher Is the company using a thermal oxid'uer AND requesting a minimum combustion chamber temperature lowerthan 1,400 degrees FT If yes,the permit will contain an"Initial Compliance"testing requirement AND a permit condition specifying the minmum combustion chamber temperature far the thermal oxidizer. Section OS-Technical Analoplpruotes- �,,„., ;r: 'Applicant has ndicatedtt+llatihedehydratcrstifventgne epoytddoa iud"unser prior to the VRU or flare.DCP is not takligemission reduction credit from VOC and HAP removed in the oondebser.Th secondary combustion emfasionalculadons are based on the pos£-cotndenser'stream from GlyCalcslncett is more representative of actual operatiOn.3lnce primarily water is removed-in condense,the btu/hr; flow to the flare does not changosigniAontlysinceD2?has HHVotff.DCP usedi.HV in their ernisawnz;icutationsas opposed to H HV.Ths s beirigaccepted as the resulting emissions vary Insignificantly, '. 'The primary operating scenarialle.identified as oilman/control scenario anaksis:above)is not considered in.uncontrolreid emissions cakulations.Ths is based on the faathat thereat.redundant Mrs in placeto recyde vapors in the etentthatthe primaryls down.Therefore,theVRU is not conslderede controldevitafor purposes of tills analysis, - - ^The operator calculated 5o2 emissions using a mass balance andtheassumptwn that 100%of the H25resuking from the dehydration sort(routed.the combustor)Is convertedto5OL The calculation Das fo((owst _; 502(lb/year)=(5 lb H25/year)'is4.DDGlb 502/lb-mol)/134.0009 lb₹f2S/Ib-rnpll=9Ib/yr(This calculation is a conservative estimate based onthe:representative H2S composition andtherefore acceptable for -.-petmiming purposes 1.,41 additional process limit Wilk be added to address the volommof gas that could be processed by the dehydrator during VRU downtime.This process)knits based on 2%ofthetotalgesthe;may:be processed by the dehydrator.As a result,the process limits in the permit are nowas follow:(i)Process 0l Total naturulgasthroughput_83,950MMscf/yearand girl Process 02-Natural gas throughput during VRO downtime= 1,679 MMscf/Year +, - "The peenitwll not include monthly emission limits Forths source,Although this D a new source,the coMmiledernission rates are based on a backupcontroi scenarios.DCP has:inthateduhattheoccuonce of VRU downtime could potentialy.ntrurail in one month and cannot be-forseably broken down on a monthly-basis.Assuch,DCP needontyuempiy with an annual limit-1 WD maintain-aspoMhlyproeess limit'for to tal gas processed since this is:indeperident of the monthly amount of primarymntrol device downtime.However,there will not beacornmpending monthly emission limitsincethecontroiledemissiots are based an alternate process sce®coos. 'The operator did not talculatePM-emissions associated with the combustion ofshll vent and flash tank emissions that are routed to and controlled by the:plantflaro(polnt125)..The operator asserted that since the flare is desgnedto be a smokeless oombustion device,pa r[ic latematter is not expected to be generated from the combustion o€dehydrator waste gas:routed to this device. In:0rdcrto eddressthsstatementthe emission factor source for-combustionamiss ens(Nov andCO),AP-42Chapt r135„was reviewed Thisdocumenf expressesthe'emissions Cone flaring may Include carbon''. particles(soot),unburned hydrocarbons,CO end partially binned and altered hydrocarbons.Also emitted are Mocncccxdes.(woxl aid,If sulfur contain hg materialsosh ashydrogensulfldegp.mercaptansis oo flared,sulfur (502)-'Based onthl0 statement,the document does notprovldo Information with regards to particulate matter,except with regards to soot.The dccumentfurtherprphldos than a smoking I flare directly results in soot formation when o it states'The tendency of a fuel tsmoke or make soot is influenced by fuel characteristics and by the amount and disenbition of oxygen in the combustion zone'This is'further supported by footnote e05 below table 13.5.1 which provides the following,'.Soot n concentratonva€ues,nonsriokingftares,a micrograms per liter(µg/L);lightly smoking lSres,40 pet:,avenge cooking flares,177ge/L;andheavly smoking flares,274 hg/L"At the time,the not anothersource0fdatb that quantifies PMiO arPM25 from industrialflaresandtherefarekwlf beassumed that the s s only sourze of particulate metter€ flare is so.from smoke as expressed in AP-42 Chapter 13-5. -2 should be noted that the O&M plan-requiresthat daily checks beoatductedto determine if the flareassrooking,ifsmoke is observed durmglheilalycheekthe source-isrequteedto eiiharoonduct a method 22 or mmediately shut it the equipment to investigate the cause of the smoke and conduct repairs asnecrosaly,Rased on this requirement forthe flare andtltemanufactlrerdesigtrfortheflare to he smokeless a operated properly,it can safelyde assumed Mettle flare willaparatewhhoutsmohe one regular bass.Aaglfsmoke Is observed,the operator=o1 ill h:requiredtoasses.the problem and perform necessary maintenance to prevent the flaaefr msnaking.As such,I am comfsrtableassuming a soot concentration of 0 micrograms perliteras provided in AP-42 Chapter 125for nonsmoking flares..: One other item that should be consideredis that the source is permuted to primarily route still vent and flash tank emissions toe VRU to be recycled;The VRU is only p itted to haveamax;of 2%annual downtime during which emissions will he routed to the flare.If the total PM emission factor of 7.6.1b/MMscf from AP-42 Chapter 1.4 were used,the total PM.emissions(for both PM:lO and 2.5)would only he 0.005tpy.This sa very small:amount of emissions and would not resuhn permit limits for PM or result maddrtuon al regulatory requirements. Rased on themformatior,dtscussed 1 unsound above,itwas deManin eothat the operator's assertion that a smokeless flare would not be ekpectedto have PM rr,o, cis asvald.However,If hill future better data is developed for estimating PM emissions from industrial fie res it should be included n future analyss. `upon review of the draft Permit,the applicant requested that the permit dardythatthere are separate dedcetedVnUsforeach process vent(e.still vent and flash tank),Downtime wi0 be tracked seepratelyfor each VRU(Still vent VRU and flash Tank VRtn.Retrisionsweremade to clarify that up to 2%downtme fnrSOl Vent VRU and up tot%downtenefor Flash Tank VRU 5 permitted. 'boon review of the draft permit, equested to modify permit language to allow for flexibility in monitoringaahanlfl wet gasvolumeatihedehydtatarirtoror(Illdnygasvolume at the dehydrator outlet it was discussed and agreedthat order.allow 04atiex,b,Ien,DCPwouldassumeuhat regardisss of meter placemnet(e at the inlet the metered volume would be assumed equivalenttothe"dry gas"volume for purposes of input wines to GlyCalc.Appropriate revisions were made tothe permitter accomodatethis request. Section 09-Inventory SCC Coding and Emisiors Factors Uncontrolled AIRS Pointft Process# sCC Cod _�,^ Pollutant Emissions Factor 0ant ol% Units CO3 01 'n4¢0 s.wss`i c w3ngiyhia}p(8./nbmHnf yep[ etlty�ccm.RI/no) ..y PM10 O.IX0 0.0 b/MMscf PM75 0.1100 0.0 b/MMscf SOx 0.000 0.0 b/MMscf 000 0.001 0.0 b/MMscf VOC 0.5 950 b/MMscf CO 0.005 0.0 b/MMscf Benzene 0.039 95.0 b/MMscf Toluene 0.025 950 b/MMscf Xylene 0.010 950 b/MMscf n-Hexane 0.020 95.0 b/MMscf 224TMP 0.000 95.0 b/MMscf Dehydrator Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B-APEN and Permit Re•uirements Source is in the Non-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 11.D.3)? 'You have indicated that source is in the Non-Attainment Area NON-ATTAINMENT 119999 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)? Wrr 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 ll,D.2)? 'Source requires a permit Colorado Regulation 7,Section XII.H 1. Is this glycol natural gas dehydrator located in the 8-hr ozone control area or any ozone non-attainment area or attainment/maintenance area(Reg 7,Section XII.H.1 and 2)? Yes 2. Is this glycol natural gas dehydrator located at an oil and gas exploration and production operation,natural gas compressor station,natural gas drip station or gas-processing plant(Reg 7 Section Yes 3. Is the sum of actual uncontrolled emissions of VOC from any single dehydrator or group of dehydrators at a single stationary source equal to or greater than 15 tpy(Reg 7,Section XII.H.3.b)? 4. Are actual uncontrolled emissions of VOC from the individual glycol natural gas dehydrator equal to or greater than 1 tpy(Reg 7,Section XII.H.3.a)? reg, ". Dehydrator is subject to Regulation 7,Section XII.H Section XII.H—Emission Reductions from glycol natural gas dehydrators MACT Analysis 1. Is the dehydrator located at an oil and natural gas production facility that meets either of the following criteria: Yes a.Afacility that processes,upgrades or stores hydrocarbon liquids'(63.700(a((2));OR 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 b.end user"(53.760(a((3))? 2. Is the dehydrator located at a facility that is a major source for HAPs? 1441,1 Ion to MACT HH Area Source Requirement section to determine MACT HH applicability 40 CFR,Part 63,Subpart MACI'NH,Oil and Gas Production Facilities Area Source Requirements 1. Is the dehydrator a trthylene glycol(TEG)dehydration unit(63.760(b)(2))? Yes Exemptions 2a. Isthe actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day(63.764(e)(1)(i)? 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr(63.764(e)(1)(ii)? 3. Is the unit located inside of a UA plus offset and UC boundary area? The dehy unit meets the benzene exemption Subpart A,General provisions per§63.764(a)Table 2 §63.765-Emissions Control Standards Do Not Apply §63.773-Monitoring Standards Do Not Apply §63.774-Recordkeeping §63.775-Reporting Standards Do Not Apply Major Source Requirements 1. Does the facility have a facility-wide actual annual average natural gas throughput less than 0.65 MMscf/day AND a facility-wide actual annual average hydrocarbon liquid throughput less than 249.7 Small or Large Dehy Determination 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day(63.761)? ≥ 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr(63.761)? Small Dehy Requirements 3. Did construction of the small glycol dehydration unit commence on or before August 23,2011(63.760(b)(1)(i)(B)and(C)? 4. For this small dehy,is a control device required to meet the BTEX emission limit given by the applicable equation? I� . IYou have indicated that this facility is not subject to Major Source requirements of MACE HH. Subpart A,General provisions per§63.764(a)Table 2 ' §63.765-Emissions Control Standards §63.773-Monitoring §63.774-Recordkeeping §63.775-Reporting 40 CFR,Part 63,Subpart MAD HHH,Natural Gas Transmission and Storage Facilities 1 Is the facility wide actual annual average natural gas throughput less than 0.9994051 MMscf/day and glycol dehydrators the only HAP emission source(63.1270(f))? A Small or Large Dehy Determination 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 9.994051 MMscf per day(63.1270(b)(2)j? , x1 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr(63.1270(b)(2))? Small Dehy Requirements glycol dehydration August ( ()( ) ()) s ri 3. Did construction of the small I col unit commence on or before 23,2011 63.1270 6 2 and 3 7 �-�' 4. For this small dehy,is a control device required to meet the BTEX emission limit(standard?)given by the applicable equation? 'r� You have indicated that this facility is not subject to MALT HHH. Subpart A,General provisions per§63.1274(a)Table 2 §63.1275-Emissions Control Standards §63.1281-Control Equipment Standards §63.1283-Inspection and Monitoring §63.1284-Recordkeeping §63.1285-Reporting Colorado Regulation 7,Section XVII-D 1. Is the dehydrator subject to an emissions control requirement under MAD HH or HHH(Regulation 7,Section XVII.B.5)? No 2. Is this dehydrator located at a transmission/storage facility? No • 3. Is this dehydrator located at an oil and gas exploration and production operation,natural gas compressor station or gas processing plant(Reg 7,Section XVII.D.3)? Yes 4. Was this glycol natural gas dehydrator constructed before May 1,2015(Reg 7 Section XVII.D.4.b)? If constructed prior to May 1,2015,are uncontrolled actual emissionsfrom a single glycol natural gas dehydrator equal to or greater than 6 tons per year VOC or 2 tpy VOC if the 4a. dehydrator is located within 1,320 feet of a building unit or designated outside activity area(Reg 7,Section XVII.D.4.b)? 5. If constructed on or after May 1,2015,are uncontrolled actual emissionsfrom a single glycol natural gas dehydrator equal to or greater than 2tpy VOC(Regulation 7,Section XVII.D.4.a)? 'Dehydrator is subject to Regulation 7,Section XVII,B,0.3 Section XVII.B—General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.D.3-Emissions Reduction Provisions Alternative Emissions Control(Optional Section) 6. Is this glycol natural gas dehydrator controlled by a back-up or aiternate combustion device(i.e.,not the primary control device)that is not enclosed? *WOO,I IThe control device for this dehydrator is subject to Regulation 7,Section XVII.B.2.e Section XVII.8.2.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. • Natural Gas Heater Emissions Inventory 004&005 NG Heater Facility AIRS ID: u I v "aikr,a.1c 1 dam. y,,,PO4-00S_ County Plant Pont 'Point 004 and 005 are identical make/model heaters used for the same purpose with the respective process trains.This analysis applies to each heater individually. Section 02-Equipment Description Details Heater Information Fuel Type - Natural Gas Number of Heaters 1 3„f.3.One(1) Purpose 'Ft-.YaS. 3�$l .� Make: Tulsa leaters Midstream l Model: 7�$HfOT280 I I Serial Number: 1010 _ f` 11: Design Heat Input Rate: ll- 23^33:: 't� 3.;MMBtu/hr Equipped with Low-NOx burners: */`; Equipped with Add-On Control Equipment: '44.,1.?; -;:tNihfcAVE :AM, One(1)natural gas heater(Manufacturer:Tulsa Heaters Midstream,Model:5401250,Serial Number:TBD)each with a design heat input rote of 23.33 MMBtu/hr.Each unit is equipped with low-NOx burners.This unit is used as a Detailed Emissions Unit Description: molecular sieve regeneration heater. No add-on control equipment Emission Control Device Description: Aj Requested Overall VOC&HAP Control Efficiency%: „ r ,Low NOx combustion system is considered an integral control device. Section 03-Processing Rate Information for Emissions Estimates Design Heat Input Rate= 23.33 MMBtu/hr Heat content of waste gas= ll, 1050 Btu/scf Actual Hours of Operation= hrs/year Requested Hours of Operation= 8760 hrs/year Requested heat input rate= 143,059.56 MMBTU per year 'Limited to 70%annual fuel use per applicant(see notes in section 08) Actual Fuel Consumption= 0.00 MMscf/year Requested Fuel Consumption= 136.25 MMscf/year Requested Monthly Throughput= 11.57 MMscf per month Potential to Emit(PTE)Fuel Consumption= 194.64 MMscf/year Section 04-Emissions Factors&Methodologies Emission Factors Uncontrolled Uncontrolled Ib/MMBtu lb/MMscf Pollutant Emission Factor Source (Fuel Heat [Fuel Combusted) Consumption) PM30 0.0052 ®: ,,, e .:*° PM2.5 0.0052 ® eesafk D• SOx 0.00057 •� , 2.7 ;'3f '''d" - NOx 0.04742 :IMMEIN CO 0.08000 .•,IIMEM " av VOC 0.80524. ®e:....:.:.'iE!ms.•, , !Formaldehyde 0.00007- sg/ta,•. IlliffetEEIIIII0.00000 0.0021 -;immitemaciii Toluene 0:00000 0.0034 0.00171 ... Section 05-Emissions Inventory . Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Critena Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month) PM10 0.54 0.00 0.00 0.37 0.37 63.6 PM2.5 0.54 0.00 0.00 0.37 0.37 63.6 500 0.06 0.00 0.00 0.04 0.04 6.9 NOx 4.87 0.00 0.00 3.41 3.41 578.6 CO 8.37 0.00 0.00 5.72 5.72- 972.0 VOC 0.54 0.00 0.00 0.37 0.37 63.6 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants _ Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (lbs/year) llbs/yearl (lbs/year) (lbs/year) Formaldehyde 15 0 0 10 10 Benzene 0 0 0 0.3 0.3 Toluene 1 0 0 0.5 0.5 n-Hexane 350 0 0 245 245 17 of 65 K:\PA\2018\18W E0465.CP1-xlsm • • Natural Gas Heater Emissions Inventory Section 06-Regulatory Summary Analysis Regulation 3,Parts A,B Source requires a permit Regulation 1,Section VI Based on the requested emissions and emission factor,compliance is presumed. Based on the design heat input rate,the source is subject to Regulation 1Section III.A.1.c.and Regulation 6,Part B,Section II.C.3.Based on the requested Regulation 1,Section III&Regulation 6,Part B,Section II emission factor,compliance is presumed. Regulation 6,Part A,Subpart Db,502 Standards Source is not subject to NSPS Db. Regulation 6,Part A,SubpartDb,NOx Standards Source is not subject to NSPS Db. Regulation 6,Part A,Subpart Dc - Source is subject to NSPS Dc. Regulation 7,Section XVI.D Source is not subject to Regulation 7,Section XVI.D. Regulation 8,Part E,MACE Subpart DDDDD Source is not subject to MACT DDDDD. • (See regulatory applicabilityworksheet for detailed analysis) Section 07-Initial and Periodic Sampling and Testing Requirements Is the project close to the 40 tpy modeling/NANSR threshold for NOx? > yx If yes,stack-testing should be required for NOx,as well as for CO. Is the operator limiting their heat input rate below the design rate? If yes,stack-testing should be required for NOx,as well as for CO. Is the project close to the 5 tpy modeling threshold for PM 2.5? Yes _ If yes,stack-testing should be required for PM 2.5 'See note in section 08 Mgr Does the company use AP-42 emission faders(or more conservative factors)? If no and testing hasn't already been required due to proximity to modeling thresholds,testing should be required for any pollutants for which alternative emission factors have been used.If testing is being done for only NOx or only CO,the other should be included as well. • Section 08-Technical Analysis Notes This source uses plant reside gas as fuel.Applicant usedresidue gas HRSof1050 btu/scf based on a residuegas analysis torn a similarDCP facility. '.Theemisignsfactgrsfrom AP-42 Chapter LA used tacatculate emissions homthis source are based on an average rtatueei gas higher heating voice of 1,020 litu/scf.The operator basedt#ieir calculations ono heating value of 1,050Rtu/scf.As a result.the emissions factorswould typically be converted to this heating value by multiplying the emission factors by a ratio of 10$0/5020=1,.03.However,the operator simply used the Ih/MMscf emissions factors direttlyfrom AP-42toestimate emisions.Thia was deemed acceptable mce scaling the emisionsfactorsto-a heating value of 1,050 Btu/sfresultsin a minimal impactonoverall emissionsSince the . change in emissions would be negligible and the facility status would not change based on the minor increase in emissions„hfijl accept the operators calculationsfor permitting purposes(facility-wide emissions were evaidated when converting the emission factors forall heaters using AF42atthis facilility)To furthersupportthisdeterrtdnation,it should be noted thatthe applicant provided a manufacturer.specification that lists emission guaraafeees,in units of lb/MMbtu,which are not as conservabve:as the-16/MMbtu values used for NOxand CO hi this analysis...`This heater's equipped with a low NDx combustion system.Asa result,the operator utilized the NOx emission factor from AP.42 Table L4-1 that is based on small boilers(x100 MMBtu)equipped with low NOx burners .Applicant indicatesth tthis heater viii be hmitedto operate at.70%of Mil beat input capacity:DCP indicatesthat the(eaterwial be limited based on operating hours(i.e.the regeneratfon s cyclicatin nature,no the heater turns on and off as needed for•regeneration.However,whenever firing,the heater is at or near full firing rate Since a limb included on feel use with oompltantemonitore$yfiing y meterl,a'limit on operating moors H not • . .An initial compliancetestwill be requiredforthis heterta demonstrate compliance with Noy and CO emission limits Although DCP is using manufacturer guaranteed emission factorsfor PM25,itwas agreed to remove VMS 5 from the initial compliance test becuase i)emissions ofP512.5.are below reporting thresholds and of RCP provided later from thenrapufacturer that guarantees the particulate matteremissionswiR not exceed 0.005 Ili/MM5113 'The heater is subject to an identical standard for particulate emissions in Regulation 1,111.0,1 and Regulation 6,Part 0,I1,As such,I've combinedthe requirementslnto a single condition that references both regulations.1 did not include refereceto theSulfur standard in Regulation't2 tons per day)since compliance may be presumedfor this equipvent. I had some question as to how the manufacturer spec sheet was reportingthe design rated duty or heat input rating.Since the specifications call out the design rating as"Heat Release';.€asked DCP to clarify if this was indeed the resulting,useful heat released or if it is representative of the maximum heat input rating, DCP Response:Please note that each spec sheet has 2 numbers-heat release and heat absorbed/duty.Heat releases what the burnerfuel input is based on,while heat absorbed is accountingfor efficiency lasses.Therefore the number that is used is appropriate and isequivalentto the heat input capacity.Accordingly,the emission factors are also appropriate,Itis a nomenclature issue;each menufacturerprovides slightly differentterinlnology i. for the same number so it can be confusing.Here is the table of heat input and heat absorbed for each heater for clarity. I confirmed the values used in permitting with the vendor and engineenngand they agree that the fuel limit and emissions.are based on theoppropriate heat inputs for each heater. - - - - Heel lnpui. Duty/Absorbed Heat Regen heater 2333MMBtu/hr 1377 MMBtu/hr Stabd zer'heter 55.0 5 Metu/hr 19.697 MMBtu/hr De methanizer heater - - 53.93 MMBtu/hr 3905 MMBtu/hr Section 09-Inventory SCC Coding and Emissions Factors Uncontrolled • Emissions AIRS Point# Process# SCC Code Pollutant Factor Control% Units 004-005 01 IS-10-004-04:Industrial Process;Oil&Gas Production;Process Heaters;Natural Gas(MMscf( PM10 5.50 0 Ib/MMscf Bumed PM2.5 5.50 0 lb/MMscf Burned SOx 0.60 0 Ib/MMscf Burned NOx 50.00 0 Ib/MMscf Burned CO 84.00 0 lb/MMscf Burned VOC 5.50 0 lb/MMscf Burned -Formaldehyde 7.50E-02 0 Ib/MMscf Burned Benzene - 2.10E-03 0 Ib/MMscf Burned • Toluene 3,40E-03 0 lb/MMscf Burned n-Hexane L8 0 Ib/MMscf Burned • 18 eggs K:\PA\2018\18WE0465.CPLxIsm Natural Gas Heater Regulatory Analysis Worksheet • Based an the heater purpose selector in the Inventory,N6 unit malios...homing equipment per most°Reguotbns 1&B,a Mei.genemRag uNcper NSP5068 oc and industrial,commercial°,imtlnrtonal hour or process heater oar MAC]60000 IThsmitMes mom.gmasdefine,lay NSP5 Ob.ooandfors designed tooengm1 Nehru defined try MAR 0000D 1 Colorado Reeulatkn3 Pere A and B-OPEN and Permit Remdremene I5o rice.is in the Nom.ttainmem Area AMAINMENT L unmr0olled actual W emissions from any mitena pollumnm from Nis intddualsourcegreener than z'my treguotion 3,aart.Seaton n.D.Lalx 2. mdw heater have a design heat inpucam lens Manor equal 0,5 MMB.rhr,(Regulation 3,Part.Section II.O.L,.I 3. Does Me heater have a design n.c input rate lens Manor equal to to MMB (Regulation 3 Part B,Section 11.0.1.o) v reek,, q om. 4. ore. ogor unconpolled VOC emissions greater than 5 Y,NORgreater thur than MTP/or CO emissions greeter Men 107P1{Regulation 3,Part B,section ll.D.31x /% 'e toot enough Information t00N-AT0AWMF311 Me uncontrolled ns from arty criteria pollutants from Mls Individual source gavot Pun 1 TM'tRaauatlon 3,Part.Section llD.tgx .T.C Rd'Nd"se'"w,5,v toted non question 2. Doe Me hexer haveaides less Man equal to Bmrhtx(tuet Part e Smtionll.O.Lk.I question. 3. Doe the heater have deign heat Input ess then or to lO MMMuMrx(Regulation 3.art B,section ll.O.Le.) <udwm q ,nn. a Are am.Meal,usmntrMied VOC emissions from Meeeamr than 2 TPT,NOY pester Men s MY or CO emissions greeter Man 5 MY Meeulation 3,Part%Section ll.DSI _�u.ugry rm.�Pemdr 'Source requires a pen. L AreRegulation serdtn Nl sulfur dioxide emissions from Me heater greater Men i tone per day?(Regulation L5ecvon N.R.5.a. I No IBotedonihe requestades-abeaaend..onm¢o.compemoe',rammed 'Based emissions and emission Maar,cumafene h gramme. SeNon v1.65-Emission Lim. Section VI.B.6 and]-RewNkeePln&Reporting,Data Retention Regulation 1.Section n and cobra.Regulation 6.Pert B.Section II,Bmnderds of Performance for Nee reel-Burning.Equipment PIM,Is the design heat inn.late tithe heater,lfegulston 1,Section ill..and Regulation 6,Part B,Section PC.) 2333 NIMPturhr cocoa...Mag. Does the swrte discharge particulate matte.mns of CO ibrMmbtu heatinput,(Regulation L Section III.A.1.a.and Regulation 6.Part B,Section II.C.14 3. Does Me sauce discharge particulate.atom in excess of the following em otion:PEsAS(Rli-'stf(Regulation 1,Section III...L and Regulation 6,Parto,5eNon 11.G21- roma on t nted he mou emissionm u on team mpllan u prxurroa. A. Does tim more.disaharga Perticulete moms matter in of0.11brOmbo hearmpeot(Regulation 1,Section .0.o.l J/ll"✓ Ji 'Based nMg...,the desgt opmm,the sarrte0subject.Reeid..11oeaon nISLc and Regulation n 6,Part B. ltG3.Based on the requested emission(Se te,,compliance is Co lared0 IMO Won P.Section%n.D. joss fired heater orated at en existing facility that Is classlged.a major source of NOR as listed In Regulation]Section gig.,(Regulation]Section ANI.D.LI sm„mi.mi wqu¢tu Requlnon]sa¢ium gVI.0 0, Doe Me natural gas fi hex con0dled egos.em s of 005 equal to or greater than 0,y,IRegulation 7 Section AVI.D.L1 nI'Source red lsn subteen to ReguItion,,union 0 and r.—Combustion Process MNon sert Section M.D.a Reeardkeeping Section MOM.—Alternative to requhemene described in Sections OIV.D.la.through tt.O].e.and 001.0.3.5. • • NSPS Analysis • 1. Does Me naturalises fired Seater haves maximum design beat Input seamier 01'29 megawatts iMI)(103MMetuhr)or less,but grea.Man or equal to 2.9 MW(10MMBtu/nil(§63.2.(a)) Yes G IX apgimbdey sanian 0. Does the natural ural gn fired heater M1aveam m anmu design heat Input cascases.greategreater..29 megawaa WWI(1WMMetu/br1?(4WAoblap No Source.nasalanml5PSON 'Ma pia s..abyss In NSP5IX section below. 40 CM.PRItSu6pert Dc smpder.of Ter...Ice fa smell IndatrlaCommerealatateMonel Steam General.lInfos 1 Mal consulate.,mdlPotien,or remm6uman of Me steam eeneradnx ones Commerce after tune 9,a9e9,(§W.40Nal rigarittaMMISmacria ma..NSPsk ISourse is subleet to NS.Or. suhart A General PnavisionS 5544.-Pepmting and Pmordkeaitg Fequiremm¢ oe Pert 60.hbeenOb Sener.e&Perfarmnee for indu0.4Commerell-ImtRManalsteam General.Una. Goren-as.,modihcetlun,m reconstruction of the steam generating unit comnren.aka-lune 19,19547(5..40(.) In2 mender. 2. Does Me tu.gas Pmt Hearer Save emission rem of Wire(032 i6/MMetui beet Input or less214W.a2b(k)(2i) 3. Did<be affected teal commence ccantrumfon.reconstruction ar modamslon21450.426lkll ll • sour.is not subject to NS.Ob. NOn Standards Dees me namrel en fired beater berme beat mpe nsp.cnv of73 Mw I2s,MM9mmrl oriess?I§sn44W41 1lllr4,.'�.2�i,Wit^=°ors^as. 5. Does the hater meet ey of the fdlovkng cdmda?(950442)(01) Sa. Comb.,alone or In1O0F'adon,om.natural as,dledllemoP,or residual MI wiM a Orosen content of 0.3 weight percent or less(450446g1(11k Gate nett cowman. 5b. Neves combined annualapadmham of 10 percent mass tor natural as,Ma'am dl.and residual o2 with a nitrogen Content of03o weight percent or leas(2W.G25O22)I;aM Ares augers to federally enforceable raqulremen,limiting opens.ofdmeffected rail.to ae flring of natural ges,disbllam t,and/orraldueldl ads a nitrogen mrmntoa.o -j weight camera or less eMItmithopea4on of dm affect.halts me combined anal mass.fa.of 10 percent m less for saw.as,dlstlllemOB.aM rraid..widta nitrogennitrogen -// SG connotef0.30wnrght percent or Ices.1450.4W11311 5. CM Me affected face.commence Ceramauon,rermnrurdon or modification after]Wy 03.1997)(§®.a4b111) '✓ is Me natural gee Mal beater ablario endF...artm wits(easily a.m.Nerequirement Masan.awe.Dr McNoLry men annual apaclty.aor of 10...SM..)a less 1'.r ✓ m Does. oes ,aMnatunl aa(oranymmwaw bar Aeaerareend anbpl(111 n tMnaobl gez fired beater Seesaw M1eat2am rare end Comb ustnatural§amdisvlbtedlin exm0z o1'3oper00 SIO heat input ona3i.Way rollFgavera55 from the co412000 of all Y/ 9. fuels?(4W.4d 08111 'Source 700.os a)ssUStandard for suffix di.tlde(so2) §sn.44bl.la(k7mm:lpand tna gl-smndera tor...eno.wes 4 50.46.Compliance end performance . 77,e meae and procedure.Mr sulfurdb.. 560.466-Compliance aM perlsmnae ms meNMs end procedures Mr...see mates and nemgen asides §40.46-[Cola m mmMd...Eur ia. §60466.Elaine monimringla pwdc0lse mater end nbyen°saes 565.466.gepoelnp and recordieePhe eequiemenb MAR Analysis 46R pen G3.Subvert matt 45000,MnS0APfa Meb,source.IndatAa.Commercial.end Ins0eutionel aoltrsend process Heaters • ter located et a fa..Nat Is major source Mr HAec7(O5374e5) sd.aNaTaNT Ma unnbn.subject tomncT old ramwmon(4®.7490@0 or reconstruction(453.7490(.(ofbamr commence sear lune4,2010? SMettatt 3. is the bear In.capacity less Nan or equal to s MMetuthr?(§53.75W(el) No Domn° A Is Me hestlnput capacity greater than 5 MMBtu/Sr but less than mama to 10MMem/br?(§®.7soiye(I No "...CUrrnnwn.mdunamno-upamu5IIC Iseura is not subject to AMR 000me. 463.750061 end Table-Work prances-tender. §a 4905(e)-General requirements 463.7510(e)- Ida)requirements Mrmadng sources on 63.7910 WI(0,new SON[H 753.0513(4-subsauem teen,Ina analyses or mneum 453.7s3o)e1 aM(0-Omw0euamgmidat mmdlmwe §®.75401.110)and 6013)-Den.ae°.nne continuow¢mmpliance 5®.7555 pl,(beta eamig or c-Ice newt.(4 ICU e14,ern,Os)-72.25,002,0 755.790514.1¢).Ill.(.(11.l(51'505mrmrg §65.l5ss(a).NMI end Al and 69.7560 lab @1 em)o-imroidkeeply QIx6lmer tub document assists aperebrs with d2brmlnlng applbabllilyarsenal',m7uhemen9 o1M0 Cka0.144 lslmplemenling mgulaoana,and AU Quality C.O. Commission regul00206 TNsdxument is not rule Orleguk0on,and Me analysis it contains may not apply is a partMularslual/on based upon the I5MNkluel/ads and tlrwmstonces This obannent noes not changeorsubs0Nfa Moony lave,regulation,or any oilier'agony bin2lg requirement and Is nollegalty enforceable In the event o/ anyconilk...veen We language olthls documentand and.language of..Clam AUAct„Its Mpkmenurg regulation;and Air Quality Control Commission regulations. Me language o(Mestaneorregualbn WN con0o1.The ass or non-mandatoryk7guageauc0 oa3000mme2'rney,"-0000ld alb'can'l?mono..c.o.O.APCO Inteimeistions aric reconrrencesnons.Mandewry%m0Pgbgysu5l aslrvrsr and'Mon.ed are lnfendedm da2De controlling requlrenianis urner0a lemm aM.Cksn AUAefano Air Quality Control Commission regulations.but Mk document does'Wasn't,ll legaffy00cIrg require's.noln and allG I/. Natural Gas Heater Emissions Inventory • 006&007 NG Heater Facility AIRS ID: County Plant Point "Point 006 and 007 are identical make/model heaters used for the same purpose with the respective process trains.This analysis applies to each heater individually. Section 02-Equipment Description Details Heater Information Fuel Type Natural Gas Number of Heaters . Wt one(1)Purpose Used for condensate stabilizer Make: xrt''rpHPd En'iffi;i-A;iPffirrififi Model: '1611°fifi5fl Lh,altrin `� Serial Number: l3 #0 Design Heat Input Rate: 1,,2 .MMBtu/hr Equipped with Low-NOx burners: Equipped with Add-On Control Equipment: �zS One(1)natural gas heater(Manufacturer:Heatec,Model:HCI-18010-50-O-G,Serial Number:TBO)with a design heat input rate of 25 MMBtu/hr.The unit is equipped with low-NO.burners.This unit is used as a hot oil heater for the Detailed Emissions Unit Description: condesate stabilizer. No add-on control equipment Emission Control Device Description: Requested Overall VOC&HAP Control Efficiency%: Low NOx combustion system is considered an integral control device. Section 03-Processing Rate Information for Emissions Estimates Design Heat Input Rate= 25.0 MMBtu/hr Heat content of waste gas= 1050 Btu/scf Actual Hours of Operation= hrs/year Requested Hours of Operation= 8760'.hrs/year Requested heat input rate= 219.000.00 MMBTU per year Actual Fuel Consumption= 0.00 MMscf/year Requested Fuel Consumption= 208.57 MMscf/year Requested Monthly Throughput= 17.714 MMscf per month Potential to Emit(PTE)Fuel Consumption= 208.57 MMscf/year Section 04-Emissions Factors&Methodologies Emission Factors Natural Gas Heaters Uncontrolled Uncontrolled Ib/MMBtu lb/MMscf Pollutant Emission Factor Source (Fuel Heat (Fuel Combusted) Consumption) PM10 0.0072 7.6 PM2.5 0.0072 7.6 A. so. .0:0006 0.6 Y 5 NOx 0.0476 50 co 0.0800 84 voc 0.0052 5.5 Formaldehyde 0.0001 0075 •W "y Benzene o.0000 00021 �.) b3b%.�{' Toluene 0.0000 0.0034 ggA n-Hexane 0.0017 1.80 $.,6t Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month) PM10 0.79 0.00 0.00 0.79 0.79 135 PM2.5 0.79 0.00 0.00 0.79 0.79 135 500 0.06 0.00 0.00 0.06 0.06 11 NOx 5.21 0.00 0.00 5.21 5.21 885.7 CO 8.76 0.00 0,00 8.76 8.76 1488.0 VOC 0.57 0.00 0.00 0.57 0.57 97 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ibs/year) (Ibs/year) (lbs/year) (Ibs/year) (lbs/year) Formaldehyde 16 0 0 16 16 Benzene 0 0 0 0 0 Toluene 1 0 0 1 1 n-Hexane 375 0 0 375 375 Section 06-Regulatory Summary Analysis Regulation 3,Parts A,B Source requires a permit Regulation 1,Section VI Based on the requested emissions and emission factor,compliance is presumed. Based on the design heat input rate,the source is subject to Regulation 1 Section III.A.1.c.and Regulation 6,Part B,Section ILG3.Based on the requested . Regulation 1,Section III&Regulation 6,Part B,Section II emission factor,compliance Is presumed. Regulation 6,Part A,Subpart Db,SO2 Standards Source is not subject to NSPS Db. Regulation 6,Part A,Subpart lb,NOx Standards Source is not subject to NIPS Db. Regulation 6,Part A,Subpart Dc Source is subject to NSPS Dc. Regulation 7,Section%VI.D Source is not subject to Regulation 7,Section XVI.0. Regulation 8,Part E,MACT Subpart ODDOD Source is not subject to MAC(DD000. 21 of 65 K:\PA\2018\18WE0465.CP1.xlsm Natural Gas Heater Emissions Inventory (See regulatory applicability worksheet for detailed analysis) Section 07-Initial and Periodic Sampling and Testing Requirements Is the project close to the 40 tpy modeling/NANSR threshold for NOx? 13 if yes,stack-testing should be required for NOx,as well as for CO. Is the operator limiting their heat input rate below the design rate? If yes,stack-testing should he required for NOx,as well as for CO. Is the project close to the 5 tpy modeling threshold for PM 2.5? If yes,stack-testing should be required for PM 2.5 Does the company use AP-42 emission factors(or more conservative factors)? If no and testing hasn't already been required due to proximity to modeling thresholds,testing should be required for any pollutants for which alternative emission factors have been used.If testing is being done for only NOx or only CO,the other should be included as well. Section 08-Technical Analysis Notes _ _ ---- *This southeast,plant residue gas as fuel.Applicant used residue gas HHV of 105nbtu/scfbased on a.residue gas anaiysis from a similar DCP faUI'ny, - `The emissions factors from AP-42 Chapter 1.4 used to calculate emissions from thissourceace based on an average natural gash igher heating value of 1,020 Btu/scf.The operetorbased their calculations on a heating value of1,050Btu/scf.As a result,the emss ens factors would typically be converted to this heating value by multiplying the emission factors bye ratioof 1050/1020.11B.However,the operator simply used the lb/MMscf emisscans factors directly from AP-42 to estimate emissions.This was deemed acceptable since scaling the emissions factors to a heatingvalue of#,050 Btu/scf results in a minimal impart on overall emissions.Since the change in emissions would be negligible arid the facility status would not change based on the minor Increase rtie missions,I will accept the operators caleulatlons for permitting purposes(Pacilltµwideemissions were evaluated:when converting the emission far ors for all heaters using AP-42 at this faolility) *This heaters equipped with a low Nog combustion system.As a result,the operator utilized the Not emission factor from AP 42 Table 1.4-1 that is based on small boilers(s100 MMOtu)equipped with low NOx burners. *The heater's subject to an identical standard for particulate emissions in Regulation 1,1I1.A.1 and Regulation 6,Part B,ll.As such,I've combnedthe requirements into a single condition that references both regulations I did not include referee°to the Sulfur standard in Regulation 1(2 tons per day)since compliance maybe presumed for tbls equipment I had some question as to how the manufacturer spec sheet was reporting the design rated duty or heat input rating.Since the specifthations call out the design rating as"Heat Release,I asked DCP to clarify If this was indeed the resulting,useful heat mleased or if it is representativeof the maximum heat input rating. DCP Response.Please note that each spec.sheet has 2 numbers heat release and heat absorbed/duty.Heat release is what the burner fuel Input is based on,while heat absorbed is accounting far efficiency tosses.Therefore the number that is used Is appropriate and is equivalent to the heat input rapacity.Accordingly,the emission factorsare also appropriate.It is a nomenclature Issue,each manufacturer provldesslightly different terminology for the same number so'Egan be confusing.Here is the table of heat input and heat absorbed for each heater for clarity.I confirmed the values used in permitting with the vendor and engineering and they agree that the fuel mitandemissions are based on the appropriate heat inputs for each heater. Heatinput Duty/Absorbed Heat Regen heater 23.33 MMetu/hr 1377 MMBtu/hr Stebiluerheater 25.0MMBtu/hr _ 19.697 MM8tu/hr 0emethanizer heater 53.93 MMeto/hr 3105 MtBto/hr Section 09-Inventory SCC Coding and Emissions Factors Uncontrolled Emissions AIRS Point# Process# SCC Cade Pollutant Factor Control% Units 006-007 01 I3-10-00404:Industrial Process;Oil&Gas Production;Process Heaters:Natural Gas(MMscf) PM10 7.60 0 Ib/MMsef Burned PM25 7.60 0 Ib/MMscf Burned 5Ox 0.60 0 lb/MMscf Burned NOx 50.00 0 lb/MMscf Burned CO 84.00 0 lb/MMscf Burned VOC 5.50 0 lb/MMscf Burned Formaldehyde 7.50E-02 0 lb/MMscf Burned Benzene 210E-03 0 lb/MMscf Burned • Toluene 3.40E-03 0 lb/MMscf Burned n-Hexane 1.8 0 lb/MMscf Burned • 22 of 65 K:\PA\2018\18WE0465.CP1.xlsm Natural Gas Neater 0egelatory Analysis Worksheet ea*.the heater purpose selection mthe bnentory,this Link',Ries as fuel bvNngegn.ment per Cobrada Ragelat.rts 116,asteamgemratint unit perhth5 Db e Oc end industrial commercial or Insttut..l boiler or process heater per MAR 00000 lTh..nd ruesnatural,as as defined h,NhP506&o and/or s designed toWneasl(uakaxdeinatlMMMa00000 1 Wont.Re lhrywl3 Pam p eatl 0-APEN and Permit Requlreme. Iwmce is In the Non.Attalnmam Area ATTARIMNT • E:monied actual emisslot foam anydteda pollutants from this individual source greater than EmY(Regulation 3,ParlkSection II.O.Lalt • Goes*heater have a design heat Input me less than or equal m5 MMett/nri(Regulation 3,Part A,Section II.D.Lk.I Co to tha next question. 3. Goes the heater knee a design heat input rate less.an or equal to lO MMBtu/hr,(Regulation 3.Part 0...Ion ll.0.1e.) ma dean q rbn. a. Are rook fedlitvoaamdled VOC emission ter then 51PY.NOxgeater than 10TPy orCO emissions ater than 10192 IRegWadon 3,Pa.Section llD3lt t enough formation • NONAlTAiNPAENT • mnndled emissionsrwm any criteria pdOtnt from MrslndMdual source grater than loot(Regulatl1n 3.Part A Sembnll.0.lalt ))g*0' ` zourm Rogmdtsan aasx raotMnmµe°t'on Ilan the terhawa design heatlnput rate less..or equal O5 MMBI/hrt(Regulation 3,Part',Section II.0.2.1.) No po mason..question. 3. Does the heater have adesgu heat input rateess than°requal 110 MrOetu/hri(Regulation 3,Part 9,Section 11.O.1..1 No Gottarho next guest-ion. A. Precool facility uncontrolled VOC emissions from the pester than 209Y,NO,greater than 59PY or CO emissions pester Nan 5TTY(Regulation 3,Part 2,Section 11.0.2)? Source Requires a permit iSo rce requires e permit Cetera.Regatta.1 Section V( • Are sulfur dioxide emislans from N e n heater ggre�maswn�s per day,(Regulation 1,Section 88.&5.X.1 I No lea.on tea rogened dpn ambs end es...teem,compliance braes....N.S factor,Resed on Se* -Emission Nmlts dp d sedan Vl.e.6 and)-Reconikeeping,Repwtlng rota Re,ntbn • Section and Colorado Re gulation egulation 6.Part',Section II,standards of'Merman.,for New Fuepeombg Equbmmt 1.• Reguhtlen,e tert(Maga.dml,secd A Per/a onlll. and Regie.n6.Pa Res.IL1) {hr 0oesse155 Nwharge guparticulate nurser m mess of asb/Mmbw Mat Input,(Reguati.l 5.145Section 82,2e.end 0egulnbn 6,PaesP sacra°P.1O ! ;f,// Based on Me rage..emNNonfaq«,wmppanak leasuvea 3. Mg the edlscharge particulate matter In access of the following equation:PE=65(P)t'al(Reguation 1,Section TALI,and Regulation G Pert e,Section 11.121 MEM eased on.requested omission I actor,compliance Is pmsumad. 2. Ones the source tllwharge particulate matter In excess of 0.11b/Mmbw heat Inpt,(Regulatlm l5edon IIIA.1.e1 /jl„k;'l// ea*.Na request.emission tame,,coma.=Ss pavans.. . loaeadOnt design heat lupus rate,the source b.Netto Regulation iseala.FILM,attd Regulations,Pan6,sealan1003.eased on the requested*Ion Ia..compae51.b .qm tl. Colorado Raoad.2 section/PR • • s the natural gas fired heater located acan existing IMBry that Is classified as a major soumaf NOa as listed in Regulation,Section XIXA>(Regulation,section=ILL) h out subject to Rep.,.7.soncnxvla. 2 Wes the natural gas fired heater have uncontrolled actual welssl.sof NO:meal.err water.an5 oyt(Regulati.>Section 81/1.0.1.1 isms.is not sublet to mauled.,,seal.Rare. sealannseP.a.e malt-Combustion Process Adlmapnent sallon gym.-Rcm0Neepang seal.aIro.A.-a/ematiw to/nal/enema described N Sections 1YV.D.ia.through X88.Oi•.and X88.0.3.0. NSPS Analysis la tees Acnetaal Res fired heater have a maximum design heat input[epeelry of E9 megawatn(Mw)(IWMMO0{hr)or less,but grater than or equal to 29 MW(10fat0b./nr)t(8824.8) Yes Go to NSPS Oeepplomlrty swim 2 Does the natural gas fired heater have a maximum design hltlnpt apaciry greater than E9 megawatts NMI(120MMP1u/nr)i(§80.4010l) No scarce is no1wblonta MPS Ob. leaalueM nuestloa in vises x section below. waqi Part 6e.subsea 01standardsof Perform e.for smell tldunr0Lcemmeld oflkudonat steam Generating unit 1. Old consaoc6Pn,modifEcation,er reconseueslonof the team generating unit commerce afteelune9,1989?i§eaa0c(all sir- 1...rou subj.to NIPS pc I5otete is subject to N SPS tic. ne Subpart',Genera is/pagans g60.431.Repelling and Record keeping Requirement s,0 efli,Part 60.Subvert ob.Sender&of pe��µersareafer unetauomral am Generating UM. • Did construct., nmdon,ate onofdleateamm gemming unit mmmen«: lone ss,leg4,(§®.mb(all 503 standards 2. Ores the nature gasflrd heater Ilene potential Sox emission rase of 14O ng11(03216/MMBmI brat Input or less,1§w.2b(kl(211 % 3. Diddle affecodfadliw n cammce cro cu struon,renaastrucm a n mndlfiadon after leh en 28,30057(55.03b(kllills'.11//Fiiia/./�. 'sou la nos am eubfe NenOb. Roe mend Goes the natural gas flM hnmr haves heat input expadtyofea taw(250 0,1108m/hr)or less?(4m4.1k11 - I Yes IGo toommionps. 5. 020 the hewer meetaf of Me fdlvwingcnteclil(#43bh1) 5a. Combust,alone or n «comteuon,amynatural gas,distillate oil,°residual.Wei a nitrogen ontent°,0.3 weight{wont or kss(4gn4abp)(1)6 ✓flH,�:�f:rheas quest... 51. Ranacombined annual capacity facm3of10 percent alms for natural gas,disigia.oil,and residual ollwlMa nitrogen content of030 weight percent or Ins(4w.aabg113U;and ..eject ma federagy*Me rcouisers...iing operation of the affected facility m Me firing of natural gas,distillate el,and/or residua on with&niw¢em mnsencof030 weight percent or less ndElmltlng operation of the affected hell-Wm a combined annual capacity factor of 10persnt or less Mr natural gas,distills,¢o0,and residual al with a nitrogen . content of 0.30 weight pemem 333.or lest(§531333&307 g. red Me affected facility commence construction,recaemaUon or modlfiadon eferluly03,399,3 14®..1111 is Me nayaral gas flied heater sublecem and In compliance with a federally enforceable requirement Mat RM.opaasion of Me facility m an annual®wslty fano.,30pemenr(OM aless fa • teal,O.and natural gas(or any oMe Mree))3l560MbI II Oen Me nameless fired heater have law heat release ra and combustnatu.gas«dhoMte dl in saws of30percent of the heat input n a 30-day rolllag average from Me combustion of all / r's` a. Mgsz 1§® Ixm a6 mtsubpam asps ob. §gb.mb00(11-Standard for augur dkvide(5011 5,.330.mid s gL Nand()a 3.*suitor nitrogen cantles 1353 4w.ab-Compliance and padoma3 tea motels and procedures for sulfur d1®de 4®.ego-conpl.urca and 00.503 a 03 me methods and procedures for particulate matter and nitrogen oxides 060.4x33.1,ton monitoring f«sego,dioxide §60.360-Emekon 3,9,0ing for particulate matter and nitrogen naives 400.400 Reporting aM recadkeeping requirements MALT Analysis 30 pm.part 63 subs&.Mace oo00,.55X075,0&alor sources Industllal.Commercht and Inokmional Boilers and Morels Heaters L Is Me Fester located at a(achy Mat is a momscumekrxa3s,(4s3T4851 m.80111. 733313388078005. • Did. m3pds+1005.74001.11 r, n mm m 1403.7490(3ll of h commence after June 4,2010, pan 3. Iathe Mat input opacity less than0,.SSSl to5 MMmr1 Bh,0(433.350Ole1) 00 Go to n°^4".td°^ 4. ISMe e.407o'n alm terthans wascubbut less than mrepulommBMAnl14s3.xwgel1 Nu The source mw con3uaa nm. w 0 up3m . Meal sanceIs not su b lees to VAR 00000. • §®.35001el and Table 3-Work practice sonde. 0€3.7335(.(-General requirements §13.75101.)-1 ml requirements for 1013)for new sources 403.7515 140-5uMenuene mss,fueEanaM4s sunem03 4®.x53.(,)and(0-oaten«tracing lmdal mma6noe 463.054aa1Ro(and 1,(0130-q complain 503.704513),@-20,3 mine or far swig le),(MU WLe171.eel.rv°gnamm • ga.7ss30,(33,I<L lel(U,651.333030303 §03.x553 la,(a)p)end g!(aq G3.25rm la b Oil am 14-pe3ordlsedng CLsdalmer lesdocumentas0sfseperebrswiz r/sterMning applkabllliy°Icarian,requirements°five Clean AlrAct IItslmplerrenWg regula0ons,and Air 0aa0fyControl C«omssdn regulations leis document Is not a rule.'regulation,and Me analysts contains may not applytoa partholersNaaon bass upon ue Individual lads and • circumstances.misdocument.esnotMarge orsubs.10breny few,mule from oranyoterlegaaybtrimnpmqulrarrenrandkndleg5lyenr a0M.nma3senta anycon0ld between the language.,Ihis document sac the language oythe clean Air Act„Its Impkmen0ng reguations,sae Quality contra Commission regulations, Vie language ate statute orregulardn WI cannot.The OmetrenmetlWdry language such as 5sconunend"may.'"should.'aM"c3n;s in6no8tlto coacmbe AP00 Interpretations and m®mnlss&R7m2 o ratorykmllsologystr.as'mus,aid50501rO'aro intended to 6avlbe controlling requlrementr uncor0e toms or.Clean Air Rased Alr0ua0tyCn0ol Commission regulations,007170s documenldaae not establish legally/. 79 requirements in anal olds* Natural Gas Heater Emissions Inventory 008&009 NG Heater Facility AIRS ID: TZ3i 9FBB 008-009 County Plant Pont 'Point 008 and 009 are identical make/model heaters used for the same purpose with the respective process trains.This analysis applies to each heater individually. Section 02-Equipment Description Details Heater Information Fuel Type Natural Gas Number of Heaters C () ri � One l Purpose r', hutudf l0O , `Used fordemethanizer Make: Tulsa Heaters Mid,t ape Model: SIlO4U3O Serial Number: TOO �4..f: Design Heat Input Rate: 53.93„ a MMBtu/hr Equipped with Low-NOx burners: Equipped with Add-On Control Equipment: _„4/' One(1)natural gas heater(s)(Manufacturer:Tulsa Heaters Midstream,Model:5004000,Serial Number.TOO)each with a design heat input rate of 53.93 MMBtu/hr.Each unit is a hot oil heater. Detailed Emissions Unit Description: No add-on control equipment . Emission Control Device Description: Requested Overall VOC&HAP Control Efficiency%: Section 03-Processing Rate Information for Emissions Estimates Design Heat Input Rate= 53 93 MMBtu/hr Heat content of waste gas= L Btu/scf Actual Hours of Operation= 876i0� hrs/year Requested Hours of Operation= 871 ii:hrs/year Requested heat input rate= 472,426.80 MMBTU per year Actual Fuel Consumption= - 449.93 MMscf/year Requested Fuel Consumption= 449.93 MMscf/year Requested Monthly Throughput= 38.213 MMscf per month Potential to Emit(PTE)Fuel Consumption= 449.93 MMscf/year Section 04-Emissions Factors&Methodologies Emission Factors Natural Gas Heaters Uncontrolled Uncontrolled Ib/MMBtu lb/MMscf Emission Factor Source Pollutant (Fuel Heat (Fuel Combusted) Consumption) PM10 0:0052 5.5 ''dlit3#9abrjCti" ' PM2.5 0 0052 5.5 'PZ -ytdtt#d/ t; SOx 0.0006 0.6 �//T NOx 0:0340 35.70 riv,fufatdss l✓1/ cD u csoU Ba w I�T�. {ems VOC 0.0052 5.5 **-14-2 Formaldehyde 0.0001 0.075 -t'etzte14- Benzene 0.0000 00021 W42.TdHe-S4t3={8' j Toluene 0;0000 0.0034 Ap-4Z.:LdiS) nHexane 0.0017; 1.8 AP-4L;Fm4ile... nej` Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month) PM10 1.23 1.23 1.23 1.23 1.23 208.6 PM2.5 1.23 1.23 1.23 1.23 1.23 208.6 SOx 0.13 0.13 0.13 0.13 0.13 22.9 NOx 8.03 8.03 8.03 8.03 8.03 - 1364.2 CO 18.90 18.90 18.90 18.90 18.90 3209.9 VOC 1.24 1.24 1.24 1.24 1.24 210.2 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ibs/year) )Ibs/year) (Os/year) (lbs/year) fibs/year) Formaldehyde 34 34 34 34 34 Benzene 1 1 1 1 1 Toluene 2 2 2 2 2 n-Hexane 810 810 810 810 810 Section 06-Regulatory Summary Analysis Regulation 3,Parts A,B Source requires a permit Regulation 1,Section VI Based on the requested emissions and emission factor,compliance is presumed. Based on the design heat input rate,the source is subject to Regulation'Section III.A.1.c.and Regulation 6,Part B,Section II.C3.Based on the requested Regulation 1,Section III&Regulation 6,Part B,Section II emission factor,compliance is presumed. Regulation 6,Part A,Subpart Dh,502 Standards Source is not subject to NSPS Db. Regulation 6,Part A,Subpart Db,NOx Standards Source is not subject to NSPS Db. -Regulation 6,Part A,Subpart Dc Source is subject to NSPS Dc. Regulation 7,Section XVI.D Source is not subject to Regulation 7,Section XVI.D. Regulation 8,Part E,MACC Subpart DDDDD Source is not subject to MACT DODDE. 25 of 65 K:\PA\2018\18WE046S.CP1,xlsm • Natural Gas Heater Emissions Inventory (See regulatory applicability worksheet for detailed analysis) • Section 07-Initial and Periodic Sampling and Testing Requirements Is the project close to the 40 tpy modeling/NANSR threshold for NOx? If yes,stack-testing should be required for NOx,as well as for CO. Is the operator limiting their heat input rate below the design rate? If yes,stack-testing should be required for NOx,as well as forCO. Is the project close to the 5 tpy modeling threshold far PM 2.5? LISIMEN If yes,stack-testing should he required for PM 2.5 Does the company use AP-42 emission factors for more conservative factors)? ,h7ta : If no and testing hasn't already been required due to proximity to modeling thresholds,testing should be required for any pollutants for which alternative emission factors have been used.If testing is being done for only NOx or only CO,the other should be included as well. Section 08-Technical Analysis Notes *This source uses plant residue gas as fuel.Applicant used residue gas:HHVaf1050 btu/scf based an a residue gas analysis fern a similar OCPfacilty, *The emissions factors from AP-42 Chapter 1.4 used tocaiculate emissions from this source are based on an average natural gas higher heatingyaibe of 1,020:.Btu/scf.The operatorbased their calculationson sheeting value of 1,050 Btu/sff.Asa result,the emissions fa tors would typically be converted to this heating value by mulhpfyingthe enission factors by a ratio of 1050/1020-1.03.However,the operator simply used the lb/MMscf emissionsfattors directly from AP-42 to estimate emissions.This was deemed acceptable since soaring the emissions factors to a heating Value 011,050 Btu/scf results in a,minimal intpoct on overall emissions,Siscethe Mange in emissions would be negligible and the facility status would not change based on the minor increamin owl sloe,(will accept the operators calculations for permitting purposes(facility-wide emissloas"Were evaluated when converting the emission So tuns for al,heaters Using AP-42 at thisfacilillty)To further support:thisdetermmatlon,a should be noted that the applicant provided a manufacturer specification that bsts emission guarantees,in ands:of Ib/MMbtu,which.are not as conuareaI ve as the Ib/MMhtuvalues used far N Oxand CO:in this analysis *This heater is equipped with ultra low lox"com bust on system.Rsa result;the operator utilized the NOx emission factorprovided by the heater manufacturer. *An initial-compliance test will bete oured for this heater to demonstrate compliance with NOx andCO emission limits.Ahinugh-DCP is use manufacturerguaranteede[nission factors for PM2.5,,t was agreed to remove P112.5 from the initial compliance to-nbewo=e i)emissions of PM2.5.are-below reporting thresholds and it).DCP provided a later from themapufacturer.that guarantees theparticolate matter emissionswill not exceed 0.005 lb/MM BTU. had some question as to how the manu,acturer spec sheet Was reporting the design rated duty or heat input rating.Since the specificationseati out the design rating an Heat Release",l asked DCP tO clarify if this was ndeedthe:resulting,useful heat released or:ifitis repres n tine of It maximum heat input rating. • DCP Response(Please note that each specsheet has 2 numbers heat retease andheetabsorbed/dutV•Heat release is what the burner fuel inputishasod on,while heat absorbed isacceunting forefficiency losses.Therefore the number that:is used is appropriate and is equivalent to the heat input capacity.Accordingly,the emission€actors are also appropriate.It isa nomenclature issue;each manufacturer provides slightly different terminology for the same number so it can be contusing.Here is the table of heat input and heat absorbed for each heater for clarity,I confirmed the values used in permitting with the vendor and engineering and they agree that the fuel limit:and emissions are based on the appropriate heat inputs for each neater.. Heat Input • Outy/Absorbed Heat Regen heater 23,33 MMBta/hr 1377MMBtu/tit Stabilizer heater 25.0 MM Btu/fir 15.697 MMBtu/hr Demethanizerheatus 53,93 MM6tu/hr 3905 MMetu/hr - • Section 09-Inventory SCC Coding and Emissions Factors Uncontrolled Emissions AIRS Point# Process# SCC Code Pollutant Factor Control 96 Units 008-009 01 13-10-004-04r Industrial Process;Oil&Gas Production;Process Heaters;Natural Gas(MMscf) PM10 5.46 0 lb/MMscf E PM2.5 5.46 0 Ih/MMscfE 500 0.60 0 Ib/MMscfE - NOx 35.70 0 lb/MMscf E CO 84.00 0 lb/MMscf E VOC 5.50 0 lb/MMscf E Formaldehyde 7.50E-02 0 Ib/MMscfE Benzene 2.10E-03 0 Ib/MMscfE Toluene 3.40E-03 0 Ib/MMscf E n-Hexane L8 0 lb/MMscf E 26 of 65 K:\PA\2018\18W E0465.CPLxIsm • • Natural Gas Floater Regulatory Analysis Worksheet Rased on tie hearer selection In the inventory,this unit mtg.,as Mel burning equipment per Colorado Regulations 1IS6,a steam generating Rena;set IMP506 a 04 and Industrial commercial or InstimloiW holler or procem heater per MAer 00000 Imo uniflres natural ems as defined by N5P5 Ob a nc and/or h desigm5 inborn ems 1 fuels as defined by MAR 00000 Colorado Rea(rb rcePara Aandafi AAPEN and Pe.a Regulrmer. ' ATTAINMENT L are uncontrolled nual emissm a ns tan at-waiter.pollutants h ,en tlslndividual source greater Men 3.Part 7. Co lLP.Lali > a ter hoe a amtgn hem input..less Manor equal to 5 MMgw/nri(Regulation(Regulation ,3.Part Section 11.0.1.,)I yr co tothe next question. 3. Do. the heater have admign heat Input ate less Nan or equal to 10MMBtu/N](Ragulad0n 3,Part B,Sectlnn 00.0.1 s,:.:i Go to manse question a Are total facility unc0ntrolledMCC amissbns gamer Man SiFt WOO Mono,than 10 SPY or c0 emissions greeter than 10]00(Regulation 3,Part MS.01,11.0.39 ,'//VP [Not enoughInformation 1. Are controlled em0slena OnMorn any criteria polluter.from this Individual source greater than 1000(Regulation 3,Part A,Section ii.0.1.ali 6'Frd'1I S*;5&h so m totha nee question Does tie heater hew adesign heat input rate less dun or equal m 5 MMSOTri(Regulation 3.Part A,Section 11.0.1.1s)1 eationN 3. Does Me heater have adeslgn heat Input rate less Nan coequal to la MMetu/haMegulaton 3,Part B,section 11.0.10.1 No Got°.'last question. a. Pre total facility uncontrolled MCC emissions front Me greater Nan,SOY,NO2 greater Man 5SPY or CO emissions greater span 5rny(Regulation 3,Pert B,Secti av o,1l.0.el? so Rmoiresa prmb I�rmrweresapermit Colorado Reahtbnl Section VI L Aresufur dioxide emissions tom theheatecgreater than E tans per day](Regulation l.5ectIonV1.aMa.1 I No 'Ma on tit rommncd emissions and emae0ntama,compfenceis presumed I&ased on the°maen50 emissions and emission factor.compliance kprasumed. Sambn VI33-Emission limas 5emlon VI.a6 and Remrdkeepin&Reporting Data Re..0, Colorado Regulation 1,Section!Rand Colorado Revelation 6,Part B,season 0,Standards.of Performance for New Fuepeurnlre 5000wont Millet is tie design heat input ate of Me hearer,(Regulation 1,Section III.,and Regulation 6,Pert B,Section 11.24 Wm the source discharge pankulate matter.excess of oslb/Mmbtu heat Input?(Regulation 1.Seaton 111,4.1.5.and Regulation 6,Pan,.Section 11.01.1 ".�///ns MR%�/f sat a. amission fano, n 3. Goes the soune discharge 00101ulatenuMer11 as of the following equation:PE=oslftll'gi(Regulation 1,Section 111.,10 and Regulation 6,Pan B,Seaton 11.02) NO geoml on Marmites,.emission lama,camlanalsw unite. a. Wes the srcediecharee pasuculate nutter in excess of 0.1Ih/Mmbsu heat 1,0010 mew..15.1000111011.0/ V%�y / Based on the requested emission Iactor,mtro0ance is presumed. 'Based presumed.nd design a p rag,the some hsoblect to Regulation 15.6m 111.1.1,c,and Repletion 6,Pert e,seceen isca.eased on the requested emlssbn factor,compliance is • Wor.Peed.. Section XV.. Is tie natural gas fired heater at an existing facMty Nat is classified as a major scarce of NOxa listed In Regulation S5a0on XIXA0(Regulation n Section XM.0.1) Mures§rte wbjm to rs5001bn i,x¢bn via. 2 Does tat natural gas areal heater have uncontrolled actual emissions of NOx eoual en or leaner Man 5.spy?IRaruladon]5ec0on resume subpar 0. Sea ton XVb0sae and f.—Combustion Process M v iustrnt Sem,.X000.0.—nemdkeepleg • Sembn XVb0.d—Ntemetivem ree.iremenmdeecdEed In 5mOons XIV.0.2a.through XMD.l.e.and XVI.D.3.a. NSPS Analysis 1. nom she naornlgas RMed hearer have a maximum design heat Input capacity of H megawatts NW)(1W Bmihr)or less.lam greater than or equal to 2.9 MW IlOMMR0/erli l0w.0x(all Yes ea to N5P5 OcapoIMMItty simian 2 Does the natural fired heater have a maximum deal heat In tCaoaCI arer than ao me we B.Au,4®W.a Iar0Albject to NUT 05. Maluate own.. N5P5 Os section below. 00 0100,Part 60,5ubo5n',standards or Performance for small IrdumriKommerrisFN#Nrtlonai steam Erne rtlna Uri. L ad construction,modification,or reconstruction.,the steam generating Rent commence after lsne 9,1989?15010 fall IYde,•.............::I Moos la rbboto laps 0s.. [Some is emlect to N5Pb M. subped A.General Provislons 560.aac-Reponine andRecordkeeprng Requirements m 60.Pert W.Subpart OOStendardsoggerfmmmce ter udumlaKnmmerdeHnstltedonal5mem eeneo tine Units Old conouctlm,modification,or reconsauNon of de steam generating unit commerce aftedune 19,ts84)(§W.4oblall 3elmandards 2 Does de natural steered beater have a potential 502 emission rate of loo ngll(0,3116/MMul heat Input ar less)1§50.41b(l1(1)1 f 3. Mito affected ted faddy commence constmtttan,rxOovucdon er modification afar red.,18.1D05)(§50.41b(kIR11 _ .. ,° no[subject.Nsps Db. Nag Standard 0. Does de neutral gas dad',enviagea Feat Input capacity of 73(NW(15OMM6w/hr)odds?(§B0.44Mk1) visa �ca q ranvs. 5. Dam de heater meecofof the followngam0af(§60.aabpl) ua 5a. [embus,alone or In consignation,only natural as,distillate an.or'ada,oil wen a nitrogen content of 0.3 weft percent or less(§30.446(l)(1)), %lflw. ,.r ik/co tong cryeslw. m. teecombinedt a tednualmpzdn.cs0of 10 ramemann0rlms for natural de,aiected og,t.residual cal wdanl gagmcommcAoOO weightd/or residual cewant orilwt.tessl§WA canted and areaugacasnacadss and mma°paragonofth affected fadgniting dy to de affectedandllrywde firing of .Ilia gas,orleas al,and/0rli oilwdanibogimm�mma)o3o weigh[permn[ar less aiNlfmib'ngopmtlon of the effected htlliry m a rombnaiamsuel mpaary lacmrof SO pefmn[0 ids fornwnl ate,diznlllete o,and rmdual all rod a nitrogen 5. [ot commence pe0worIces 3003001o311 CM tlxaRecmd.dlitycommenm uaentcebn,rxawoucdon Omotliflmtion after Italy®,Leg"(§W.44b1g1 is de natural as fired healer subjeam and'm compliances..a federally enforceable requirement that um.operation of de facility to an annual capachy factor at 30 percent 10.3010 less f3, teal,ell,and natural ga(r any de dreel)1§50.a46011111 Wade natural gas fired heater...low heat release rateaM combusknawralgaz mdjzAlamal bexmsxaf 3D perwncoltheheatbry[on a 3oday mllingaverage Mote de combustion of all e. fuels)(§50.4461111111 i Source Y sandblast dbks to NIvm5 Ob. §W.ae(k1131-5mwm for sulfur dioade(5011 ..Siallo,d p .4b1a1 m rylO Oli(land d0pan-Standard for oxides M041 0W.45b-ompgaOe as performancdeadenedancedeadenedand procedures for sulfur dioxide §W.45b-Cnmpl.nce and performance test medrods and procedures dr pedgube matter and nivojen onties 30§ta.4rb-[mission monhodv for sulfur dioxide §W.456-Emission mmhndnq for pasixulae mead and meogen oeldes §W.4m-Repormy and mcorddepaia repueemerm • MALT Analysis 40 M.00 63,Subpart MAR Doom NB5027 f0 realer saloon Indu0dal Commas.,aM(..banal Bogen and process garters I. Is de healer locatedat a test ldshat IS a major source dr0a0zi(§03.)4051 .r...'r;0dd,..3n0i Meted fond solos to mod. Dldmnswemn(§W.04W(Il or an(§63. 30(11 ads eater cramenm 303,10ne,20100 M'4,'i'..:,r 3. is de heat padryless[anor�ai ms MMen4A(§63.75m(e11 n 4 Isere heat Input capacity greater than 5MMgwmr but lm den or equalta10MMeto0?I§W.75Dgell No Ole wrote naa sondes a[enoueannudy. 'Sours h sod vegetate MALT 00000. §53.7500(el and Table 3-Work praNce standards §35.7310 -General...Leann. 435.7530lel-Ideal smjsmeneroroadeng sources oil 35.7531101 for new sour §63.7533141-Subsequent 0 rem,ma analyses or nandullo §63 040 .73501elendMso compile2s 463.754¢(MILO and(a lid)-Demonstrating continuous compliance §55.7545(I,(-for existing era-far new),(el,Mw,35161,aft),a(B)-Notification §53.75001q,1bh 01,131(1 and ( §6s.75ss(al, M sod al anti Wa5W 101,Ill and(0-riemeakeeping Disclaimer Thbdocunrantassisbap$sods w?M de)emin?ragappl03b➢hy of certain r quIremenh of the Clean Air AcC s implementing regulallees,end AN QuaMy Control Commission regulations Thls document's'Iola rule or,egula7bn,armt.analysisil00nlalns maynol apply.a partkularsNation base'upon the irdrtooI hots and tlmonsta007&Thisdocwuentd0.smf charge orWbs.tubrw anyhw,regulation,lrany olherlege0ybBndrgreg0venrent and not legally 000 amble.h Me erento/ any08000 between Me language 00000080menl end the language on.Glam.,.Act lh Implementing regulations,and Air Ovally.on.DI Commission regulallwns, Iha language oft.statue 0rregubtbn W210011000 The use01800-nandadry language such eS5ecamrrenq'-mar:Thoud,'ard tan.'lslnbn2db des..APCD Mlerpreblbns and recorrimer.tions M2Mebrybmi00bgy such as-must and're31005t ere In...s cla I0003nb0l1Mgraquiminanh under the terms of the 02303 Air Act am:Al Welty Control Corrvnrssbn regula0Ws,but Mis recnman0does not eslabtish legacy b2mng requlremen0!nand of bell. Condensate Storage Tank(s)Emissions Inventory 010 Condensate Tank 123 - '.9FBB 010 Facility AlRs ID: County Plant Point Section 02-Equipment Description Details Detailed Emissions Unit Four(4)1,000 barrel fixed roof condensate storage vessels connected via liquid manifold.Tanks store siabil[zed. Description: condensate from Train#1. Emission Control Device Enclosed combustor.During any ECD downtime,emissions will be routed to an open flare(FLARE-1) Description: 111 a: Requested Overall VOC&HAP Control Efficiency%: 95, Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Storage Tank(s) Actual Condensate Throughput= "1A','t:lli1,(ii ]rjJlII)It Barrels(bbl)per year Actual Condensate Throughput While Emissions Controls Operating= ''.Barrels(bbl)per year IRequested Permit Limit Throughput= 1,,,,„,__2;971;1)00'.;Barrels(bbl)per year Requested Monthly Throughput= 167,400.00 Barrels(bbl)per month I Potential to Emit(PTE)Condensate Throughput I I ,t: s 3C 7 0 d,Barrels(bbl) - _ a ,�a9� 0,;. Per year• Secondary Emissions-Combustion Device(s) Heat content of waste gas= 3577 Btu/scf Volume of waste gas emitted per BR of liquids produced= 0.64 scf/bbl Actual heat content of waste gas routed to combustion device= 0 MMBTU per year Requested heat content of waste gas routed to combustion device= 4,641 MMBTU per year Potential to Emit(PTE)heat content of waste gas routed to combustion device= 4,641 MMBTU per year Combustor Emissions Control Device: IEi cbsed Cutnbustor(Make:TBD,Model:TIM) Pilot Flow Rate: y,-50.00 scf/hr Pilot Gas Volume: 0.53 MMscf/yr Assist Gas Flow Rate: 1200.05 scf/hr Requested Assist Gas Volun 10.51 MMscf/yr Fuel Gas HHV: 1050,00?Btu/scf Pilot Heat Input: 551.88 MM Btu/yr Assist Gas Heat Input: 11037.60 MMBtu/yr NOTE t THIS COMBUSTOR ALSO CONTROLS EMISSIONS FROM POINT 017.AND 012,HOW EVER,ALL EMISSIONS PROM U€LCOMBUSt7ON AT THE ECD AR€REPORTED WITH THIS POINT. lI • 29 of 65 K:\PA\2018\18WE0465.CP1.xlsm Condensate Storage Tank(s)Emissions Inventory Section 04-Emissions Factors&Methodologies Will this storage tank emit flash emissions? Emission Factors Condensate Tank Uncontrolled Controlled (Ih/bbl) Emission Factor Source Pollutant (lb/bbl) (Condensate (Condensate Throughput) Throughput) VOC ."0.0932 0.0047 ° 1 ,83Seoth31i Benzene 0.0012 0.0001 5#ma5 Ai; 7 Toluene 0.0034 0.0002 EFATANKS 4'Woziang Ethylbenzene 0.0603 1.3E-05 EPAT'ANK5 E".Fktteand0anathie Xylene 0.0026 0.0001 c, yT 'Worror atuf 82281 sir n-Hexane 0.0067 0.0003 Sit ,, �tr�g,and Btesthin 224 TMP 0.0000 0.0000 Site ;,.,., „ ?td,&2dfh7P Waste Gas Combustion Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) (l6/bbl) Emission Factor Source (waste hest (Condensate combusted) Throughput) PM10 0.0075 0.0000 '3' r PM2.5 00075 0.0000 NOx 0.0680 0.0002 kP. h CO 0,3100 0.0007 t$F^.F2,Chapter ,Ith0 , , Pilot Gas Combustion Uncontrolled Uncontrolled Pollutant (16/MMBtu) (Ib/MMSCF) Emission Factor Source (waste hest (Condensate combusted) Throughput) PM10 0.0072 7.6000 T PM2.5 0,0072 7.6000 T NOx 0.0952 100.0000 '92Table CO 0.0800- 04.0000 'beT-atde ;'q ,�. q Assist Gas Combustion Uncontroled Uncontrolled Pollutant (Ib/MMBtu) (lb/MMSCF) Emission Factor Source (waste heat (Condensate. combusted) Throughput) PM10 00075- 7.8750 'T T 111-2jpM1 PM,2.) - PM2S 0.0075 7.8235 NOx 0.0680 71.4000 UlNOs( ;k� CO 0,3100 326 5000 Aern;s Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontroled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month) VOC 91.8 0.0 0,0 91.81 4.59 779.8 PM10 0.1 0.0 0.0 0.1 0.1 10.3 PM2.5 0.1 0.0 0.0 0.1 0.1 10.3 NOx 0.6 0.0 0.0 0.6 0.56 95.0 CO 2.5 0.0 0.0 2.5 2.45 416.6 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year) Benzene 2440 0 0 2440 122 Toluene 6761 0 0 6761 338 Ethylbenzene 504 0 0 504 - 25 Xylene 5110 0 0 5110 256 n-Hexane 13127 0 0 13127 656 224 TMP 10 0 0 10 0 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 not subject to Regulation 7,Section XVII.C.2 Regulation 6,Part A,NSPS Subpart Kb Storage tank is subject to NSPS Kb Regulation 6,Part A,NSPS Subpart 0000 Storage Tank inner subject to NSPS 0000 Regulation B,Part E,MACT Subpart HH Storage Tank is not subject to MACT HH (See regulatory applicability worksheet for detailed analysis) 30 of 65 K:\PA\2018\18WE0465.CP1.xlsm Condensate Storage Tank(s)Emissions Inventory Section 07-Initial and Period ic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? If yes,are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? WAWA If yes,the permit will contain an"Initial Compliance"testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. 0 ' nr 'i 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 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 - w ' 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 05-01. a control device efficiency t Does the company request s1s y'P Y ry greater than 95%for a flare or combustion device? iF` * 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 *Based on the process description provided by the operator,the condensate that results at the inlet receiving stage Is routed to a stabilizer prior to distribution to the storage vessels.The stabilizer Is essentiagya separation device that removes the remaining lighter hydrocarbons from the liquid.As a result,the condensate is stabilized once it is routed to the condensate tanks, *Source estimated emissions from this tank using EPA TANKS assuming RVP 10 liquid stored. *According to"Fundamentals of Natural Gas Processing,Second Edition"by K(dnay,Parrish and McCartney"[Reid Vapor Pressure)values range from 10 to 34 psi,but the common range is 9 to 12 psi when the liquid is trucked offsite-" Therefore,I will accept the assumption;of Gasoline RVP 10 for use in EPA Tanks4.09.4 for the condensate corn postion - ' ate order to calculate combustion emissions,operator calculated the volume vented from the condensate tanks using the idea(g as law(PV=nRT)The values used in this calculation areas follow-, {I)n=(91,81 ton/year)*(2000 lb/ton)*(1 lb-tool/66.Ib)=2782.11 lb-mot/year - (ii)P=12.12 psis Oil)T=512.45 0(52.45`F) (iv)R=10.731 psta*ft^3/R*Ib-mol V.(2782.11 lb-mo€/year)*(10731 psia.*ft^3)/R*Ib-moo*(512.45R)/(12.12psia)=1,262.804,076ft^3/year This value was converted to scf/bb by dividing by the total throughput. - - - note.The calculation in this analysis is based on standard cubic feet(i.e.f=3 @ STP or serf).The volumereported above is"actual"volume(i.e.ft^3 @ actual conditions).If you convert the actual volume above to standard volume(i.e. scf),you use the combined gas law(P1*V1/Y1=P2*V2/T2).Carrying out this conversion indicates that the volume at STP is 950,840.48 scf/yr.Since the value calculated Mantua'cubic feet is more conservative,it is accepted here. *MW of vapors is based on AP-42 Table 7.1-2 for RVP 10 liquid at 60F(66 lb/Ibmol).Based on this molecular weight,it is assumed that the HHV of the vapors tart be reasonbly approximated based on the physical characteristics of butane(MW 58 Ro/lbmol)and Pentane(MW 721b/Ibmol).Interpolating between the gross heating values of the butane and pentane,a heating value of 3677 is assumed. • *The emissions o€}IAPs are based on a stabilized liquid composition from a similar DCP feciltiy-The weightfactions are multiplied by the total VOC lossesto deterndnelosses of the respective BTEX components: *Emissions of NOx and CO horn combustion include emissions from combustion of pilot fuel and assist gas(referred to collectively as"fuel gas'in this discussion).Fuel gas emissions are acounted for with the emissions reported as -. Point 010(TANKS-1).This was done to avoid confusion in allocatng emissions based on relative gas combusted from the various emission points routing emission to the ECD(Point 010,Point 011,&Point 012)-Fudges emissions are based one heetvalue of 1,050 btu/scf and 1,200 scf/hr flowrate of assist gas.Fuel gas emissions were reported with this point(as opposed to 011 or 012)since DCP plans to construct and operate this source first. *Vessels with capacity<10,000 bbl used for condensate stored prior to custody transfer are exempt from the requirements contained in NSPS Subpart Kb.This faci(tiy receives pressurized condensate from surrounding midstream facilities(see point 013)that is stored in addition to condensate that is separated from the gas stream at the inlet slug catchers.As a result,the liqu€8s received are considered'post custody transfer'for these purposes and the source does not meet the exemption criteria in Subpart Kb, - - - *This storage vessel is subject to NSPS Kb,In order to comply with this requirement,the operator has indicated the storage vessels will be controlled with either: a closed vent system and an enclosed combustor(not a flare(;Based on§60.11fib(g)"each vessel equipped with a closed vent system and control device-..is exemptfromthe requirements of paragraphs(c)and(d)of[§60.116b]As a result,I did not include information pertaining to the determination of the maximum true vapor pressures found in§60.116b(e)since paragraph (c)end(dl are the only sections that require moniturleg of this parameter, *NSPS Kb 60.113b(c),each source equipped with a dosed vent system and control device as required in 60.112b(a)(3)or(b)(2)(other than a flare)is exempt from 608 General Provisions and shall develop and lotlowa monitoring plan per 60.113b(c)(1)and(2).As such,DCP wilt be required to submit a monitoring plan for each control scenario since an enclosed combustor is not considered a flare for purposes of NSPS Kb_EPA has stated that general NSPS requirements for flares as well as the general MACFrequirenrents for flares apply to open flares only and not to enclosed flares or enclosed combustor(citation:ADt 0000019),Furthermore,NSPS Kb requirements in 60113b(c)(1)(i): mentions speidf design paametersfor"enclosed combustion devices"that should be addressed in the monitoring plan.This requirement was communicated to DCP and the citation of the rule language pertaining to this requirement was included in the permit DCP has indicated that"an operatingp€an per the requirements of 40CFRS0313b(c)(1(will be prepared and submitted to the Division.The dosed vent system and control device will be operated and monitored in accordance with the operating plan submitted to the Division:A copy of the operating plan and record of the measured values of the parameters monitored per 40 CFR 60113b(c)(2)shall be maintained for at least 2 ;. years,' *AOCC Regulation 7,Section Vl establishes requirements for the storage and transfer of petroleum liquid.Perthe definitions set forth in Section VI,petroleum liquids are defined as"crude oil,condensate and any finished or intermediate product manufactured or extracted lea petroleum refinery".This plant stores condensate on its premises,however,the Division has determined that the original intent of this rule was to regulate gasoline storage and loading facilities and it is not applicable-to facilities that have tanks that are otherwise regulated within Regulation 7(SectionXVll)-Therefore,it has been determined thatthe requirements of Section VI do not apply at this facility. *Upon review and dscussion of draft permit,DCP indicated that the flare is not a backup to the enclosed combustor due to-low operating pressure of the ECD.The PA and permit was modified accordingly, Section 09-Inventory SCC Coding and Emissions Factors Uncontrolled Emissions AIRS Point# Process# SCC Cod 1 Pollutant Factor Control% Units -;1 010 Ol '" 'A .�. �, � �t.--.:.,,1)Z,9.� -, � .• `4:.0 li PM10 0.00 0 lb/1,000 gallons condensate throughput PM25 0.00 0 lb/1,000 gallons condensate throughput NOx 0.01 0 lb/1,000 gallons condensate throughput VOC 2.2 95 lb/1,000 gallons condensate throughput CO 0.06 0 lb/1,000 gallons condensate throughput Benzene 0.03 95 lb/1,000 gallons condensate throughput Toluene 0.08 95 lb/1,000 gallons condensate throughput Ethylbenzene 0.01 95 lb/1,000 gallons condensate throughput Xylene 0.06 95 lb/1,000 gallons condensate throughput n-Hexane 0.16 95 lb/1,000 gallons condensate throughput 224 TMP 0.00 95 lb/1,000 gallons condensate throughput 31 of 65 K:\PA\2018\18W E0465.CP1xlsm • • • Candeisate Tank Regulatory Aralrss Warl,heet Colorado P.„a.6 mrsmmaxam.tarmr.m.raa maa"m"' I.Arc amal miss.,from a:•..eria colt..Iran wawl e.al souzpeatarlton irregular.3.van0.5mxa muka«wdata w«rm 12/30131.3 and w...daxv tzAznovz4.brenoaazoennaloaz.0 ami.14 anduewn zta amdonalvmn. pa:...ra*.b.d, s.netvd a faeadvu:mmw a miv vocnlaslo etctlnn 5 Tr, gra a m terthan lgnr aum p sbe m create, to y@°coil.3,van 6,546,110.31, 'Not enousb eo:manon NOWAITAIWIENT 1.Aream.wld emissions immemoh®porn..rmn this toilvrdoal soumr.terthan 3rvy lReculaaon 3,Part 0.5a+dn.6121, 'h[ mRwamanu3x.6nwm.m.ovuamn 2.Is Inaoastaction data ise.adatel pmrW1zlsanam and nxnwarad arterssn,n66z(See PS won va 60,1.1.and 5octlmzr.a al rvlmrma:m.ax+es-avWebityP Ne' 3.Are pam.n zm,xaaeaer am erNsas patatwn 10"UN(RegJa1.3,nda,s,mon.a11, ra--...,.smmgaam a perm, von Cobado mgdmwn r serbnpc d .f 1.xsMsnmRtaNlmtealnlM1•¢.boswe mmrol area aamomre.net.lmnent area oranarnmetimenrw:e"ape,2.Isl.stocaeo'Link looted at an oll ard gas ezoloralbn ra I�m ro m d mai.abrkaentb,',rarural gum,.eorau.4vtural gas cop Natlmi xa rvnnt«naauhi mto 1:1 II Ini anhliNNwanm•eaknaoemamae4. 3.Is DA ng dam• '.%..: jAa Section Alt. aa,nl... s :dlA,a•, bEp,m.nm-Praaxl.va,.K SactionYILE-Aaing salonsan-Rmel l.d and nepenthe ...ion natural -J oalmn.mwnan.u. m..b.no mWsl4mnbm and have ante anima.g:ateraho nwrarw:w twrra er rva 3a'_-... Sumo h...mwero+w newam"i.5ev«•nn Internee inn.not cobs toss-ton, ,.serrion pia Solon -Ernbslons Control lieourannes. Soction MIL.-General Requirements fix", «n Comm 5owPm=a_Prevention olLoatage coload..ga.emd,.tatra meiwnoagetamwr ,.x,.660 4atam ,w �m,«a, w.e«draadm.atma4®coma p 6666. 6,066 2.la Ws conderraarestoragetank Imatel xan and supMtbnard production op4a6..wdlwmalm laaM',natural ga mmP.WtaNbn'anatural gas pawing.. sanaarnawuaamrmenaemrmsammamaea a,avumal� suhbttm6eW;d"•5miontoo-p.8.....P.yo WC, -.... .mm mpare., uonismmrrv,Wemwxnnmwemon cage tank on cs .5.crionxviLa—General Provhions Vol..Control Comm,adMmaoNavmwmw pnm and Pmemnnd6mxslom aerns 5.Oa. m g�Ye mN'samrtw Roo., I.h fro:�sm n re=a<wlmmneN.tom a.swr.mu Salon XV1I.G.2 Ca...ream!eelonlioringia.Storagerarb fitted wall Alr Pollabn award Esnicam.a ja OS Part 60%Wart Kb.wndard,a Porforrnanc4 for Yak.pn swap Pope} u:Imh rn33 a v 3, 6anlss11,..itma m ermoaoua Peemanoas vast,coedtdm,..a4npmm n;no,a4 MU 0,6021 ramm4.n'am,danaaamoaa.wo®41.awtm adnrwaewamawer a.dar,w in 601.111, 3. eirememn2.333. reL I><emRnvwswaR6g11 anawryz3,3aa,4.Does enm n a,alwtd NOW'deindma6.111bp m� Go to �ma o 6. emPtbm a v> 5.115..a.Is thastoralevessel a 6 deMgmlto von Ma).1 and out amsaomo mmdm laialeNdll311i or Na�Y:.ky�ko b.The des.son rW rzo Rajah pert ram a blbnr:or mud ton M'ra eau t lest limn 151m'[950 aeu and na,e.a HeNdwhna maximum Ime.am due m man15.a real6.stmb➢r GIs wnualamr,�n a�R5:c Er, r CoProvisbns ad.wemc _ 460.113.13-.core and Pmedum §60.156-k000Nng•nd RecodNeeplrg Rmwremeroa g60av6b-MomRMngorooanlms man Paco W aYw+rt wx,padarm N P•rlamara per Cn...a3 and Natural as Pmduabe Tts:wbtloo and obmion t Is Ills a ianlNnrb[cohort al and natural gaspolnwn natural pos ing segment orneval gas trammbe and g segment wei toftrev x.Was ulk condermarencraga r®mtmad or mad.lseelg rhwrtapan,..)Isawvn.a.,,zmsand....v.xau, e• nnaw,.mraraaa Pronomeaop lax ore... emissions'from!Gated d e nwwn,om d-uonr se r 5.Nine e r.an or wequaltors mw Ions J.. m timnaub xsna6ro elsu6e4.Doas thh condensate ewa� de d mm,baun am4mmewnn r4wlmmemt for mage vms.rao vR Part sdart Kb maw von 63srbanxx, 'a.m costs,=e s+rPm 4 6 eraal P.*.per 450..x5 mote §665395-bnNbm Control s.rdardafvvoc 406.13-.amrr as vromive g60s33.1-xanowr.Reporting and xeaaraang uwwn as §6a.161d-Col Requirements 460.5•17 Devito Devil Closed "g Ixm.:ea66611.vonall.va.o.obt•o•rmrr.dnb..uwaa*a usPsa000au.to...or.ama6mm per war vac ontt..evllabuty d•mrmlmnndea,It Amid remain auw.ct to raps ouco per 6a.63.•llzl.an pe.m3drx emralom drop baloma6 tompe Vaal 1. n .anon andmatural gup-cducdonfaditythalmeatsetle.arthr5*gciteria: Ir.s koalas, bare'mowed the sow.aa®r,.menolmsammaa.a. a.AfaoRrtrat orom.e.uogada a none Mdrmmarxwrds 1a3.]6ulaifa11:a3 Afarflty that puaaa,ureade of store natural Pa lope the paint at whim nxad ras mm lna natural as tantmxtwn and stoawemrx.tewry or is aanerd tea',Word user'(63.36.113111 swnu h mmla w "5nots. srxx tn4.aa•am...CrCrmreanmNb b.n"atamloon= waer«4.Qom thet.F.most • S.rsthet Pan66.6bwrtgbdshalOC or.36u ,-......... dl. 5ubo�AGm�Itpoilslams Per 463i.Ial.pble 563.366-6mmwnt Contra 5.daw u3.i35-Monnpdne g53_»..RmdNeam 5.53.775•Reporting PACT rm... r•ardaalrx•al•tlenadoss mtapw...PI16 tank laInaba rarattarnetoea.x'rho tank mash both and.,Own m ia...0aardmm4da cobdmwmin assists coaamx.11 OMe'rrening applicability ofcaaln ra¢rleenk oflm Crean Air Apt if inpxmenting bum,and Ab one CmM Cammksim regdanons.This decu�nt is not a rmmm.agubnon..a th analysis contains may not 6ppy bapadcdan stalianb6SM upon the individual fans am®cumstance,me Occuinent dens 50t change nauM�Iforany and Iifb irq.eat>emne.eis mliegsif Corp®anb.m ua eventaanY conrtsl...en live 6�W Of ropunenl and lnen.Ipugewue Can uycoremfcommesion repuerure.phe aaxyap.of Mauna regp6Pon peg awmpl. rusofrwn+ramsary 6muaseswnxs YxwrvreM".62..' •"pima•aid •�snendsd rams,*Aeonxd6rperaiips anarao,nemalanv Mandatory luminaapr suchasrest and•aatrer are',vended Iodesamamnbapmg.ry6aamanis u r melemmw ma n66Ael ands.olaon Can MN 0610..56615',gnation,but Una document does not establish iagsiy656150 aginninanis wane ofd,w. Condensate Storage Tank(s)Emissions Inventory 011 Condensate Tank Facility AIRS County Plant Point Section 02-Equipment Description Details Detailed Emissions UnH Four(4)1,000 barrel fixed roof condensate storage vessels onnected via liquid manifold.Tanks store stabilized Description. condensate horn Train 2. Emission Control Device Enclosed combustor..During any ECO downtime,emissions will be routed to an open flare(FLARE-1)Description: y„ Requested Overall VOC&HAP Control Efficiency%: 95 Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Storage Tank(s) Actual Condensate Throughput= g,TAPREMPM,Barrels(bbl)per year Actual Condensate Throughput While Emissions Controls Operating= Barrels(bbl)per year I Requested Permit Limit Throughput= 1971.dUft Barrels(bbl)per year Requested Monthly Throughput= 167,400.00 Barrels(bbl)per month Potential to Emit(PTE)Condensate ::'::KRE;: Throughput= 1297,1,,000 Barrels(bbl)per year Secondary Emissions-Combustion Device(s) �� Heat content of waste gas= .; 1P7'3 63Y77 Btu/scf Volume ofwaste gas emitted per BBL of liquids '"Sg '1.11h j 11 produced= acf/bbl Actual heat content of waste gas routed to combustion device= 0 MMBTU per year Requested heat content of waste gas routed to combustion device= 4,641 MMBTU per year Potential to Emit(PTE)heat content of waste gas routed to combustion device= 4,641 MMBTU per year Combustor Emissions Control Deuce "i asus aT"LAtie �£g94Wt,,,r". ,p s Pilot Flow Rats j� ._ ct/h r Pilot Gas Volume. 0.00 MMs O yr Assist Gas Flow Rate) '' „, .,,sfihr IRequesteri Assist Gas tolun 0.00 MMscf/yr I Fuel Gas;1HV: f33 9731€y4f„ .9tu;scf Pilot Heat Input: 0.00 MftlBtu/yr Assist Gas Heat Input: 0.00 MMBtu/yr COMBUSTOR FUEL EMISSIONS ARE INCLUDED IN POINT 010 33 of 65 K:\PA\2018\18WE0465.CP1.xlsm • Condensate Storage Tank(s)Emissions Inventory Section 04-Emissions Factors&Methodologies Will this storage tank emit flash emissions? ,,• , Emission Factors Condensate Tank Uncontrolled Controlled Emission Factor Source Pollutant (lb/bbl) (lb/bbl) _ (Condensate (Condensate Throughput) Throughput). VOC 80982 0.0047 )&s:„:„,„ AFtKS EX.Worn" Sreathc' Benzene -80012 0.0001 e_ LYKSCF Workf 8raeth€r Toluene 40034) 0.0002 :St7ed#7 F Worhhs9 e thk Ethylbenzene 0.1Y003. ) 1.3E-05 '!1X ,v,Wtuk$ip,:1 t'math Xylene 00020 l) 0.0001 7ic ., n-Hexane 00097-- 0.0003 224 TMP 0.0000 0.17000 ._"ffs EPtF ngatsF ., Waste Gas Combustion Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) (lb/bbl) Emission Factor Source (waste heat (Condensate combusted) Throughput) _ PM10 0,0075'0100 0.0000 —0hIat PM2.5 0.0075 k 0.0000e• NOx 0.0680 0.0002 1(042).,..):. y CO 0.3100- 0.0007 Ti#+42Cha _t -:x .-,tr:,lled Pollutant •-_ ;lb/MMSCF' S„isstcc Factor Source - "ondensate ihroughuuti P9910 PM2.5 NOx om.j"Y33,__..-oustton ..ncontrollen Pollutant (Ib/NIMSCF) Emission Factor Source (Condensate Throughput) PM10 PM2.5 Y /00'40 NOx - Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month) • VOC 91.8 0.0 0.0 91.81 4.59 779.8 PM10 0.0 0.0 0.0 0.0 0.0 3.0 PM2.5 0.0 0.0 0.0 0.0 0.0 2.9 NOx 0.2 0.0 D.0 0.2 0.16 26.8 CO 0.7 0.0 0.0 0.7 0.72 122.2 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Ohs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year) Benzene 2440 0 0 2440 122 Toluene 6761 0 0 6761 338 Ethylbenzene 504 0 0 504 25 Xylene 5110 0 0 5110 256 • n-Hexane 13127 0 0 13127 656 • 224TMP 10 0 0 10 0 Section 06-Regulatory Summary Analy-s 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 XVILB,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 not subject to Regulation 7,Section XVIl.C.2 Regulation 6,Part A,NSPS Subpart Kb Storage tank is subject to NSPS Kb Regulation 6,Part A,NSPS Subpart 0000 Storage Tank is not subject to NSPS 0000 Regulation 8,Part E,MAR Subpart HH Storage Tank is not subject to MAR HH (See regulatory applicability worksheet for detailed analysis) 34 of 65 K:\PA\2018\18WE0465.CP1.xlsm Condensate Storage Tank(s)Emissions Inventory Section 07-Initial and Periodic Semolina and Testing Requirements Does the company use the state default emissions factors to estimate emissions? - dyes,are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? ry lives,the permit will contain an"Initial Compliance"testing requirement to 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? If yes 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 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. Tel0PreiltIVISMI If no,the permit will contain an"Initial Compliance"testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. 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 ii Based on the process description provided bythe nparatpr,ilia condensate that results at the inlet receiving stage is routed toe stabilizer prior to disifl m butionihe storage vessels.The stabilizer is essenitalyaseparatien device thaT"� renovesaheremaining lighter hydrocarbonsfrom the liquid.Asa:revolt thecondensate is stabilized once d is routed to the condensate tonics. " "Source-estimated emissions from this tanRusing EPA TANKS assuming RVP 1D "Accordingto"Fundamentals of Natural Gas Processing,Second.Edition"'by Iddney,Parrish and McCartney"(Reid Vapor Pressure]values range from 10 to 34psi,buttlecommon range is 9 to 12 psi when the liquid is trucked offsite'' Therefore,heal accept the assumption of RVP 10foruse in EPATarrks:4.09.d for the-condensate-composition. - - - "In order to calculate combustlonenrissions;operator calculated the volurhevented from the condensatetanks using the ideal gaslaw(PV=nfT(.The values used in thisca₹cu(atinn are as follow: (I)n=(91 81ton/year) (20001b/tan)"'(1 lb-owl/66 lb)-2782.1116-mil/year 12.12 Oa (iii)T=512.45 R(52.45°F) (£v)R 10.731 psis"R^3/Rtlb-mol - - V=(2782.1116-caul/year)*(10.731,psi a+ft^3)/R•1b-mot)"(002AS R(/(12,12psia)=1,262,304,076-ftu3/year- Thisvaluewasconvertedtoscf/bbl by dividing bythe total throughput. • - - vote The caltsilotion lv thlsevolvoiv is boned DO Standard cublcfeet(1,e>ft°3-@STP orscff(.The volume reported above is"actual"volume(haft 3&tr actual conditions},If you convert the actual volume above to standard volume(I.e. 1. scff(,you:use the combined gas law(Pl*V1/T1=P2'V2/T2),Carryiogoutthisconversion indicetesthat the volume at5TP is 950,840.48 sdjyr.Sincethe value calculated in actuoleubic feet is moreconservative,it is accepted here, *MW of vapors is based on AP-42 Table 7-1-2 for RVP 101iquid at SOF(66 Ib/Ibmot).Based'on this molecular weight,itis assumed thatthe}7HV ofthevaporscan be roesonab€y approximated based.-on the physical characteristics of-- butane(MW 581b/Ibmoi(.and Pentane(MW 72 lb/Ibmol).Interpolatingbetweea the grass hnotfegvaluns of the butane and pentane,a heatingvalue of 3677 is assumed. 'The emissions.ofHAPs are based on a stabilized liquid composition from asimfar DCPfacility,.The weight fractions are multiplied bythetotalVOC losses to determine losses of the respective BTEX components:. - remissions of Moo and CO from combustive includeemissions from combustion o€pilot fuel andassistgas(referred to collectivelyas."feel gas"in this discussion).Fuel gas emissions are accounted for with the emissions reported as PotntUl0(fANKS-1).Tbiswas done to avoid confusion in allocating emissionsbased on relative gas combusted from the variousemission points muting emission to the ECD(Point O14 Pointi11,&Point 012).Fuel gas emissions are based ona heat value of 1,050 btu/scf and 1,200 scf/hrflowrate of assistgas. - - - 'This storagevessel is subject to NSPS Kb,In orderto complywith this requirement,the operator has indicated the storage v essels imbibe controlled with either: aclosedventsystemandanenclosedcombustor(note flare);0R- - - a flare.:.- - - Based on t60,116b(g)"each vessel equipped with a closed vent system and control device.-.is exemptfrom the requirements of paragraphs(c(and.(d)of(§60.1166],"Asa result,l did not include information pertaining to the deierminationofthe maximum true vapor pressuresfound in.;§60.116b(a(:sinceparagraphs(c)and(d)arethe only sections that require monitoring ofthis:parameter, 'Vesselswithrapacity<10,000bbl itsedgor condensate stored prior tocustodytransfer are exemptfrom the requirements contained in NSP5Subpaml Kb.This facility receives pressurized condensate from surrounding midstream facilities(see point 013)that is stored In addition to condensate that is separated from the gas stream at the inlet slug catchers:As a result,the liquids received are considered"post-eostodytzansfer"for these purposes and thesource does not meet the exemption criteria in Subpart Kb. - • `NSPS Kb 60.113b(c(,cads source equipped with a closed vent system and control device as required in 60.112b(a((3(or(h)(2((otherthan a flare)is exempt from 00.8 General:Provisions and shall develop and follow a monitoring plan per 60.113b(c)(i)and(2).As such,DCPwtl be required tosubmit a monitoringplan for each control scenario since an enclosed combustor isnot considereda flareforporposes of NSPS Kb:EPA has stated that general N5PS requirements for flares aswell as the general MAGIIegolrements fordaresapply to open flares only and not to enclosed flares or endosedcnmbustor(citatlon:AD€0000019).Furthermore,NSPS Kb regoirementsin 60,113b(c)(1)(i) mentionsspecdlc design parameteesfor"enclosed combustion devices"thetshould be addressed in the monitoringplan,This regoirementwas communicated to DCPand--the citation of the rule language pertainingto this requiremeotwas included in the permit.DCP hasindicated that"an operating plan per the requirementsof 40CFR 60.113b(c)(1)will be prepared and submittedtothe Division.The closed vent system and control device will be operatad�arid monitored in accordancewith the operating plan submitted to the Division-A copy of the operating plan and record of the measured Values of the parameters monitored per 40 CFR 80,1134(4(2)shall be maintained for etleast2 years." Since the apen flare(Paint WA)will be,uded to control tank vapors in the event of ECD downtime,it is subject to the requirements of 00,10 per 50,112b(a)(3)(d) 0AO,CC Regulation 7,Section VI establishes requirements for the storage and transfer of petroleum liquid.Per the definitions set forth in Section VI,petroleum liquids are defined as"crude oil,condensate and any finished or intermediateprodact manufactured orextractedina petroleum refinery'?.Thin plant stores condensate units premises,however,the Division has detenninedthat the original intent of this rulewastoregutate gasoline storage and loading facilities and it is not applicable tafadlities that have tanks thatare otherwise regulated within Regulation 7(Section XVII).Therefore,€than been determined-that-the requirements ofSectioo Vldo not apply at this facility. Section 09-Inventory SCC Coding and Emissions Factors Uncontrolled Emissions AIRS Point 8 Process B - SCC Code 1 Pollutant Factor Control% Units 011 01 6#1ink Yd s.� _ ,'j PM30 0.00 0 lb/1,000 gallons condensate throughput PM2.5 0.00_ 0 lb/1,000 gallons condensate throughput NOx 0.00 0 lb/1,000 gallons condensate throughput VOC 2.2 95 lb/1,000 gallons condensate throughput CO 0.02 0 lb/1,000 gallons condensate throughput Benzene 0.03 95 lb/1,000 gallons condensate throughput Toluene 0.08 95 lb/1,000 gallons condensate throughput Ethylbenzene 0.01 95 lb/1,000 gallons condensate throughput Xylene 0.06 95 lb/1,000 gallons condensate throughput n-Hexane 0.16 95 lb/1,000 gallons condensate throughput 224 TMP 0.00 95 lb/1,000 gallons condensate throughput 35 of 65 K:\PA\2018\18WE0465.CP1.xlsm • • • • Condensate Tank Regulatory Anatysk Worksheet Colwam aaNeavm Pam A end 6-Antimars Corm.eqummarss xmx roam n L.e wax..actual en....from any...wtwrssIrom twMaumawas greater.n2Tsrtaewlat.3,Penn,SIamn 11,1.1.4li fffk'GLG�d, els.cemW wwo 12/30/2002 and:umnalatianassryr(ccCO a PSMenoasazx.410 e3.zza:w.v+a:asm34efen admmal e�dda.xen:mnmatl�erewrouayli i2 3,nnstadfaam.mrs.ldvoeemmios emetonsipr xa e.mtonvu Tr(emermi.o Awr.twn3DR7r f,1gwtw3,van 3.sez.l3osli p•^�''��d. 'Not ann.nmrmetrsn Notkvrpowelr 1 x uncomdled eanuox from anyone.pagmnsxnmtMwe.dwlgom ratter wn3rPy(R<Nad.3.pan,54:41.1,431.41•2 4m.nnoio.nartx.6omwe.nnvgdn sate Is.x<mtel prb.12/30/20:13.ansl net,edited J4.412/33/2002 1s.PSMegtaL3 Dmna we 3 ss anu.v+amsex2n 3.4.14441 gudanem aareal.444.M�barNi 3_Are e,eoerthanz M..4 greater then snywm emissions 0eteron1gm 1,14(4141.3,Pana,swma.o.zli Nam, ndea pewit ualsl 4(y named s pet. • 2.Is thIs rode 714Nge t1.Is thla stonge o en al Mm melon and p:niuv t.natwaw.nvmare central area oranyaver.enon•etninment area omxon w naturnaintenance ral Ras one seas mbwn4eecno an73.4.,1 rwe.a•el win real., weed. .03 II. • 3.Is this ng.rnt swage Sect. -Gencr4,44euirements m..b EpWome t-Prevention ate..S4.41444.41L11-Emissions Con.ilepatirearmem, Colorado lwme• I.Ls this Iterate 4dl�nd, o e w area :q:.wl,:men area oramx,ment/maMenanceneat2.Is.staneetaa m' :.�� 3.Does nkeauba natural :ablerninlons and have u.,...,.a.e aeielemsabns greeter or gel to,tmas oervearvoci 041.: a rank enots..e:eW.uan a.nw®rata w`jS T.s.,:nn,xl.D Seaton XII..-6eneral Kbautrements Poll..Control Enulprnent-Prevention of Lukage Calera.e4(,dad2n T,e.,11,1,1 xwn • 1.1st.tank Iccated at a transmisslon/storagefa4414, .ou 2.Fs This condensate stooge Mk'Imated at an el and gal*ration am n:minlon°Mon.wdpmmdaaadld.nat 444 gmpr 4,44,..natunl gss poxeslmgami a4a...ImleuanerzrnP.a.P�epersmmwenen. 3.Is ThIscordereate storage tank a findmarmeeragen. Via:. +.An ureentrolled ecIWI ernisslcos4d.sewage..a Lew pm.,than 6t.awvearwe aa4:.xme,eomo44,4mwwrlee 7.srdwaawa.t.caw wnetee,en IS4.4424emliissulaiectlo See,n ',GI 8. .54.4.4411...Emissims.Dew.and 4.44naor44,44,44.4 Staloas.om 3se rennin snam.rmami rY" _J eTankenaa,daexte x.7 a..a.xvata Izw Sam Me and fOonitor414.5torageTarks .1.4 Pollution Control Foutment .44 1.la Illeandmdtial stare.vemel tawdry esealer.n or await°75 cubic m..),172 eaisR x. .v3gaN+ai rvu. Comweareoaan wanks Wnarewxu3.9.,Tam'rloAweaz1...enoleum'a.:d.satestaet.o:ecesmt.4(eandnlormenstoayteannelesadtnedlnw.ss3bi aw lsgdePntws4uag6011ahvbN 23,1984i lave,. ',togaam on me et me=sa-'® m -. en 3. xaxgelwa"e tbi as 6. ee ttmlaareingaskrntemplem:a.is thestora.vent vessel a�doesierxiaaaeved teoPoee In mums d 12.swariaimn and xMw ernbsamte,h..tuba Roa3oadaRIIi. rap we:;;� xarm m 1.950 earl and n.as a llmdxwt a ma.=tmevapwmes.. wnss wa lTouo(b)It or elnal.op 3�tereno�lem�.rrneanw less than sstm'rss00ea and stomaa2a sambametmenweraae,r2arre.Iesw2Is.bna160.33ubro07 .u.- mNSP6Rb pmgra,4.oere.lP,v lens 460.1131,-.ling nd Co t aasMrv« d Procedures 460...14-eg2.6g and neeabweepine ana:ar=mwa 460.11614-M2at.meolDpeatws 40 C R.Paneamb.eCoop,standard.of Permmaern for twoOil and Nat4.Ion Production rrs,.niman and Distribution faulty baknxe2mal and natural gas proaumonseDnert,ne.a1..p,mxra34(m23 a!gestnwnmkm 2:duwage seginert323133343337 2.Wastlaston*41.1.441.0.4.41 rwm:o...wmvnuna.wmodilai(sea drmmon.aa.3O1)bexvnwgun23.2033 anasepeberu,i2ssi axaala2Nspsmg0--m2 wasmawcnrnr.prods 223223121 date 3..2 060.4313CCeanisslorte from the inaledual norage.....21 pseater than or 2.31 to5 tors oe.mrr >: .w2mnnkeaR mama Ng,moo. 4.134..this cerdensalestorageuesseirneet theelefireima4steneemn4444 444605430? S. stl< x.brmauemere foram-age ve:esEn4um Parts subpart nor40tw 4.63swwiHIV Intaga rank is rat ter moo svn2.nA, a s0.ws 3 4441.31,95-4.114•44 Ca naa.VOC 4ao.M33-retx:e.dpr�me , 4...951s1.Nam Om.Reponing and n.,gsPelna Rgoken.n 4.0.,.3.1.1.coveam Coxed vent swim Monitoring Requirement uD.2037-4m.a Device M.ltnnna Requirements Immo:Ns glen,"ve.lo wwmtnryae..m6.a te b.wa.do xsPS LOCD a:.to.:rx.o:.,A..6 tens par sr v«onw applicability...nation den.It amaa ram.wnlaeo ears cos.P.ra0.,3e31a1131even d mum.v«.minion drop balow sivra p.r yaw, Part as,sutean buy 11,1.011 and D.P.mwan wd... 3.rs tresecnvianIg bat.at anal and natural gas pm:m.mayt.t meet,mnedtkbabe3gcriteria: Iva. Icarslme y.have .alvR .Summary sheet. 8.M.01y that onx 226.pgraaewstcrtshamn20ww'163.i6olmisl:0R fad.that 'antral gas[rim totbe paint at xd6mm-oil,.sers Ina robnl gas tnnamnsmnaMvoaxs.rrxca1egw art,claw...lea nmle.a.._.163.7601a11311i • is dletank mabi'fix RAW 32242 2232 133834432.ACTHU'T220214233001 HHO 3482212312 332224 338242483 1.isaas the tank meet thedanglori a4a~er..63.1i fll: 5.618#33383480203183832na2.0C 32060.wmerott23as we130wx63 3i Ieionk orn 0.u.val t sub provisions per...GI rabb z 433.786-Emwb,Control staraa:aa 4n.773-M2NteAg 4,13.774-em:akmare 463.773-Rwem6 PAU And* 2x02 3.2 'pared...lat.,dm rot app 322D 043 tank la tn..nonamimr.mama 2w eat raw:,bothwxar4,than mks.RAorqu,nx:m. Olzaalmer Ms l es.. 2pp1oa2343emadn men.,"sa22/tte Clean AbAel.3283.emenxn3 regulaton.and....Con., n.Camso 123330ane.Ma document a3(0lallon Wig.analysis n25(1223 may 4(27 app.,to a p4Teu3rnbalion based upon the...la Facts and timunsslancen.ilrk documentdoes not 3arge an substitute lorany • ae,requlal 4 a enyndle'IN0a6Y P.n..rynme.and's. In Ve event deny con/Rtbetvean 2331323222334038$68351243122#30322.31338032113110035.is Impbmanling rug...end Aip..Control Cnmmlaaon1.93632186,the 3.202,102sable ormgublon xWcon..The usealmn-men..y3rg2awaegnn Yaoamile.• • inlarpreIsnons and rerdmm Ie rertians.3lardal3ry ml...,2309 as'm2 m C and 66"squired are naee l2 aex1be.u2 nFr:gaeamemena under the lens 6/ am ma Clean Air Act a 4(v ownry Con.,Gom-raeai4n 1222632#4,beat...men,don.1201,3330legaly 3ra5greyu oment2 in 4(d 013320. Hydrocarbon Loadout Emissions Inventory 012 Liquid Loading Facility AIRs ID: 123 9FBB 012 County Plant Point Section 02-Equipment Description Details • Detailed Emissions Unit I II P t0ad00t of stabilized)eond mate i0tank trucks. "''' • Description: q rdffr"a�...,1laIX....�rkl. ,R1...� >�„n3,,3aIJ1�313� - :'-- !'•�A - Emission Control Device �tiased flare Description: Is this loadout controlled? Collection Efficiency: i..10O0 1131 Control Efficiency: 1 1 3 1. Requested Overall VOC&HAP Control Efficiency%: 95.00 Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Hydrocarbon Loadout Actual Volume Loaded= T:i Barrels(bbl)per year Actual Volume Loaded While Emissions Controls Operating= n3)1_^''r,•Barrels(bbl)per year Requested Permit Limit Throughput= - . 2,007;500',Barrels(661)per year Requested Monthly Throughput= 430500 Barrels(bbl)per month Potential to Emit(PTE)Volume Loaded= 2,002;500i Barrels(bbl)per year Secondary Emissions-Combustion Device(s) Heat content of waste gas= �- • I 3��'Btu/scF • Volume of waste gas emitted per year= 2792284 scf/year 1.3909 scf/bbl Actual heat content of waste gas routed to combustion device= 0 MMBTU per year Requested heat content of waste gas routed to combustion device= 10,257 MMBTU per year Potential to Emit(PTE)heat content of waste gas routed to combustion device= 10,267 MMBTU per year Combustor Emuslons p Control Device: Eitcl"aced combuuto(1�j 47 laiiek'fBbl.,. ,,;,,.ii1 1 1lILP :' Pilot Flow Rate: 113n I s scf/hr Pilot Gas Volume: 0.00 MMscf/yr Assist Gas Flow Rate: , ,,x'H �33;?sv/hr Requested Assist Gas Volume: 0.00 MMscf/yr Fuel Gas HHV: �,a 1d15Q� ,Btu/scf Pilot Heat Input: 0.00 MMBtu/yr Assist Gas Heat Input: 0.00 MMBtu/yr COMBUSTOR FUEL EMISSIONS ARE INCLUDED IN POINT 010 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*S*P"M/T Factor Meaning Value Units Source S Saturation Factor 0.6 � r., AP:42 Cfieptee: ," P True Vapor Pressure 5.0 '.j psia AP-42 Table 7.1-2 for RVP to liquid:RVPP is based"'ne a sta61"e';condeosate saugrle from another M Molecular Weight of Vapors 66 lb/lb-mol facility T Liquid Temperature 512-45 Rankine Avg Liquid.Bulk Temperature from EPA TANKS in Denver,CO.: Loading Losses 4.817365462 lb/1000 gallons 0.202329349 lb/bbl Component Mass Fraction Emission Factor Units Source Benzene 0,01329! 0.002688957 lb/bbl Stabilized condensate';sample3froae storage vessels at similar DCP facility Toluene 0.03683 S 0.00745179 lb/bbl :i/flhabflizet3 condensate'sampie'fttutstorage vessels at similar DCP facility Ethylbenzene ,= r 0.002744.}. 0.000555192 lb/bbl .: -a*Cab0(zed condensate sam le from;p storage vessels at similar DCP facility Xylene "=;,₹,,,,-OiT Z7fl4i. --" 0.005632849 lb/bbl .-' " STaliii ed condensate sample from storage vessels at similar DCP facility ' n-Hexane i' Tr 0.07151: '- 0.014468572 lb/bbl Stabilized condensate sample from storage vessels at similar DCP facility 224 TMP f ��, 0,00005 ,,, 1:fi: 1.07235E-05 lb/bbl Stabilized condensate sample front storage vessels at.similar DCP facility 37 of 65 K:\PA\2018\18WE0465.CP1xlsm Hydrocarbon Loadout Emissions Inventory Emission Factors Hydrocarbon Loadout Uncontrolled Controlled Pollutant (lb/bbl) (lb/bbl) Emission Factor Source (Volume (Volume Loaded) Loaded) VOC 2.02E-01 1.01E-02 €ier'S"pec#frt.AP-42:17capter5.2,Equation 1 Benzene 2.69E-03 1.34E-04 c AP-42.thapter5.2,;£goat xt ,"..; Toluene :, 7.45E-03 3.73E-04 AP-02.Chapter 5.2,£gtiattottS Ethylbenzene 5.55E-04 ',Ali',Alite 2.78E-05 AP-42 chapterS.2£git>rtwu 1 Xylene 5.63E-03 13 2.82E-04 a�w a-i r n-Hexane 1.45E-02 { .off; 7.23E-04 *''' 224 TMP 1.071-05 5.36E-07 _ G, Waste Gas Combustion Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (lb/bbl) Emission Factor Source (Volume (waste heat combusted) Loaded) PM10 0.0075 3.81E-05 ../.. 2.. Wg PM2.5 0.0075. 3.81E-05 AP-4k >., SOx 0.0006- 3.01E-06 a " NOx = 0.0680. 3.48E-04 ` CO 0.3100. 1.59E-03 AP , £hYeY1tfe,.r Ct hR_,.., - Fl , l<g-, ?ciiutant .. -- ilbr-iMscfl Emission Factor Source (Volume -.. -. -.-i Loaded) PM10 C'/ /' P512,5 :L - _ w isOtt �„ C sox £ -r-'fC, o � _ u ay.,i is NOx rtS.< 0 ,-)_ c4 i. - � CO ;ktqa ass`�,_.„ t";fix.,a Assist.Gas Combustion Uncontrolled Uncontrolled Pollutant (Ib/RlPRBtu) (Ibis/Mss:1 Emission Factor Source (Volume busted) Loaded) PMt,: f gyr PM2.0 SOx - NC,: Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled - - (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month)PM10 0.04 0.00 0.00 0.04 0.04 6 PM2.5 0.04 0.00 0.00 0.04 0.04 6 sox 0.00 0.00 0.00 0.00 0.00 1 NOx 0.35 0.00 0.00 0.35 0.35 59 VOC 203.09 0.00 0.00 203.09 10.15 1725 CO 1.59 0.00 0.00 1.59 1.59 270 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year) , Benzene 5398 0 0 5398 270 Toluene 14959 0 0 14959 748 Ethylbenzene 1115 0 0 1115 56 Xylene 11308 0 0 11308 565 n-Hexane 29046 0 0 29046 1452 224 TMP 22 0 0 22 1 38 of 65 K:\PA\2018\18WE0465.CP1.xlsm Hydrocarbon Loadout Emissions Inventory Section 06-Regulatory Summary Analysis Regulation 3,Parts A,B Source requires a permit RACT-Regulation 3,Part B,Section III.D.2.a The loadout must operate with submerged fill and loadout emissions must be routed to flare to satisfy RACT. (See regulatory applicability worksheet for detailed analysis) Section 07-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 08-Technical Analysis Notes *Please refer to Section So of the analysts tab for condensate storage tanos(point 010 and 01')for calculation methods for gas rolu ce..om busted and HHV of the vapors. 'Loadoutbytn ck is supplemented by-pipeline hua dour Loadout by tank scucks Is only used during ploeline outages or sues As such,only ati annual Brit wilt be placed on loadout volume 6hjstfcmb`ofNOxand3COfrom,carOustion DO NOT include emissions from combustion of pilot fuel and assist gas(referred to collectively as"fuel gas"m this discussion).Fite I gas emissions are acounted forwrth the emlcoicns reported ao Pnint 03.011 Nlt5-1).This was none to avoid confusion in allocating emissions based on e lative gas coin bused from the various emission points routing emission to the EC3(Point:010,Point 0r 1,& Point SI2(._€uel gas emissionS,are bas d on a heat value of 1,450 btu/sc;and 1,200 scf/hr#lowrate of assisttgas. Section 09-Inventory SCC Coding and Emissions Factors Uncontrolled Emissions AIRS Point# Process# SCC Code Pollutant Factor Control% Units 012 01 - 4-06-001-32 Crude Oil:Submerged Loading Normal Service(S=0.6) PM10 0.00 0 . lb/1,000 gallons transferred PM2.5 0.00 0 lb/1,000 gallons transferred 500 0.00 0 lb/1,000 gallons transferred NO0 0.01 0 lb/1,000 gallons transferred VOC 4.8 95 lb/1,000 gallons transferred CO 0.04 0 lb/1,000 gallons transferred Benzene 0.06 95 lb/1,000 gallons transferred Toluene 0.18 95 lb/1,000 gallons transferred Ethylbenzene 0.01 95 lb/1,000 gallons transferred Xylene 0.13 95 lb/1,000 gallons transferred n-Hexane 0.34 95 lb/1,000 gallons transferred 224 TMP 0.00- 95 lb/1,000 gallons transferred 39 of 65 K:\PA\2018\18WE0465.CP1xlsm Hydrocarbon Loadoot Regulatory Analysis Worksheet mbcoda Rory ct n Ircrlo pod B.nor oeed Nee.ttanmrd Permit Pero eeulromann L uncontrolled criteria (g.WAbIndiNdgulmumgeeamdnnzmY.1.Ifl non 3,Part 0.Sectlm nn.i.ali th Imm3. Is eIaced et an explora de Icedcur oundah on old 1productions.is10,00leg.ns(S8 Sfl s)°,mn3,Pap&day ricuon n,.,.lit folding lm don 10,003 gallons year of mole per lash MO ammlauvaee west 4. Is de Icculcut on l®dhg lm than 6,750 bbb per year ro fvadenv m via splash MO operation iwd'eg tees dvni63®tan per year aftatlemao wav8rcrged OP procedure? eater. s tml Pre umool W lCembsurs gm m,easnansNOe greeter w m enigvmemisla vmxrwn n00 WV lPewladm &se 3.Part <omllD3iT ITauod that source n int.Nondaonmone area low' 'ird¢m NONAITAP MBNT mantra.emissions ham any sited+pollutants from Ebb Ind rdduel mate Bream Nan 1TPT land..SiPart P,Se<tlm If.0.vali 1.Arem Ye 0,0..m 2.it thooadeutiotezed Dian eualorialonra lemnmc IO.C Ian.gSCOM(pedl(Peg m .c.gi 'r+o. G010,0.. w,6 3. Is Ore load°.opera Hon loading ors lr3 ...de annual a.v.ae hadsi 4. Is the mdmtapuauon m®iglm dvn 6,]5�o bb s per Ymeol<ontlen¢tad splash MR am 5. Is the oadwt operatlon loadinglm than 16300 bb sper year of condensate Na submerged fill procedure, 6.Net uncontrolled m tors from ore greater then 2 iPT.Num greater Ulan 5 WV or membslons greater dun 51PY(Reguladm 3.Part B.5ectonI10.21i Y_:Cr!Irawdoo requires cove. 7.PACT I5ou toy I...on3 Pert B.5eNon 02.a), yes.OUOI " Ina oadout most operate wd submerged fill orra loadoutcmusb mustbrrornedtothistoaaehryMR. loadou mot operator,.wtnugeiil and l auanbawumu¢temnvnocomato satisfy 000?.Hror ccotrogroi,a PAR analysis Is rear.cod aoade doussn0 xsacna,a. Disclaimer Tlrs tlocunmt assists operators wM meminrg epp'Icasility a cent.g✓reneRO*PM Clean Air Act ib implemedrg g✓etions,and Air 0ualiry Corud CanmSvm regulations.iha tlorwnenlisrlot a Necr rej✓Prim,and teaelyssu1artars may rut apply Na parhaaa station based Won Me/adv..I'ac baldarcunslannos.Th14eccume tlasrIX chageo.subsPMa/or anyFew.gWa6-on a my other lega'ryd7.5,0 regwrernenl i4 ru legally enforceable.Ineleeantdanyc7Mkrbelwem delarguayedthisdamnerteel No language dmz Cl®n.Nr Act..its implemmtlrg g✓alias. aMNr, Orally ContNCommissimmguhttans.tie language a.aahtea regulation will control.TT use&non-mamPtoy language sbchas'raanmend.—may:'shwkl'alH'can'is irfmildb tlescri0',PLO inferpre&Xxss as:recanmer 611ws.Alanmby fermimllpysuch as'mssr end'IIOllw,are i3ea4aito WscnbeOO NrO7lrg requirenerm tor&126 termsa&Ae Clean AIrMa,d Orally Control Commission gWarivas,',Le.document does not establish legally binding requirements in aM1RSM Hydrocarbon Loadout Emissions Inventory Section 01-Administrative Information 'Facility AIRS ID: 123. 9FBB ,, 013. County Plant Pont Section 02-Equipment Description Details Ugfoa'sd`irtg f d t frontp sb di ktuck t p zed d sate teeritanks.load a:vapor balance oaurs vi Detailed Emissions Unit Description: r„eelp*Pesare only r leasedlo the atmosphere Nuringhose disconnect. Emission Control Device Descr t Emhslons3fi'rn�tLggpdurce are not controlled 41 Is this loadout controlled? ke0A1/44 Requested Overall VOC&HAP Control Efficiency%: 0.00 Section 03-Procession Rate Information for Emissions Estimates Primary Emissions-Hydrocarbon Loadout Truck Loadout Capacity 1 j� f7t 990 g II ns/load �. III gallons/month Cpndensate Unloaded - ------ �,.,1,460,0DD,o0 bbl/year Loadouts/month 730.00 loadout/month Loadouts/year 8,760.00 loadout/year 5 d ry E Cp b t D e(s) , v � MBTu Per Year J ._ MMBTU per year l d +�r`Jd f4 lfN i i ., +. _,,.,�,1.kP`.t 1,ui.l.,?, of<l. ^ G ,-s ,,i MMBTU per year Section 04-Emissions Factors&Methodologies Loadout Hose Parameters Liquid Hose Diameter 0-25 f t Vapor Hose 0 ameter8,8 0'25 feet N t Liquid'Hose Length` "s'feet `Length accounts forlength of slat on valve on pressunzed hose. Vapor Hose Lenih` 3 7, ,,,, 1-'feet There are two hoses connected to each truck during loadout, 1 Liquid Hose Volume 0.0491 cubic feet `......._........_.......... ....._.._..._....__........_........_.._.........__..._..............._.._.......i Vapor Hose Volume 0.0491 cubic feet T k ndT ckP T k d t k P role 3 9T psig • 109.2 Hole PV,RT Where: P=pressure in hose at time of disconnect=storage tank pressure(psis) V=volume of hoses(cubic feet) = umber of Ib-moles of product in hoses R=Universal gas constant=10.73 ftx3`psi/Ibmole/degR T=average loadout temperature=60°F=519.67R • - -. -. Vapor Density - liquid Density - n - 0.000961314 lbmol SG 3306132f22A$ Density of n/V 0.019583724 Ibmol/fM3 Water ;,$30 lb/gallon MW it _ :/f Ib/Ibmol liquid Density 5.14171123 lb/gallon Vapor Density 0.861304733 Ib/ft^3 38,46 Ib/f a3 Notes: 1,All liquid lines contain liquid products et Individual specific gravity. 2,All vapor return lines contain products that behave as ideal gases at 60"F and storage tank pressure, Uncontrolled VOC Emissions: Vapor Emissions 370.37 lb/year 30.86 lb/month 0,19 tpy 0.703990902 total tons per month liquid Emissions 16,525.42 lb/year 1,377.12 lb/month 8.26 tpy Total Emitu:nns 0.45 ny DCP requested Total 8.45 tpy • Comp000nt Mass Fraction ., F_=p= n t0 So ny (Sor>_c,,nn: Benzene 0.065% 10 for':,,v I Toluene 0953%»i7 CS for noes) Repie.n[at 2 Serial (S..e Sect,an Ethylbenzene 005094r as o,it+rsl Recrc n a:nipl $Pn>nc,on: Xylene 0.301°5 208 for lotus) n-Hexane 0.375% OS for note-j Representative Sucvpi (5 5 M 224TMP 3.3049 r..,,v.,?'.+0a for 41 of 65 - K:\PA\2018\18WE0465.CP1.xlsm • • Hydrocarbon Loadout Emissions Inventory EMMEMEN Hydrocarbon Loadout Uncontrolled Controlled (Ib/loadoet Emission Factor Source Pollutant (nb/loadeut event) event) (Volume (Volume Loaded) Loaded) MMIIIITINEZEINNIIII 9.64E-04 ®" .x anon a₹7cAftE - . �m y. {5 r-. ' ArratYsrs ' ' Control Device Uncontrolled Uncontrolled Pollutant )Ib/MMBtu) )lb/bbl) Emission Factor Source (Volume (waste heat combusted) Loaded) IIIIIIIIIM lira ..a`t✓ 000E+00 intf) i�x2 r-` 000E+00 ty ! l / ' z - , 000E+00 v:/1.71. a::; �i,« /` 0.006100 :2, > `fJ 0.00E+00 "&%�'lLO.:..Allatitiellitailill. Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled gore/year) (tans/year) Irons/year) (tens/veer) (torn/year) PM10 0.00 0.00 0.00 0.00 0.00 PM2.5 0.00 0.00 0.00 0.00 0.00 SOx 0.00 0.00 0.00 0.00 0.00 Nov 0.00 0.00 0.00 0.00 0.00 VOC 8.45 8.45 8.45 5.45 8.45 CO 0.00 0.00 0.00 0.00 0.00 Potential to Emit Actual Emissions Requested Permit Units Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Its/year) (Ibs/year) (ibs/year) (lbs/year) (Ibs/year) Benzene 160.09 153.04 163.09 163 163 Toluene . 160.95 160.95 160.95 161 161 Ethylbenzene 8.45 8.45 8.45 8 8 Xylene 50.92 50.92 50.92 51 51 n-Hexane 1364.37 1364.37 1364.37 1364 1364 224 TMP 51.30 51.30 51.30 51 51 Section 06-Regulatory Summary Analysis Regulation 3,Parts A,B Source requires a permit RACE-Regulation 3,Part B,Section 111.1.2.0 The loadout operation must satisfy RACY. (Sae regulatory applicability worksheet for detailed analysis) Section 07-Initial and Periodic Sampling and Testing Requirements You have indicated above the source is not controlled.The following question does not require an answer. ,' / 'l 0f // ,' .E/F $'7"e ti m //' 3 /'.mil' '- i ii z i Section 08 Technical Analysis Notes .,,, '*n`9P`" :--",___...-..,.- *the 3v den tethatwilf betnack d nandu I do't#H"dagiBty+u,l 3k*nespre-ss' dstorage.tanksat5eld boettei P fl rrt-Tlni Cende satef}3cohtlied.- 41734 3 densetn ptaducedeTthrsfanNrignpsteeaen fthe stahlliierandis•R sheda d:stqbilizedbeFaredischargetastocagyt0y/ 11/l'.y 1 I NT 3j111,l 1l) 1'sy3ir 3 t Ba ed. ffi forma₹tonpravrr�ed 1ptba eppi sat �' ISiI sa ly occur from apinsun ad•lbarloGFaperaOo h th hostsusadt t sferfluldsare d}wonnected and mrpd5edta the atmoEp{i t adnut accu ff ma pressurxedle kt kvesseita a pressurlie8sm ge s o I[c d n tef dtardrsl peratmgatthe seine presswe. .r 311- )19L/ 33) 3 ' Appluoan'•fndicatedtbdddilaw0sg',DG$hes vaorkprue*,--op:f.004Y7wtmrrumefvopaYsarerefeosedc000u etmrsosphe d gthep kemcrdir(&4blltidco d)mee0 unJoadm9 pro MEiI.IgdiefOnneclM enor'e ;- mm in;)redbyzapt0elaphgr�r,srytitpp�between the fsotut1aii:404 lylh 'o3sapnd'yryck rhpcuirm *sestets pWredilr an©P-rf toppgrfabfacoutofaeY'bgr'0 clidxverandEoRsj4mred tatho uA0 Net-SuunpicNrerweryor_- ₹hohosemoybedroctmvnn dedao o sump to Ilvos the pr4efiiebmm.esal%ared211 jl1y 33 3 3 "` - rr .. 13 l - is 3I.1111J131d1113(IP(3(1 oum - -. 1 11 YTb ppl cantsubmr[teda Praha �. I t nthacmode}s the rapre entativeSrreesurt3redd�q 3u3)13e3anmpx rd n[@"�DDps aftaa separatianve set tae_osphedcpressute jY22ps a)T♦l nal}� re $r€nz totalfla hlos atII.14' ilb3 P rP }b fcondens"atok d d.._Y14%vaporrzat onon--- es bas 35Then:farex[aa 6s/ehli i,ao61111�%nf0h liquid erPdiedt the t osphereintlr po'phaev s u6ve ssumptkn DCP halt ngmeftpl9aprue4- reduc₹on ,_cap( k q0 yq - """, k a {ns ion eak�t n that aQ:oumed fo'rtfiis memtsst nsbasedapm�nut lry.' dtl �hefi ir�h wev r3her"ld� rir n nest ns ppsedbytLreiAylsl n gard ngflasht pip mtureandwar fossEs yt' ��;� �qulds'.ar t ns{ red apdstnred prlorto pumping hack mt pE3 eess,N[fille develapingresponsestoY}iesequestf ns;the app(tabir'det;:.r toed that ihlerew re s�eu raiareas&r whtctxtheaxigi_srat psaposal was'gceatiy 3 3I1 y,i1 phyrastlmatutgX queste prase5sngi}�rrgiputr t 5 fa,ikiiodt9o26lNsed Appl"a tpovdedeem Il"le5po eon R/2E[isdet0iilti5gfhe'sea5signptltmslsod CEvi;Gd,Rh h)C)abcr)eq)h 16U&h0hOEem)ssibnuua estimated ur(u;gthe hr tyafthe rysco(ieftlnthcll ...aft disco ect-4* l,the loading rack is emitted to the atmosphere RS indbatedabove thlsprovidoe a consarva₹rve esturrate an Butt+d'tanmi edthat ,forth ly is - wasreq Iced 1a `f�151/"0 3 .ze ' .'., 19'. t 1II art3 +The r cul rw gh₹afihego a3 natty bfihe iqud and m ass I tines of HAPs used to t t th HAP' nsvre bt edfem uresentat esampenf"unsatoi ed' ders tea atenfE 3DGP b^�csonus/P€ostun -_ 13)5/14 While the samplafsnoCsiteepeafi and more than one year old,it was Aetermined n}ntal Comp)' test requ ing as1e-spec{icsamplebenbta ed wasnattequired0D 0(ES Cpd satE"hEhtgtruciced teed))flan€ 3, .. �- - n))�1)33 113� ya!)'mgcomFOSr₹on andGOmpa5itlan tSti4texpected Cowry significantly from the rResantdt yesginpl�l ddt DCP those rvdCNelyrepPrtlngVfaCfromthissoulGeba5ad pn�fre3S,f�trr!pfArillS fete₹anr�ilit}saa��ments--_ jibo eR qu ring an moat sitespecflcsample he obtained andused to estimate fomthis sdur< ould th g tho.ntimpactoothe'p for missions tEdiA: Rwarrant--8:77da)i}ss'tQne 3 31 I t" � a 111', f 'This dsa new t t ce after 11/21/07#locatedintheed ne -omaismen{arm sn 3(1Ill400ur s subJgtton RACE.Eased¢rtinform t'r np?uvidedli I dout peranon33iie sfets Ruldhum pressurized' i storynsovve₹sto pr dt ktrucks As the leadouteperatlanisepitdctedthevap eid)9plpcet4ylor�rtfh 3plesdunliedtrucks"is routed backtatheipressuEigedstoregev Is As3Tesul€e')srls@@nsanlydccur when Mielltjuld andvapAlfpsusafcEd0,4)94ttudmRettF,.° tlonoo ofsheluadouka1feata�,j 1 hllcEflh nfirf110)ip oeacwter3s s uing"vapor#talanccWtthpcou00rlzed3veie)S""-Ni-10 meta dyfWt r4I9ol1 eI5fle R551 _ 3011 i 4 X5,,1113 3113331 1OPiPA �:,, AACC.Regurab n75e/U'n'1Jhnrh' tec tibpersonsha cli,- eafvalatikprganiq mp ds yti�po 3o4spi�ge nolassEACT}s utigz d Emissi nsth tresgltfrore be hose dis onnect dbyth ssonrP rot j 3m>h,,a' q 3313333 3 11 f�, 'ate less tiwaZD ipyV{5C, i p hag usad 2l#tpyasasgtafftorr Burn gturth 3LRC�; � �pad'ougpaintsata I$rtacllr#res ThrereEwe,pdfurtherERL1'ap lysrsl cessaryfarfhi5P Irt/ 3 .13>p3 3 3�" M - .: 3 1 3 1 3 a t:E - 1 3 1'133 3"11 1 (h// 1 m� _ - 1I3 3 a • • 1 p,"x;r3JY, 31(1 3 311 s:�>£ �fl,f ., ,;,, (1 t��: 133311331 0,2',3r _...... ,oG:.kdireak ....... .,: ._". _8<.-„w", , ,,..,r t . _ ......• .. _ _, ,w .,,,,,/µ'+'ti , :ggi Section 09-Inventory SCC Coding and Emissions Factors Uncontrolled Emissions AIRS Point tf Process H SCC Code Pollutant Factor Control% Units sxoxsr ,fi 013 01 =466�I.42CrusfdO�Cp�f�a,NCg0w',,, ,,, � .��`f3r�,a�y,,,'�S41L"��'�,,, ' .-,_' '"-"--2. VOC 2.76E-01 0 lb/1,000 gallons transferred .., _ _a. _.. n-Hexane 2.22E-02 0 lb/1,000 gallons transferred 42 of 65 K:\PA\2018\18WE0465.CP1.xlsm • Hydrocarbon Loadout Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B-APEN and Permit Re.uirements !Source i5 in the Non-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 11.5.1.0)? �� 2. Is the loadout located at an exploration and production site(e.g.,well pad)(Regulation 3,Part B,Section 11.8.1.1)? f(.. 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)? ;Not enough information! • NON-ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY(Regulation 3;Part A,Section Hata)? Fes ic'L'go to next question. 2. Is the loadout located at an exploration and production site(e.g.,well pad)(Regulation 3,Part B,Section II.D.1.1)? r q k Go to question 6 3. Is the loadout operation loading less than 10,000 gallons(238 BBLs)of crude oil per day on an annual average basis? VAT:' 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? NA,l'.;?. 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 144'7 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)? Yps .,ti The loadout requires a permit 'Source requires a permit 7. RACr-Are uncontrolled VOC emissions from the loadout operation greater than 20 tpy(Regulation 3,Part B,Section III.D.2.a(0 Pia , The loadout operation must satisfy RAG!''The loadout operation snout satisfy RACE. 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.la 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"am 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. Flare Emissions Inventory Section al-Administrative Information Facility AIRs ID: 123 9PBBa 014 County Plant Point Section 02-Equipment Description Details One(i)or4n flare Wake' Ma&e TBD M'od$f 3TBD St�001(0-0F,TBDj usec�£Lo.pritro"epuss�aresfor b(oivc�owrr�pd mamtepance purpgse5 - This open flare controls em as�ons from 84 rtts1}and Ofi-(t 05(du rtgva77p�or reWvery'utr'�'l );downtame. f 1' Detailed Emissions Unit t • -11%44 3A 1y Descri tion: r >.. .. P ,,�.,.....� .- ,., 3 f:..., Emission Control DeviceS`eeabove= t, 111'1 . Description: - '3111.l(i,i ra,,, Requested Overall VOC&HAP Control • Efficiency%: q9$1 - _ Section 03-Processing Rate Informal sn for Emissions Estimates gr[gF a 0 MMatulftrrt « *Da-isi" + t a4�tx»j Volume of gas: .0.005 MMscf/day 195 scf/hr Volume of gas: "smk:wrj,� 003040.MMscf/day 1270 scf/hr Heat Content of gas: Btu/scf Heat Content of gas .. , ,,,,,,, 1098,Btu/scf Requested volume of Requested volume of gas: 1.7082 MMsd/year gas: 11.13 MMscfJyear Actual volume of gas: 0 MMscf/year Actual volume of gas: 0 MMscfJyear PTE volume of gas: 1.7082 MMsd/year PTE volume of gas: 11.13 MMscf/Year Requested heat Requested heat content of gas: 1793.61 MMBtu/year 0.20475 MMBtu/hr content of gas: 12,215 MMBtu/year _ s as bmpt tr,, - do+ans toy (f ttek&as fsr stfr`il Volumeofgas. ,( '0.tp.27a9-171CMMscf/day 509.1324201 scf/hr Volume of gas: y O.g5DZ9r1SZ1 MMscf/day 2116.438356 scf/hr Heat Content of gas: 1 = Btu scf Heat Content of gas "i,� , 1303:Btu scf Requested volume of Requested volume of gas: 4.46 MMsd/year gas: 18.54 MMscf/year Actual volume of gas: 0.00 MMscf/year Actual volume of gas: 0 MMsd/year PTE volume of gas: 4.46 MMscf/year PTE volume of gas: 18.54 MMsd/year Requested heat content of Requested heat gas: 4897.08 MMBtu/year content of gas: 24157.62 MMBtu/year s;� Refrigerant System Slowdown.(Propane); Volumeofgas: h ,0008219178.MMscf/day 342.4657534 scf/hr Heat Content of gas: 2516`;Btu/scf Requested volume of gas: 3.00 MMscf/year Actual volume of gas: 0.00 MMscf/year PTE volume of gas: 3.00 MMscf/year Requested heat content of gas: 7548 MMBtu/year Total Throughput: Total Requested Throughput to Flare (Permit Limit) 37.13 MMscf/year Actual throughput 0 MMscf/year PTE Throughput 37.13 MMscf/year Requested Purge Gas: 11.13 MMscf/yr Requested Waste Gas: 26.00 MMscf/yr Purge Gas HHV: 1098.00 Btu/sc.( Avg Waste Gas HHV: 1407.796154 Btu/scf 44 of 65 K:\PA\2018\18W E0465.CP1.xlsm Flare Emissions Inventory Y nd fiAP4rmit'i"',ptari eascontbusifon{ltesidue,C1. itusltton) l ..,cFO „T.p.a`n rgflrn lninr c,41 inbusY3o ' Throughput(Q) 11.13 MMscf/yr 1270 scf/hr Throughput(Q) 18 541 MMscf/yr 2116.4384 scf/hr MW 3 ,. 15,3 Ib/Ib-mcl 0.03048 MMsef/d MW ,ii2�3.8 Ib/ib-mol 0.0507945 MMscf/d Buffer: 10% mass fraction Ib/hr lb/yr tpy mass fraction lb/hr lb/yr tpy Helium - 0,.000E+00 0.00 0.00 0.00 Helium 0.000E+00 0.00 0.00 0.00 CO2 .3.195E-02 1.95 17114.09 8.56 CO2 4.500E-02 5.77 50564.20 25.28 N2 .183960E-03 0.55 4799.45 2.40 N2 ;,51851E-03 0.75 6574.47 3.29 methane ,_'.7:496601! 45.83 401508.93 200.75 methane lr 4.932E-01 63.26 554138.64 277.07 ethane 1.790E-01'. 10.95 95892.48 47.95 ethane '1.812E-01: 23.24 203563.59 101.78 propane ¢ 2_8025=02 1.71 15007.01 7.50 propane 1.510E-01: 19.37 169705.80 84.85 , isobutane 8:8008-04 0.05 460.66 0.23 isobutane -3.310E-02: 2.96 25950.67 12.98 n-butane 16210E-03 0.07 648.14 0.32 n-butane 6.401E-02. 8.21 71924.76 35.96 isopentane '5.000E-05 0.00 26.78 0.01 isopentane 1-422E-02 1.82 15981.66 7.99 n-pentane 3.0100.05 0.00 16,07 0.01 n-pentane :-1.459E-02 1.87 16397.41 8.20 cyclopentane 0.000E+00 0.00 0.00 0.00 cyclopentane 0.000E+00 0.00 0.00 0.00 n-Hexane 0.000E+00 0.00 0.00 0.00 n-Hexane 6,147E-03 0.79 6907.09 3.45 cyclohexane -0.000E+00 0.00 0.00 OAO cyclohexane '=%0.000E+00 0.00 0.00 0.00 Other hexanes 0.000E+00 0.00 0.00 0.00 Other hexanes "0,000E+00 0.00 0.00 0.00 heptanes :0.0005+00 0.00 0.00 0.00 heptanes 1.059E-03! 0.14 1189.94 0.59 methylcyclohexane _ 0..000E+00 0.00 0.00 0.00 methylcyclohexane ff f,0.000E+00 0.00 0.00 0.00 224-TMP 0.000E+00 0.00 0.00 0.00 224-TMP 9.942E-06 0,00 11.17 0.01 Benzene I 9.000E+00 0.00 0.00 0.00 Benzene " 2-652E-04 0.03 297,97 0,15 Toluene I 5.000E+00 0.00 0.00 0.00 Toluene f'1,283E-04 0.02 144.16 0.07 Ethylbenzene t 01000E+00 0.00 0.00 0.00 Ethylbenzene ;-0.000E+00 0.00 0.00 0.00 Xylenes 0.000E+00 0.00 0.00 0.00 Xylenes *.. '::3.236E-05! 0.00 36.37 0.02 C8+Heavies b.000E+00 0.00 0,00 0,00 08+Heavies PI , 2.180E-04 0.03 244,96 0.12 VOC mass fraction: 3.02% Total VOC(Uncontrolled) 8.08 VOC mass fraction: 27.48% Total VOC(Uncontrolled) 154.40 Total VOC(Uncontrolled w/10./0 Buffer for conservatism) 169.84 #-..,-;-_-::,,,r , y,,YOCxand`HAAzftorllR`esTttuaiG05g. H•, ly :„,4,,: ,. .. VOC from Refrigerant Gas Venting(Propane) Throughput(Q) 4.460E+00 MMscf/yr 509.1324201 scf/hr Throughput(Q) I 3.00 MMscf/yr 342.46575 scf/hr MW 10.3 Ib0b-mol 0.012219178 MMscf/d MW I r 44-0 Ib4b-mot 0.0082192 MMscf/d mass fraction lb/hr lb/yr tpy mass fraction lb/hr lb/yr tpy Propane 1.000E+00 39.701 347771.81 173.89 Helium f 0.000E+00 0.00 0.00 0.00 VOC mass fraction; 100% Total VOC(Uncontrolled) 173.89 _._._.._.__.._ CO2 .',31599 5E-02 0.78 6860.90 3.43 N2 8.960E-03 0.22 1924.06 0.96 methane 7.496E-01 18.37 160961.58 80.48 ethane 1.700E-01 4.39 38442.50 19.22 propane .2802E-02 0.69 6016.19 3.01 isobutane I' 8.600E-04 0.02 184.68 0.09 n-butane 1.210E-03 0.03 259.83 0.13 isopentane -5.000E-05 0.00 10.74 0.01 n-pentane I 3.000E-05 0.00 6.44 0.00 cyclopentane 0.000E+00 0.00 0.00 0.00 n-Hexane 0.000E+00 0.00 0,00 0.00 cyclohexane 0.000E+00 0,00 0.00 0.00 Other hexanes 0.000E+00 0.00 0.00 0.00 heptanes -S;::0.000E+00 0,00 0.00 0.00 methylcyclohexane 09000E+00 0.00 0.00 0.00 224-TMP 0.000E+00 0.00 0.00 0.00 Benzene 0.000E+00 0.00 0.00 0.00 Toluene 0.000E+00 0.00 0.00 0,00 Ethylbenzene 0.000E+00 0.00 0,00 0.00 Xylenes 0.000E+00 0,00 0.00 0.00 C8+Heavies 0.000E+00 0.00 0.00 0.00 VOC mass fraction: 3.02% Total VOC(Uncontrolled) 3,24 Section 04-Emissions Factors&Methodologies Pilot Gas: ' Control Device Uncontrolled Uncontrolled E.F. E.F.(Ibs/MMsef Pollutant (Ibs/MMBtu waste gas Emissions Factor Source Citation waste heat volume combusted) combusted) PM10 ,._�i `` 7,6000 y)ti�__^'a + 4 PM2,5 7,6000 iiiii'i €4- s� sn NOx , 100,0080 tA'P bfa€.4-T a 41, 4-kti VOC ..5.5000 - 14p e 1.0.»2 - CO cs c -:84.0000 , A,Oka kV A-. ' SO2 ti 0.6000 fitti fa€A r,- \A i n-Hexane Ivy' .. ',., 1,8000 .,.0 ,a�„421'>`Fdbie.Y.44 45 of 65 - K:\PA\2018\18WE0465.CP1xlsm Flare Emissions Inventory Weighted Emission Factors for Waste Gas(17%residue blowdown,r71%.inlet gas blowdown,12%refrigerant blowdawn) Emission Factors Plant Flare Uncontrolled Controlled (lb/MMscf) (Ib/MMscf) Emission Factor Source Pollutant (Gas' (Gas Throughput) Throughput) VOC 26689263 . 1334.463 Ya Benzene 11.461 0.573 441', EP _ - - H4,•{lute Toluene 5.544 0.277 40'144P Ethylbenzene 0.000 0.000 fsst Xylene 1.399 0.070 mY" n-Hexane 265.657 13.283 r ottlnve 4) A, ,s'- 0.0 rite 224TMP 0.430 21 A , rHregtor3f'. , -i.� _„ , -`- Emission Factors for Purge Gas(Residue.gas Composition). Emission Factors Plant Flare Uncontrolled Controlled (Ib/MMscf) (lb/MMscf) Emission Factor Source Pollutant (Gas (Gas Throughput) Throughput) VOC 1452.438 72.622 A.I`m [fi(i�ttrblga Benzene 0.000 0.000 si ` prmva 3 Eo71 Toluene 0.000 0.000 , rsstht q JCt root ti,,, Ethylbenzene 0.000 0.000 E2A. **.-,X tueA„ ie5t%foturtte Xylene 0.000 0.000 EPA sfoRe , t 1Yt}lu n-Hexane 0.000 0.000 EPA£ ltnr2 meat n , nte .r urste 224 TMP 0000 0.000 EPA Efiel5t0tt'4lW6nt4 „meet Pablr tune, W- ill TT Z .�.CA,nt nfDevica(combustiotr of W, as) I , .,!.i._. Uncontrolled Uncontrolled E.F. E.F.(lbs/MMscf Pollutant Emissions Factor Source Citation (Ibs/MMBtu waste gas waste heat volume combusted) combusted) I l l - i t .1.2,1'.0 0.C8Illip (42Chaptera.3*i,ndt6frlal�u0x/C0) a Ws CO �y/�t ,t 436.417 --m,,,, ,; Slndiistrra)0 m4)f4C0 502 �i%lf'"r ,� 0.600 t v4 'rabtn _. �i; F AM'. €a. Ac,v,' ,.c, o OevEtm Icenrbustiorsof Purge Gas} ,,, Uncontrolled Pollutant Uncontrolled E.F. E.F.(Ibs/MMscf Emissions Factor Source Citation (Ibs/MMBtu waste gas waste heat volume combusted) combusted) .P � / f • AP 72,Chapier13S indusbial fkxesli+lOttj£O) ';s Er:Ag CO �� 0.310 340.380 J# 2cb0 tet1:3i5'Ifidusinial '.Old/£0) y-` -` PPI 502 „f, ;:rk. 0.600 !S 42 Table'1.4-Z dam::. ,r/,,,,, Section 05-Emissions Inventory Potential to Emit Requested Permit Limits ;dual Emis;icns Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) PM10 0.01 0.01 0.01 0.00 . 0.00 PM2.5 0.01 0.01 0.01 0.00 0.00 NOx 0.09 0.09 0.09 0.00 0.00 VOC 0.00 0.00 0.00 0.00 0.00 CO 0.07 0.07 0.07 0.00 0.00 502 0.00 0.00 0.00 0.00 0.00 n-Hexane 0.00 . 0.00 0.00 0.00 0.00 Waste Gas -- - Potential to Emit Requested Permit Limits utuel Emissions Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Control], (tons/year) (tons/year) (tons/year) (tons/pearl (tons/year' PM10 0-U0 0.00 0.00 ' PM2.5 0.00 0.00 0.00 NOx 1.24 1.24 1.24 VOC 346.96 346.96 17.35 CO 5.67 5.67 5.67 SO2 0.01 0.01 0.01 Potential to Emit Requested Permit Limits Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontreilec'" Controlled Uncontrolled Controlled (tons/year) (tons/year)- (tons/year) (tons/veer) (tons/year) (Ibs/year) (Ibs/year) Benzene 0.15 0.15 0.01 298 15 Toluene 0.07 0.07 0.00 144 7 Ethylbenzene 0.00 0.00 0.00 0 0 Xylene 0.02 0.02 0.00 36 2 n-Hexane 3.45 3.45 0.17 6907 345 224 TMP 0.01. 0.01 0.00 11 1 46 of 65 K:\PA\2018\18WE0465.CP1xlsm Flare Emissions Inventory _ Purge Gas - , Potential to Emit Requested Permit Limits Actual Emissions Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tans/year) (tons,/year) PM10 0.00 0.00 0.00 0.00 PM2.5 0.00 0.00 0.00_ 0.00 NOx 0.42 0.42 0.00 0.00 VOC - 8.08 0.40 0.00 0.00 CO 1.89 1.89 0.00 0.00 502 0.00 • 0.00 0.00 0.00 Potential to Emit Requested Permit Limits Aauai Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (eons/year) (Ibs/year) (lbs/year) Benzene 0.00 0.00 0.00 0.00 0 0 Toluene 0.00 0.00 0.00 0.00 0 0 ., Ethylbenzene 0.00 0.00 0.00 0.00 0 0 Xylene 0.00 0.00 0.00 0.00 0 0 n-Hexane 0.00 0.00 0.00 0.00 0 0 224 TMP 0.00 0.00 0.00 0.00 0 0 -- Total Emissions(Pllot+Purge+Waste.Gas) Potential to Emit Requested Permit Limits Actual Emissions Criteria Pollutants Uncontrolled Uncontrolled Controlled ..n,rantrolied Controlled (tans/year) (tons/year) (tons/year) (tons/year) (tons/year] PM10 0.01 0.01 0.01 0.00 0.00 PM2.5 0.01 0.01 0.01 0.00 0.00 NOx 1.47 1.75 1.75 0.00 0.00 VOC 26.97 355.04 17.76 .0.00 0.00 CO 6.39 7.64 7.64 0.00 0,00 502 0.01 0.01 0.01 0.00 0.00 Potential to Emit Requested Permit Limits Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled - Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons/Year) (tons/year) (lbs/year) (lbs/year) Benzene 0.15 0.15 0.01 0.00 0.00 298 15 Toluene 0.07 0.07 0.00 0.00 0.00 144 7 Ethylbenzene 0.00 0.00 0.00 0.00 0.00 0 0 Xylene 0.02 0.02 0.00 0.00 0.00 36 2 n-Hexane 3.45 3.45 0.17 0.00 0.00 6907 345 224 TMP 0.01 0.01 0.00 0.00 0.00 11 1 Section 06-Regulatory Summary Analysis Section IIA.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 Regulation 1 Duly,1992))in all subsections of Section IL A and B of this regulation. Section II.A.5-Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2 Section lA-No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to resuh in detectable odors which are measured in excess of the following limits:For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air. Part A-APEN Requirements Criteria Pollutants:For criteria pollutants,Air Pollutant Emission Notices are required for:each individual emission point in a non-attainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant(pollutants are not summed)for which the area is non-attainment. Regulation 3 Applicant is required to file an-APEN since emissions exceed 1 ton per year VOC ' Part B—Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 WY threshold(Reg.3,Part B, Section II.D.2.a) Regulation 6,Part A,NSPS Subpart Kb applies to the storage tanks points 010 and 011 at this facility.Since this flare will be used to control these tanks in the event of primary Subpart Kb control device downtime,it is subject to the requirements contained in 60.112b(a)(3)and shall meet the requirements of 60.18 of the General Provisions. Section XVII.B.2:Since this open flare is used as a backup to control emissions from the storage tanks and TEG dehydrators subject to controls , under Section XVII at this facility,it is subject to this section of Regulation 7.This portion of the regulation states:"If a combustion device is used to control emissions of VOCs and other hydrocarbons,it shall be enclosed,have no visible emissions during normal operation,and be designed so Regulation 7 that an observer can,by means of visual observation from the outside of the enclosed combustion device,or by other means approved by the Division,determine whether it is operating properly." Since this flare is not enclosed per Regulation 7,it has been approved as an alternate control device per Regulation 7 Section XVII.8.2.e.The operator submitted the"Alternative Emissions Control Equipment Request Form"to support their request to permit this flare as alternative emissions control equipment for the glycol dehydrator during VRU downtime and for the storage tank during enclosed flare downtime. 47 of 65 K:\PA\2018\18WE0465-CP1.xlsm Flare Emissions Inventory Section 07-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 08-Technical Analysis Notes *Per applicant,the flow rate volumes of purge and waste gas are estimated based on metered data at similar DCP gas processing facilities. *The calculation of VOC and HAP emissions associated with the combustion of residue gas and purge gas s is based on a residue gas data from meter data at similar OCR facilities.The inlet gas composition is based on an extended gas analysis from the inlet gas at OCR's O'Connor facility(sampled 10/27/16)„ - • *Thrsflare is used primarily for blowdownsand vents during maintenance from various portions of the plant and at variousst ages of the process.Therefore,OOP has estimated emissions from combustion of waste gas by assumingthe average composition of the waste stream may be represented by a mixture of residue gas,plant inlet gas,and gas from the cryogenic process.Of these streams,OCR has assumed the volume to the flare is accurately represented by 17%resiclue,71%inlet gas,and 12%refrigerant system gas.In addition tothe waste streams,this point accounts for a portion of the volume routed to the flare as residue gas that is used for purge gas.Considering purge gas in addition to the waste streams calculated above,the total volume of gas routedto the fla re is represented by 12%residuegas,50%inletgas,8%refrigerant system gas and 30%purge gas,Residue gas is used as purgegas:. - - - - The assumptions presented here are being accepted since it is based on actual metered data at similar plants,At this time,I will not require initial sampling of the respective waste gas streams(inlet,residue and refrigerant gas)for the following reasons: - - (i)The VOC emissiogsat this facility are not a concern with regards to P5D Major source status at this time.Even if the VOC concentration did increase slightly,It would be unlikely to result in any additional requirements since the facility is not close to exceeding major NANSR thresholds for VOC.As such,the environmental impact of requiring an initial or annual sample is - -minimal iii)The operator is using a weighted average to determine the emission factors and VOC concentration in the notesto permit holder.As a result,the annual sampling requiremeetwould seed to be explicit on how this weighted average would be calculated going forward.At this time,it was determined that the complexityrequired to include this information in the condition did not mush in a significant environmental benefit.Furthermore,the weighted average used inthis analysis is an estimation only. -(iii)The VOC concerrtmtionsfor residue and inlet gas used in this analysis appear to be consistent with valuesused-at other gas processingfacilRies,As such,this leadsto the determinationthat the estimate is representative of what would be expected at afacilityofthis type. . *The operator did not calculate PMemissions associated with the combustion of waste gas.The operator asserted that since the flare is designed to be a smokeless combustion device,particulate matter is not expected to be generated fromthe combustion of dehydrator waste gas,residue gas,inletgas or purge gas routed to this device. In order to address this statement,the emission factor source£orcombustion emissions(NOx and CO),AP-42 Chapter 13.5,was reviewed This document expresses the"emissions from flaring may include carbon particles (soot),unburned hydrocarbons,CO and partially burned and altered hydrocarbons.Also emitted are nitrogen oxides(Nax)and,if sulfur containing material such as hydrogen sulfide or mercaptans is flared,sulfur dioxide (S02) Based on this statement,the document does not provide information with regardsto particulate matter,except with regards to soot.The document further providesthat a smoking flare directly results in soot formation when it states The tendency of a fuel to smoke or make soot is influenced by fuei characteristics and by the amount and distribution of oxygen in the combustion zone."This is further supported by footnote c'Uelowtable 13.5-1 which provides the following:"Soot in concentration values:nonsmoking flares,0 micrograms per liter(tgjt);.lightly smoking fiares,40 µgel;average smoking flares,177 µg/L;and heavily smoking flares,274 µg/L" At this time,there is not another source of data that quantifies PM10 or PM25 from industrial flares and therefore It will be assumed that the only source of particulate matterfrom a flare is soot from smoke as expressed in AP-42 Chapter 13.5. It should be noted that the O&M plan requires that daily checks be conducted to determine if the flare is smoking.If smoke is observed during the daily checkthe source is required to eltherconduct a method 22 or immediately shut in the equipment to investigate the cause of the smoke and conduct repairs as necessary.Based on this requirementforthe flare and the manufacturer design fortheflareto-be smokeless if operated properly,it can safely be assumed that the flare will operate withoutsmoke on a regular basis.Also,if smoke is observed,the operator will be required to assess the.problem and perform necessary maintenance to preventthe flare from smoking,As such,I am comfortable assuming a soot concentration of 0 micrograms per liter as provided in AP-42 Chapter 13.5 fornonsmoking flares. Based on the information discussed above,0 was determined that the operator's assertion that a smokeless flare would not be expected to have PM emissions was valid.However,If in the future better data is developed for estimating PM emissions from industrial flares it should be included in future analysis. "The operator expressed a flow meter will be installed to monitortotal volume of gas during standard operational process/nor mat operation of equipment{i.e.maintenance and biowdown gas)and purge gas.As a result, a condition will be included in the permit that requires the operatorto monitortotai volume usinga flaw meter and use the data to demonstrate compliance with the process limit in the permit.The operator also indicated the pilot fuel is constant and does not vary.As a result,there is no need for a separate dedicated meterto monit orpilotfuel.._. "This permit will not Include short term limits(I.e.monthly limits).This is due to the"backup"nature of this equipment with variable peaks of throughput(i.e.the throughput is not constant but rather occurs in pulses based on maintenance activities performed at the facility).It cannot be reasonable predicted how the annual throughput will be distributed on a monthly basis. *It was determined that this flare is subjectto Regulation 6 Part ASubpartA General provisions since it is subject to control the storage tanks in accordance with NSPS Kb. Section 09-Inventory SCC Coding and Emissions Factors Uncontrolled Emissions AIRS Point# Process# Fr, Code Pollutant Factor Control% Units 014 01 '3^'I U , Cu*ca.rt ' NOx 89.4173 0 lb/MMscf Burned VOC 19126.6173 95 lb/MMscf Burned CO 407.6377 0 lb/MMscf Burned Benzene 8.0262 95 lb/MMscf Burned Toluene 3.8829 95 lb/MMscf Burned Ethylbenzene 0.0000 95 lb/MMscf Burned Xylene 0.0796 95 lb/MMscf Burned n-Hexane 186.0486 95 lb/MMscf Burned � .. .. 02 p��S�� pjp� ay�y��. Isc,E' � s y� PM10 7.60 0 lb/MMscf Burned PM2.5 7.60 0 lb/MMscf Burned NOx 100.00 0 lb/MMscf Burned VOC 5.5 0 lb/MMscf Burned CO 84.00 0 lb/MMscf Burned 502 0.60 0 lb/MMscf Burned n-Hexane 1.80 0 lb/MMscf Burned *Process 01 represents waste gas combustion associated with purge gas,inlet gas and residue gas while process 02 represents pilot light combustion.The emissions factors represented in process 01 are based on a weighted average of inlet and residue gas. 48 of 65 K:\PA\2018\18WE0465.CP1.xlsm Flare Emissions Inventory Section 01-Adminstrative Information Facility Allis ID: - -- --- ty t Section 02-Equipment Description Details 4ne-¢1}open (Make hr2 Mode1-TBDt61+"`F�f'BD}�useda a ernf$sronsforlrlowdhwnfanfimar3ritenance purposes frti $0, TigRaeafohcontrols emisot n6from Porn€0022.0t durnsg vaporrg00er}tunrt/(R1Rtf}dowhttme. Detailed Emissions Unit s333 1 ngimcgog- ilben 9 113 - ,�v1�1I 13 313�1,r r � 1J313�� _ r1�•s11331F / = t� Emission Control Device 14:414404atillirillarI •IMEREMBERREMEmplimplONEDIEBBEEM Description: filliau _ 3 m. l ...� : Requested Overall VOC&HAP Control Efficiency%: 9 � Section 03-Processing Rate Information for Emissions Estimates w'" / °aaaalMBtri/ht F., �hrt} Volume of as ll3 1a 0:005 MMscf/day 195 scf/hr Volume of gas: 1 p,.3 .`0;03033 MMscf/day 1270 scf/hr Heat Content of gas:r 11P11 1„3 2050`stu/srf Heat Content of gas ,r ll 109$stu/scf Requested volume of Requested volume of gas: • 1.7082 MMscf/year gas: 11.13 MMscf/year Actual volume of gas: 0 MMscf/year Actual volume of gas: 0 MMscf/year PTE volume of gas: 1.7082 MMscf/year PTE volume of gas: 11.13 MMscf/year Requested heat content of - Requested heat gas: 1793.61 MMBtu/year 0.20475 MMBtu/hr content of gas: 12,215 MMBtu/year „4111111111W- 42111 JEN 1„ ,,0,04410§441V,1".. }1@ ,. Bthw t t t as yet?t Volume of gas: ,i s. 000799ZMMscf/day 333 scf/hr Volume of gas: ,. 0033216!MMscf/day 1384 scf/hr Heat Content of gas: 3 ...._ _ 1139$;Btu/scf Heat Content of gas i„ ,,_3 _ -;-130 Btu/scf Requested volume of Requested volume of gas: 2.92 MMscf/year gas: 12.12 MMscf/year Actual volume of gas: 0.00 MMscf/year Actual volume of gas: 0 MMscf/year PTE volume of gas: 2.92 MMscf/year PTE volume of gas: - 12.12384 MMscf/year" Requested heat content of - - Requested heat gas: 3202.95384 MMBtu/year content of gas: 15797.36352 MMBtu/year P ,ReftrgeraqudSystem Bfowdown(Propane}: ii Volume of gas: 0.005376 MMscf/day 224 scf/hr Heat Content of gas: s 2516,Btu/scf -- - Requested volume of gas: 1,96 MMscf/year _ _ Actuavolume of gas: 0.00 MMscf/year PTE volume of gas: 1.96 MMscf/year - - - Requested heat content of gas: 4936.99584 MMBtu/year Total Throughput: Total Requested Throughtput to Flare (Permit Limit) 28.13 MMscf/year Actual throughput 0 MMscf/year PTE Throughput 28.13 MMscf/year Requested Purge Gas: 11.13 MMscf/yr Requested Waste Gas: 17.00 MMscf/yr Purge Gas HHV: 1098,00 Btu/scf Avg Waste Gas HHV: 1407.815559 Btu/scf 49 of 65 K:\PA\2018\18WE0465.CP1.xlsm Flare Emissions Inventory , .ve--e tlr`tat#ruetpiuge.0scon€fastta:tReslie4asconsProst'ttarl. i,y< ,sutOca lititlii4rinteeiilE.__..3k >i# '-- 4 ''';;A:41 Throughput(0) 11.13 MMscf/yr 1270 scf/hr Throughput(0) 12.12384 MMscf/yr 1384 scf/hr MW ,,,'€8",.3 Ib/Ib-mol 0.03048 MMscf/d MW lea 1;23:0 Ib/Ib-mol - 0.033216 MMscf/d ---- Buffer. 10% mass fraction lb/hr lb/yr tpy mass fraction lb/hr lb/yr tpy Helium -0.000E+08 0.00 0.00 0.00 Helium .0.000E+00! 0.00 0.00 0.00 CO2 3.155E-02 1.95 17114.09 8.56 CO2 '14'2560E:64 3.77 33065.38 16.53 N2 I 8.960E=03 0.55 4799.45 2.40 N2 ,'S 51Ef-0 0.49 4299.23 2.15 methane .....F4965-01 45.83 401508.93 200.75 methane '„4.5320-Of 41.37 362367.22 181.18 ethane a - 7,790E-01! 10.95 95892.48 47.95 ethane =1,812E-01 15.20 133116.09 66.56 propane : 2.802E-02' 1.71 15007.01 7.50 propane 1.510E-01 12.67 110975.51 55.49 isobutane "WU,8.6000-04 0.05 460.66 0.23 isobutane ! 2.310E-02 1.94 16969.89 8.48 n-butane f'ii' 1210E-03 0.07 648.14 0.32 n-butane 6.401E-02'. 5.37 47033.67 23.52 isopentane - .5,005E-05' 0.00 26.78 0.01 isopentane 1.422E-03. 1.19 10450.87 5.23 n-pentane -,2.000E-05'. 0.00 16.07 0.01 n-pentane 1.459E-02'. 1.22 10722.74 5.36 cyclopentane %0.000E+00'. 0.00 0.00 0.00 cyclopentane _ 0.000E+00. 0.00 0.00 0.00 n-Hexane O.000E+00 0.00 0.00 0.00 n-Hexane 6.147E-03. 0.52 4516.75 2.26 cyclohexane 0.000E+00. 0.00 0.00 0.00 cyclohexane I- 0.000E+00. 0.00 0.00 0.00 Other hexanes 0.000E+001 0.00 0.00 0.00 Other hexanes I 0..000E=00'. 0.00 0.00 0.00 E^-^ heptanes 0.000E+0ti 0.00 0.00 0.00 heptanes 1.059E-03 0.09 778.14 0.39 methylcyclohexane O.000E+00 0.00 0.00 0.00 methylcyclohexane 0.600E+00 0.00 0.00 0.00 224-TMP E. 0.000E+00: 0.00 0.00 0.00 224-TMP 9942E-06: 0.00 7.31 0.00 Benzene 0.000E+o01 0.00 0.00 0.00 Benzene 2.652E-04! 0.02 194.85 0.10 Toluene 0.000E+00 0.00 0.00 0.00 Toluene 1.283E-04. 0.01 94.27 0.05 Ethylbenzene 0.000E+00. 0.00 0.00 0.00 Ethylbenzene 0..000E+00; 0.00 0.00 0.00 Xylenes 0.000E+00; 0.00 0.00 0.00 Xylenes 2.236E-05 0.00 23.78. 0.01 08+Heavies ''0.000E+00. 0.00 0.00 0.00 C8+Heavies 2180E-04 0.02 160.18 0.08 VOC mass fraction: 3.02% Total VOC(Uncontrolled) 8-08 • VOC mass fraction: 27.48% Total VOC(Uncontrolled) 100.96 Total VOC(Uncontrolled w/10%Buffer for conservatism) 111.06 r�,,.,, P-.',.'11(ic andtt ,f4ili RQsidoe R3ttuit=/ S:, VOCfram Refrigerant Gas Venting{Propene)` E•-E Throughput(Q) 2.917E+00 MMscf/yr 333 scf/hr Throughput(Q) 1.96 MMscf/yr 224 scf/hr MW •,,','''',,,',E2.,,.1".,, 18.3'lb/lb-mol 0.007992 MMscf/d MW _ ,,44:0:Ib/Ib-mol 0.005376 MMscf/d mass fraction lb/hr lb/yr tpy mass fraction lb/hr lb/yr tpy Propane ) ;1:D00E40U' 25.97 227470.58 113.74 Helium :St000Ei120, 0.00 0.00 0.00 VOC mass fraction: 100% Total VOC(Uncontrolled) 113.74 CO2 ` . `'0195E;II?' 0.51 4487.40 2.24 N2 ";$960EW3 0.14 1258.44 0.03 methane s ,:°-7 496E4A 12.02 105277.54 52.64 ethane ' 1.790E-01'' 2.87 25143.48 12.57 - propane • 2.802E-02 0.45 3934.91 1.97 isobutane '.8.600E-04 0.01 120.79 0.06 n-butane _-..1.210E-03- 0.02 169.95 0.08 isopentane 5.000E-05'-- - 0.00 7.02 0.00 n-pentane 3.000E-05 0.00 4.21 0.00 cyclopentane 0.000E00. 0.00 0.00 0.00 n-Hexane 0.000E+00 0.00 0.00 0.00 cyclohexane 0.000E+00 0.00 0.00 0.00 Other hexanes 10.000E+001 0.00 0.00 0.00 heptanes 0.00.0E+00 0.00 0.00 0.00 methylcyclohexane .0.000E+00 0.00 0.00 0.00 224-TMP 0.000E+00' 0.00 0.00 0.00 Benzene 0.000E+00'. 0.00 0.00 0.00 Toluene 0.000E+00 0.00 0.00 0.00 Ethylbenzene .0.000E+00. 0.00 0.00 0.00 Xylenes •-.' 0.000E+00: 0.00 0.00 0.00 CB+Heavies •9.000E+00 0.00 0.00 0.00 VOC mass fraction: 3.02% Total VOC(Uncontrolled) 2.12 Section 04-Emissions Factors&Methodologies z Control Device Uncontrolled E.F.(Ibs/MMscf Pollutant Uncontrolled E.F. waste gas Emissions Factor Source Citation (lbs/MM Btu waste volume heat combusted) combusted) PM10 kELBLIaL>17.8000 tle 4 -'"' PM2.5 7.5000 //% 3t31e / o NOx . `a+�1 100.0000 't`attle /': VOC �,' 5.5000 T 4,•` s att - , e _ CO , IP 04F0005 .ZT-! . SO2 r 0.6000 -,f,--', ;,,,,� 'Lab ,.//�, n-Hexane ... ,2.8000 i4, �. vTaattlt _ . • • 50 of 65 K:\PA\2018\18WE0465.CP1.xlsm Flare Emissions Inventory Weighted Emission Factors for Waste Gas(17%residue blowdown,71%inlet gas blowdown,12%refrigerant blowdown) Uncontrolled Controlled Pollutant IMEME Emission Factor Source (Gas (Gas Throughput) Throughput) EMIERESE26690.816 R'"' 'thv, 0.000 0.000 un v l 0.070 x F,r� 224 TMP 0�� " �' 3 vy 1 rjl/uRfe Emission Factors for Purge Gas(Residue gas Composition) Emission Factors Plant Flare Uncontrolled Controlled Pollutant (lb/MMscf) (lb/MMscf) - Emission Factor Source (Gas (Gas Throughput) Throughput) VOC 1452.438 72.622 4tatniss€on,lnu otorylanpra (io4 Y4ol� Benzene 0.000 0.000 £PJi.:nigtln�5i ntt :lmpro l �� 3f� (ns[ Toluene 0.W0 0.000 � f4t�gr��Ejitl� Ethylbenzene 0.000 0.000 '2 - Publ(£af, Iumm Xylene - 0.000 0.000 rpgrfRit gstbj[CatfatFl£t7€unto n-Hexane 0.000 0.000 Arbit4 0 224 TMP 0.000 0.000 Gontrot#1eu "{Molt€ 1,Nlate eMI..,',1iiii: Uncontrolled E.F.(lbs/MMscf Pollutant Uncontrolled E.F. waste gas Emissions Factor Source Citation (lbs/MMBtu waste volume heat combusted) combusted) NpOx ///��lJJ) ��+,,��,� 0.068 95.731 7Sty-42Chu' �;5 fytt'lot t lar2s[DiC1�sf 7J CO 0.310 436.423 AP 4 t'lst 0 ' a , SO2 r..-1;g6///i 0,600 3' .....g1.4,V ')>1 C tt €feiikkilro iliggin.itPutgeGass Uncontrolled Pollutant E.F.(lbs/MMscf Emissions Factor Source Citation Uncontrolled E.F. waste gas (lbs/MMBtu waste volume heat combusted) combusted) • ...: 74.664 lsp<St (t(,ter l8 5'Htdust>tafRtace6(f6O40D) /r 'a '''261:c °1',2 r ,�� 'iii`" CO 0.310 340.380 AP-42Chapter 285 Industrial Flares(NO40".' r 5O2 lk 0.600 AP 42T,a231C,3 M2. .v „,,„„ ,,>„ ;„/ /4/444;',.. 51 of 65 K:\PA\2018\18WE0465.CP1xlsm Flare Emissions Inventory Section 05-Emissions Inventory , '$i'.%',,' X,, . .n.. � .Pt1Gt, . .W4 r<,, t ,--ul Potential to Emit Requested Permit Limits Actual Emissions Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tonsjye-r (tons/ye. PM10 0.01. 0.01 0.01 0.00 Oct. PM2.5 0.01 0.01 0.01 0.00 - 0.00 . NOx 0.09 0.09 0.09 0.00 0.00 VOC 0.00 0.00 0.00 0.00 0.00 CO 0.07 0.07 0.07 0.00 0.00 S02 0.00 0.00 0.00 0.00 0- n-Hexane 0.00 0.00 0.00 0.00 -_- - Waste Gas - . Potential to Emit Requested Permit Limits -._..:. Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons;yenr) (ton',',ear) PM10 0.00 0.00 0.00 PM2.5 0.00 0.00 0.00 NOx 0.81 0.81 0.81 VOC 226.91 226.91 11.35 CO 3.71 3.71 3.71 502 0.01 0.01 0.01 Potential to Emit Requested Permit Limits Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Ut.'rr*Dried Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tee';.a_, (torts/year) (lbs/year) (lbs/year) Benzene 0.10 0.10 0.00 195 10 Toluene 0.05 0.05 0.00 94 5 Ethylbenzene 0.00 0.00 0.00 0 0 Xylene 0.01 0.01 0.00 24 1 n-Hexane 2.26 2.26 0.11 4517 226 224 TMP 0.00 0.00 0.00 7 0 Purge Gas '- - - Potential to Emit Requested Permit Limits Actual Emissions Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons/year( (tone/year) PM10 0.00 0.00 0.60 0.00 PM2.5 0.00 0.00 0.00 0.00 NOx 0.42 0.42 0.00 0.00 VOC 8.08 0.40 0.:(:, 0.00 - CO 1.89 1.89 __ 0.00 SO2 0.00 0.00 C.3= 0.00 Potential to Emit Requested Permit Limits Acru l Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons'eel) (lbs/year) (lbs/year) Benzene 0.00 0.00 000 000 0 0 Toluene , 0.00 0.00 0.00 0.00 0 0 Ethylbenzene 0.00 0.00 0 10 0.00 0 0 Xylene 0.00 0.00 -- 0.00 0 0 n-Hexane 0.00 0.00 : _ 0.00 0 0 224 TMP 0.00 0.00 0,00 0 0 52 of 65 K:\PA\2018\18WE0465.CP1.xlsm Flare Emissions Inventory - Total Emissions>(Pilot+Purge+Waste-Gas) - Potential to Emit Requested Permit Limits Actual Emissions Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons/year{ (tans/year) PM10 0.01 0.01 0.01 - 0.00 0.00 PM2.5 0.01 0.01 0.01 0,00 0.00 NOx 1.14 1.31 1.31 0.00 .,10. VOC 20.43'. 235.00 11.75 0.00 0 CO 4.86 5.68 5.68 0-00 101;0 SO2 - 0.01 0.01 0.01 0.00 0O0 Potential to Emit Requested Permit Limits Actual Emisvons Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons/yes,I (tons/vear` (lbs/year) (lbs/year) Benzene 0.10 0.10 0.00 0.00 0.00 195 10 Toluene 0.05 0.05 0.00 0.00 0.00 94 5 Ethylbenzene 0.00 0.00 0.00 0.00 0.00 0 0 Xylene 0.01 0.01 0,00 0.00 0.00 24 1 n-Hexane 2.26 2.26 0.11 0 00 0.00 4517 226 224 TMP 0.00 0.00 0.00 0.00 0.00 7 0 Section 86-Regulatory Summary Analysis 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, Regulation 1 1992))in all subsections of Section II.A and B of this regulation. Section ll.A.5-Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2 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 of the following limits:For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air. Part A-APEN Requirements Criteria Pollutants:For criteria pollutants,Air Pollutant Emission Notices are required fon each individual emission point in a non-attainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant(pollutants are not summed)for which the area is non- attainment. Regulation 3 Applicant is required to file an APEN since emissions exceed 1 ton per year VOC Part B—Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold(Reg.3,Part B, Section II.D.2.a) Regulation 6,Part A,NSPS Subpart Kb applies to the storage tanks points 010 and 011 at this facility.Since this fla re will be used to control these tanks in the event of primary Subpart Kb control device downtime,it is subject to the requirements contained in 60.112b(a)(3)and shall meet the requirements of 60.18 of the General Provisions. Section XVII.B.2:Since this open flare is used as a backup to control emissions from the storage tanks and TEG dehydrators subject to controls under Section XVII at this facility,it is subject to this section of Regulation 7.This portion of the regulation states:"If a combustion device is used to control emissions of VOCs and other hydrocarbons,itshall be enclosed,have no visible emissions during normal operation,and be designed so that Regulation 7 an observer can,by means of visual observation from the outside of the enclosed combustion device,or by other means approved by the Division, determine whether it is operating properly." Since this flare is not enclosed per Regulation 7,it has been approved as an alternate control device per Regulation 7 Section XVII.B.2.e.The operator submitted the"Alternative Emissions Control Equipment Request Form"to support their request to permit this flare as alternative emissions control equipment for the glycol dehydrator during VRU downtime and for the strorage tank during enclosed flare downtime. Section 07-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 intial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling 53 of 65 K:\PA\2018\18WE0465.CP1.xlsm Flare Emissions Inventory Section 08-Technical Analysis Notes The calculation of VOC and HAP emissions associated with the combustion of residue gas and purge gas is based on a residue gas data from meter data at similar DCP facilities.The inletgas composition is based on an extended gas analysis from the inlet gas at DCP's O'Connor facility(sampled 1_0/27/16). °This flare is used primarily for blowdowns and vents during maintenance from various portions of the plant and at various stages of the process.Therefore,DCP has estimated emissions from combustion of waste gas by assuming the average composition of the waste stream may be represented by a mixtureof residue gas,plant inlet gas,and gas from the cryogenic process.Of these streams,DCP has assumed the volume to the flare is accurately represented by 17%residue,71%inlet gas,and 12%refrigerant system gas.in addition-to the waste strea ms,this point accounts for a portion of the volume routed to the flare as residue gas that is used for purge gas.Considering purge gas in addition to the waste streams calculated above,the total volume of gas routed to the flare is represented by 10%residuegas,43%inlet gas,7%refrigerant system gas and 40%purge gas.Residue gas is used as purge gas. - - - The assumptions presented here are being accepted since it is based on actual metered data at similar plants,I will require initial sampling to demonstrate that the V0C and HAP concentrations in the residue gas and inlet gas streams.At this time,1 will not require initial sampling o€the respective waste gas streams(inlet,residue and refrigerant gas)for the following reasons: (i)TneVOC emissions at this facility are not a concern with regards to P5D Major source statusat this time.Even if the VOCconcentration did increase slightly,it woulq be unlikely to result in any additional requirements since the facility is not closet°exceeding major NANSR thresholds for VOC,As such,the environmental impactof requiring art initial or annual sample is minima€, (laThe operator is using a weighted average to determine the emission factors and VOC concentration in the notes to permit holder.Asa result,the annual sampling: requirement would need to be explicit on howthis weighted average would be calculated going forward.At this time,it was determined thatthe complex€tyrequired to !: include this information in the condition did not result in a significant environmental benefit.Furthermore,the weighted average used in this analysis is an estimation only.(in)The VOC concentrations for residue and inletgas used in this analysis appear to be consistent with values used at othergas processing facilities. *The operator did not calculate PM emissions associated with the combustion of waste gas.The operator asserted that since the flare is designed to be a smokeless combustion device,particulate matter is not expected to be generated from the combustion of dehydrator waste gas,residue gas,inlet gas or purge gas touted to this device. in orderto address this statement,the emission factor source for combustion emissions(Non and CO),AP-42 Chapter 13.5,was reviewed.This document expressesthe°emissiares from flaring may include carbon particles(soot),unburned hydrocarbons,CO and partially burned and altered hydrocarbons.Also emitted are nitrogen oxides(NOx)and,if sulfur containing material such as hydrogen sulfide ormercaptans is flared, sulfur dioxide(502)."Based on this statement,the document does not provide information with regardsto;particulate matter,except with regards to soot.The document further provides that a smoking flare directly results.in soot formation when it states"The tendency of a fuel to smoke or make soot is influenced by fuelcharacteristics-and by the amount and distribution of oxygen in the combustion zone."This is further' supported by footnote'c'below table 13.5-1 which provides the following:"Soot in concentration values:nonsmoking flares,0 micrograms per liter(µg/L};lightly smoking flares,40 tig/L;average smoking flares,177 µg/L;and heavily smoking flares,274 µg/L." At this time,there is not another source of data that quantifies PM10 or PM2.5 from industrial flares and therefore it will be assumed that the only source of particulate matterfrom a flare is soot from smoke as expressed in AP-42 Chapter 13.5. It should be noted that the O&M plan requires that daily checks be conducted to determine if the flare is smoking.If smoke is observed during the daily check the source is required to either conduct a method 22 or-. immediately shut in the equipment to investigate the cause of the smoke and conduct repairs as necessary.Based on this requ irementfor the flare and the manufacturer design forthe flare to be smokeless tf operated properly,it can safely be assumed that the flare will operate without smoke on a regular basis.Also,if smoke is observed,the operator will be required to assess the problem and perform necessary maintenance__to prevent the flare from smoking.As such,I am comfortabteassuming a soot concentration of 0 micrograms per liter as provided in AP-42 Chapter 13.5 for nonsmoking flares. T. Based on the information discussed above,itwas,determined that the operator's assertion that a smokeless flare would not be expected to have PM emissions was valid.However,if in the future better data is developed for estimating PM emissions from industrial flares it should be included in futureanalysis. *The operator expressed a flow meter will be installed to monitortotal volume of gas during standard operational process/nor ma operation of equipment(i.e.maintenance and blowdown gas)and purge gas.As a result,a condition will be included in the permit that requires the operatorto monitor total volume using a flow meter and use the data to demonstrate compliance with the process limit in the permit.The operator also indicated the piiotfuel is constant and does notvary.As a result,there is no need for a separate dedicated meterto monitor pilotfuel. *This permit will not include short term limits(i.e monthly limits).This is due to the"backup"nature of this equipment ith variable peaks of throughput(i.e.the throughput is not constant but rather occurs in pulses based on maintenance activities performed at the facility).It cannot be reasonable predicted how the annual throughput will be distributed on a monthly basis. Section 09-Inventory SCC Coding and Emissions Factors . Uncontrolled Emissions AIRS Point# Process# SCC Code Pollutant Factor Control% Units 015 01 Af�-ulln6. �,cor ;"':::", . tea NOx 87.3990 0 lb/MMscf Burned VOC 16708.6482 95 lb/MMscf Burned CO 398.4364 0 lb/MMscf Burned Benzene 6.9273 95 lb/MMscf Burned Toluene 3.3513 95 lb/MMscf Burned Ethylbenzene 0.0000 95 lb/MMscf Burned Xylene 0.8454 95 lb/MMscf Burned n-Hexane 160.5762 95 Ib/MMsd Burned 02 .,.' 0 4 - 743:` , PM10 0.00 0 lb/MMscf Burned PM2.5 95.73 0 lb/MMscf Burned NOx 0.00 0 Ils/MMscf Burned VOC 436.4 0 lb/MMscf Burned CO 0.60 0 Ib/MMsd Burned t02 0.00 0 Ib/MMsd Burned n-Hexane 'MMscf waste gr 0 lb/MMscf Burned *Process 01 represents waste gas combustion associated with purge gas,inlet gas and residue gas while process 02 represents pilot light combustion.The emissions factors represented In process 01 are based on a weighted average of inlet and residue gas. 54 of 65 K:\PA\2018\18WE0465.CP1.xlsm • Fugitive Emissions Inventory Ir man o.m� 1iP .,,'u N Ettat:r saes oz-9wie..,t c.wmno n wm m ua r,6xnwar moexam-+kaa crtrvAe%a' wnasaaa-7M oaa�wo. n.,a�,re+:�d±A.�z,,m ta�`�iiiaY..%�..i; ..,.. 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Section 08.1n,..mlooy XL Ceding and Emissions Fa= LIneeKroaoti MSPewa Pollutant Gmlame.aanr Con.% Some �,� w0 ramaby me m '.., pifg5. .......,:1.W,y,.-,�__.3..»,-?� voe mmvonentnpe aanvonemnm aanaara Era Evras9masm]Tab e:s ms M1 Bann. component type mmepnen pe dams fh EPhasflrv95m]nblpi< nmVaries by Toluene component Mae component Woe samara Gus•wns5V>95m]Taae z+ Vanes./ elMdname conponemaw component type Standard En•EP.euVn95m]Tme]a Varet.,/ Mylene mneennttme component hoe sand.fh EPu5Vw95a]Table]-1 Vane,by malemne componnmrvpo comveent type Send.EFs EPM5VM195m]Table li Vanes In 324 TMp component type component type Sanaerb Us-EPMS.95m]Taae is Condensate Storage Tanl<(s)Emissions Inventory 017 Methanol Tank Facility Allis ID: "'- •• County Plant Point Section 02-Equipment Description Details Detailed Emissions Unit 'TWq(2)4DDtihtmethaanlstoragetankfi ,313laWA Emission Control Device Pdo CpntrCE - s.- �,.� 1 ' nl. ti cw 33 1 a Descnpbon: � .' '� }} Requested Overall VOC&HAP Control tirbrazgtm Efficiency 8S, Section 03-Processing Rate Information far Emissions Estimates Primary Emissions-Storage Tank(t) Actual Condensate Throughput= im,)a}., Barrels(bbl)peryear Actual Condensate Throughput While Emissions Controls Operating= WIRE Barrels(bbl)per year Requested Permit Limit Throughput= iiftat.241666ii Barrels(bbl)per year Requested Monthly Throughput= 815 Barrels(bbl)per month Potential to Emit(PTE)Condensate Throughput Barrels(bbl)per year Secondary Emissions-Combustion Device(s) Heatcontentofwastegas= ,/ Btu/scf Volume of waste gas emitted per BBL of liquids y ti produced= ,,scf/bbl Actual heat content of waste gas routed to combustion device= MMBTU per year Requested heat content of waste gas routed to combustion device= MMBTU per year Potential to Emit(PTE)heat content of waste gas routed to combustion device= y MMBTU per year Section 04-Emissions Factors&Methodologies • Will this storage tank emit flash emissions? Uncontrolled Controlled Pollutant (Ib/bbl) (Ib/bbl) Emission Factor Source (Condensate (Condensate Throughput) Throughput) M:IBMStteSltac '®' S el:ass°. a iaE&ceo 3i3 Control Device Uncontrolled Uncontrolled Pollutant (Ib/MtbIBtu) (lb/bbl) Emission Factor Source (waste heat (Condensate combusted) Throughput) l ��6 0.00001 /� f 0.0000 :, � rte 3 ^ � G 43 fff � x 0.0000 j4,i ..li t+ .,1 k_ ,h Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons'/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month) VOC 0..62 0.00 I 0.00 0.62 I 0.62 104.85 Potential to Emit Actual Emissions Requested Permit Limits HazardousAirPollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled jibs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year) Methanol 1235 0 I 0 1235 I 1235 Section 06-Reeulatory Summary Analysis Regulation 3,Parts A,B Source requires APEN,is permit exempt Regulation 7,Section XVII.B,C.1,C.3 Storage Tank is not subject to Regulation 7,Section XVII Regulation 7,Section XVII.C.2 Storage Tank is not subject to Regulation 7,Section XViI.C.2 Regulation 6,Part A,NSPS Subpart Kb Storage Tank is not subject to NSPS Kb Regulation 6,Part A,NSPS Subpart 0000 Storage Tank is not subject to NSPS 0000 Regulation 8,Part E,MACT Subpart HH Storage Tank is not subject to MACF HH (See regulatory applicability worksheet for detailed analysis) 57 of 65 K:\PA\2018\18WE0465.CP1.xlsm- 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? i!,,, tans If yes,are the uncontrolled actual or requested emissi estimated to be greater than or equal to 80 per year? -_ If yes,the permit will contain an"Initial Compliance"testing requirement to develop a site specific emissionsVOC factor based on guidelines in PS Memo 05-01. Does the company use a site specific emissions factor to estimate emissions? � If you if there are flash emissions,are the emissions factors based on a pressurized liquid sample drawn at the ` If you and ding perm�tt flash s sample should be considered representative which generally means site-specific and �" -1-''.:s-2,';.;',..,:,,„.,,,,,, collected wrthm 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. gp&�<drlr i-rt[k4 If no,the permit will contain an"Initial Compliance"Testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the compan nest a control device efficienry greater than 95%far a flare or combustion device? . Y re9 '�bxO'n device based on inlet and outlet concentration sampling Secti n 08 Technical Analysis Notes _ _ 7hi q pmenideesnot m ores, ,te p ii to tslntepo taftham ntsfper Reg3P rtAJ' nd onlyAPENtegwredfor HAPSlmet}�anolj As3s cp ., gmpny stsullnotinclud any em on, nt,. h.--" ihepermii. - "f' a.- Section 09-Inventory SCC Coding and Emissions Factors Uncontrolled Emissions AIRS Point# Process# SCC Code Pollutant Factor Control% Units 017 S� C�kf33 s ...e.„,/,,,,,,:<„,..:, r.. VOC 3.06 0 Ib/1,000 gallons condensate throughput Methanol 3.06 0 16/1,000 gallons condensate throughput 58 of 65 K:\PA\2018\18WE0465.CP1.xlsm • • fnndensate Tank Regulawry Malysi6 WWdgheet Colorado Regulation e and av��Permit Requirements uw is Ma n n5- a® I.Are unmnppued aural embsom from any alter.poll...from this Individual source greater Ilan 1111.'3211m,3.Pen 0...on Ralal) rsp 2 Is obey:instruct.demiseraloecirts)prior mu//2111 and notmcefed after101113 or e5nteno o5a10ennlNomial an d1.1.10.0153.0.0.2 Part, for addltbnel guidance on gmdhme mp®bmNl] 3 uem Ity uncmpolled VOL axioms groans Man 5111110x greaser 101113 c m mudomgreamv man t0irr lRegulemn 3.Prt,Section Dn3R �'✓p�'-;;?$to Ieo1 enough lntcemelon 1.Hemmnvoi.emhYom tummy.alter pollutants fremmb lMNkual sours greater than 1TPy cram,sbde xRPgrcater man aOlb/yrWgvlamn 3.PnA.Raba l.D.vl] Ydat;'.0.1 Sosm rres an Naha to*',mous. 2 Is ate(sets(serviced.) to am leer 12/31/2102(See P5 Memo 05-013&tion112apd1.16 aascdm2 forademone guidance on gaandv appazbreM] �+o `-I 3.Hem >w d am man zTPf,xOk greater tan 5IP,orCO emabnsaeeer Man sift lReeuladm;Par a,Scants 0.0.x1] id'tt �s se,r,eutn.w.en.na P.m®gym a I'Ixurm rooter,.WEN,Immdteemot . Colorado Regulation),saNm slla 1.Is.voraeo tank located In tlle 2-hr mono woad arm*rem ozone non.o.Inment area or acminmem/maintenence wee, storage IO.g mrelegF prosexsing p.m) 3.Dona z.Rat�p lem3373andhave uncontrolled amalem:Nmvgreeter Man cream!to2,nn,per va.yDCz "w0.0.110I5m wra,ee,m,.blectmRe„.ten,.s.bannt� "1"""mm•",n... Contra equipment onmkmes s ewnxicUz-P General sae van auesow Cobra.R.eantlm),Rana,ml ioe/stoma today] sit aabdaiionand production operamn.well produmon famWole [As o0.11prevorrodon or na[uralgas pnxessIngp.no n.wades.d,.nlhy„p.wpraae,a,a,,.rr,h.at. .1O.44•.x. m matquestion ..Heuncontrolledg eorf .than 6 ion,per,.ar«] tbsa z.,g'se.aw Tank b nee,ubMtte wbton).5w3.3xvn I vraNsbm Section 211120.5-Record...flemulrem0.0.0. 5.Does Me condensate m gquid - r?,:1 wage....retwbkn no Po..n].sacm.rvnra 2111.0.2 Section gw2u Capture emir.. on..rtx5bvage Tan.ROawit,.Pollution Control Equipment 60012 P..160 Subvert 10:3 Standards of h ICIpu1EAneeevoaab Is Me individual storage vessel capacity ere than or equal100]5abk mews{m1)(-13283B12zo m.nku u,aepn xsesm m.,m,.w�aeo.nnbaa«m„oPx.um�ww. z.Dona 5011/61111311 L lei®aMty Ins than or=WM1589.833 m‘IROPOO MI meal nsam,mrd.'3room...or sreamt prior m onmdyoanafer adCmretl xsDlub] 3.Was ifils em storage :�mma.ormodifiedfseo nlm CFRm„a,le;1„a1;:,nda 5.Does Illestorsge vessel store a Naiad.organic lipoid;We as defined In 60.1111,2 6.Does the,totageva„I meet any one alum n g addlIbnelerempdpn, stne,mrew Vestala peaaureveaseldeaped m operate In 333.333..33331-25-7psna.whhoutamb,lonam the atmosphere.0.1.10130112117, a 0.r equal 33 151rn'1"3508821 and storm a liquid'talc madm0m pun vepm preasure.Ims L519c 1w.110b10112 or.. capaeNh erecter Man°rmua to 5 .M'I-0188L1 but ass Man 151'1-31100.811 anesm qu rm a d 1.1a m w admumevan eu kit or Pr °ro' Man is 0,e18uss.104, ff, Isis randalaax5°2.b Subpart AGen sal Provisions 4W1134-FrMsbmcantral Standards for VOC e 4®1136-1-1,..rand Procedures W..- ,.end Recordkeepng pmuimmne 460.11.3-MonitoMg of Oper31100 m0.112 Pan60.Subpart 0000Rmdadam 0Mmance for Crude OR end inure Gas Ptmustlentarominim and 0ladbldon 10 O33 mr4,3 r0Wagatln0000 t orr0WTz bn wd segrrentof the Wu.,) ve vessel co ss tru,W0 m Ike bee 6OY bebaeen gust a. 11 Sepmntersg,x015]s a Tank bmawberxsn 0003-11.3.3.a1m,wctedaw m theeemm0Nwu 3.Are bap from peryea10 gN,y.y,,5ni a.Dom condensate Stara.vessel meettliee311nilim of.storage vassal' 5.Isl.store subimm end controetln accdancewithtecu rementstorsm0zge 0810021/0 CPR Pen 60 Subpart 00 or 40 CPR Pan53.boa0xx] ISterage Tank le ubjm 3� Subpart 0.General Prwgloesr per 450.545 Table 4W935•Pmbsbm Ccnod Standards for vac 4603613-rnung and Procedures 460339541-xodfiradon,Reportlne and Rec«dkeegneRmWenents §60-33123e1-Covet era Closed Vent 5vsem NalimrOm Rmunene. 461,111-Convar Dente btanimniy Rmdremena Ife.a ass age vessel la prudcurydaambato be subject toMPS 0000 duet°wassions atom 6 tau Peryenrva on the appR®may daemanatbn alts,a should remain subject to t.5-0000 per 6098.5(41(2)wen paendd V 0C emissions drop blow a twit p.r,rl 0.R.Pet 63,5°680.kuCT R x,OR end 6a s Prod*ermt w Is , sten oitand natural r rdo,„ngtmaie. ',e, I[Drama-3301.,.Bared ,°m. ,reeatagon, yrwats.10.wn,nea. a A'slily the processes,upgrades or stores hydrocarbon NU.'158.)50011211 og • facility that pracess4x upgrades afsnwm realnl gas odor to the mint atwnim namrh as men the natural gas ran,mk,bn and,mnP.e source moan or Is[fel vered toa...ch.,'163.]611811311] 2 Is..1 located ate teal,moth major'for xne] pTank rm,vblea a w rrxx.Te ate.NWT rrn m wa p=nenr c,r«w, ce, 3.Does the onic meet Me deralon of.storaRe 63.7612 0.Does the 5.LsthelnklyrectmcoonPaa uI,erems nd 01Q Part�¢s°w,rt even 0..30.0ra.v 12::1.1 5,31.0.10.General provisions w.3.7641a1Tablez 4533x63-3.35333,Crow,slantlaw 663.)13.WNW,. 463.776-Ra°rmaepbe 463.775-Reporting PARRadow aAc)reWa le neu'red N Reolatien)mm not apply MD X tna tank 0 in too non+r einmad aria.If the tank meets both criteria,then edw ancT nouinmm ms. Disclaimer • ibis dm'numnfassisb opeatasmda ddam0ll000Plica6iliN o/mrtan reque8Tenlsa'Me Gean 06 Act.Xs implemer.q regulations,and ilk Oualiy Control Cwmvsa*n regulations.This 000008) a rvborregrlaf00,and ueanarysb5 mnibins may nil a0P0ma 00oicular 011.based upon the In1nedual0}s and axumsler illlsOOmo8N does rot charge orsnb lWle/or any law epulalbn,01 any o0erbpaPy binding readne1enl antl0 not legally enforceable.In the event of any conflict batmen Ne fanpn¢ped Nb tlemnenf antl Ne 0r9,4em dole GmnAlr Act„ifs bm506011 grapxblb0*and AlrQuay Con.,Comnussend,*10000 Nro 6rya4ad NesbWle orrepu@Hots wA3tNn3t Tlla ram 3lmnneM 1101 brgrage srch 80 Temrrvrerd Trey," ".48,40."add"ten,"is'Max.,ld 0ev0030 AFCDmbnprela/onsard reconnercbtrns 1 00fl teminabgr..as 3t0sr and 0al,ireGsre NW.10c6anbe mar.,.requ0arents under Ile lams of the Goan 0ir Ad and Ab 000yCanlm'C0 misson rwati°0*but...anent does nit 20006 h kg.),b0100gregikemer min and 0000.0 Produced Water Storage Tank(s)Emissions Inventory 018 Produced Water Tank RWMFacility AIRS ID:. 1.it3 _-9E68;I 010 County Plant Point Section 02-Equipment Description Details • Detailed Emissions Unit ,{ MItre-. eliix, too pradueed"+sater9toEagetonks. _ „ s _P Description: Emission Control Device None _ 7�pp 3 3 Description: Requested Overall VOC&HAP Control Efficiency%: • Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Storage Tank(s) Actual Produced Water Throughput= „x„#r ,.'„Barrels(bbl)per year Actual Produced Water Throughput While Emissions Controls Operating= Requested Permit Limit Throughput= ?(y.445,80. Barrels(bbl)per year Requested Monthly Throughput= 3822 Barrels(bbl)per month Potential to Emit PTE Produced Water ' Throughput= max**Barrels Barrels(bbl)per year Secondary Emissions-Combustion Device(s) •Source is not controlled Heat content of waste gas= ( Btu/sci Volume of waste gas emitted per BBL of liquids f3i4Ja produced= g�:r-I,�n11131��;. /bbl Actual heat content o₹waste gas routed to combustion device= 0 MMBTU.per year Requested heat content of waste gas routed to combustion device= 0 MMBTU per year Potential to Frnit(PTE)heat content of waste gas routed to combustion device= 0 MMBTU per year Section 04-Emissions Factors&Methodologies Will this storage tank emit flash emissions? L Produced Water Tank Uncontrolled Controlled (lb/bbl) (lb/bbl) Emission Factor Source Pollutant (Produced (Produced Water Water Throughput) Throughput) • 0.252 lrPrrmduCit0 W5SyEt t#t0 is. O507 0.007 Pirrdit :: - t attlegazol 0.000 mi'io - 0.000 S I 3.. th ,M`...;-: D.DOD falintrleillinalle av W,aA103'' F`1(" 5nsSs Fran: '�'s z 0.000 MMEMEEME Uncontrolled Uncontrolled (Ib/MIVloto) lib/bbl) Pollutant Emission Factor Source (Produced (waste heat Water combusted) Throughput) 0.0000 s lax 0.0000 0.0000 Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month) VOC 5.9 0.0 0.0 5.9 5.9 1001 PM10 0.0 0.0 0.0 0.0 0.0 0 PM2.5 0.0 0.0 0.0 0.0 0.0 0 NOx 0.0 0.0 0.0 0.0 0.0 0 CO 0.0 0.0 - 0.0 0.0 0.0 0 Potential to Emit - Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year) Benzene 315 0 0 315 315 Toluene 0 0 0 0 0 Ethylbenzene 0 0 0 0 0 Xylene 0 0 0 0 0 n-Hexane 990 0 0 990 990 224 TM P 0 0 0 0 0 60 of 65 K:\PA\2018\18WE0465.CP1.xlsm Produced Water Storage Tank(s)Emissions Inventory Section 06-Regulatory Summary Analysis Regulation 3,Parts A,B Source requires APEN,is permit exempt Regulation 7,Section XVII.B,C.1,C.3 Storage Tank is not subject to Regulation 7,Section XVII Regulation 7,Section XVII.C.2 Storage Tank is not 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) Section 07-Initial and Periodic Sampling and Testing Requirements '; is`. Does the company use a site specific emissions factor to estimate emissions? 'ef- i 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 rcaot m re arho thatstora a tanks mntain;3 3 �T7I - :. - - '` _,�''` .""i p g g pted aYit'e�hiaupdglesst[zareS°r6-¢udzodbyuntume Therefore souYce�+etllbcasslle 3 1� mnfiTsrYirrg.' �as'��C+� r�d( - t��} "4114111 c'a�. jj I ��. ��3�33I]3� Apolrcantrs report ogst.`FPY V€'7C°'apd'assuditfje v2ssel 34 I.'Csub ecttq NSPS OQa£oO0d j norRegt,)atian 7f �ctidnswian rml Aa Y ,I I �I u ' y 3 33 33vd33r 3 �1 t �6 �'r 13 k x vQ I.II 3 1j 1 3 Pa i a l '� s � ¢43} fix �� x £ 3 3 I3 3Ia q v 3 3 3'7�� R _ t #.- Pif l 33333��33 3v'3�111 Ll�f S _ I e1k'Slll 2 c�.� 3 ire 3 £ <��3�3 3�3_,,,,f, i�),A3,,,,,-.. 3 .....:;3{ . " a...., ,, u m .n m.n• � I₹va�.s.,.l�..`.\.,Ye....ue��317�fiid „.,...331E3133�1��,1 .£�is�r��≥� Section 09-Inventory SCC Coding and Emissions Factors Uncontrolled Emissions AIRS Point# Process# SCC Code Pollutant Factor Control% Units 018 01 4-04-003-15 Fixed Roof Tank,Produced Water,working+breathing+flashing losses PM10 0.00 0 lb/1,000 gallons liquid throughput PM2.5 0.00 0 lb/1,000 gallons liquid throughput _ NOx 0.00 0 lb/1,000 gallons liquid throughput VOC 6.2 0 lb/1,000 gallons liquid throughput CO 0.00 0 lb/1,000 gallons liquid throughput Benzene 0.17 0 lb/1,000 gallons liquid throughput Toluene 0.00 0 lb/1,000 gallons liquid throughput Ethylbenzene 0.00 0 lb/1,000 gallons liquid throughput Xylene 0.00 0 lb/1,000 gallons liquid throughput n-Hexane 0.52 0 lb/1,000 gallons liquid throughput 224 TMP 0.00 0 lb/1,000 gallons liquid throughput • • 61 of 65 K:\PA\2018\18W E046S.CP1.xlsm • Produced Water Storage Tank Regulatory MOWS Worksheet Please note that N5PS lib might be might be appliceble for certain lento et water mmaagement and In4.dfan falliti .If the tangs you are reviewing ere at one of these Wattles,Meese review NSPS Iro.ion Pam/tend.OPEN ar.Permit mbrab-ISmnm an NONw-tevmnem Aye+ uemm¢a ATTAMMAre Sundt.actual criteria pdiuonafmnmk(ndNbpl stoma greater Man$Tp lgeauladon 3,PartMsemlon llnlaii 2 la mxawa Man aixmndeel aneh the enkMmmt eta nonmom�rdal lanutafor proms,a oil and gawmeeaen tflawlamn a Perrg,stdon ilna.Ml B....fedi,ecconaalled Noe eneebn greater Man 5iPf,NM greater men 30TPy ores emissions greater tan 10 TM'(Regulation 3,Pate,secdon ll.O.31i q//�'f/%/' 'You low edlmmatnammm ie Nor M.mmoemAm. plCiff.ATTAmpaparr 1. uncontrolk.emissions re pmuonn bamenrMNbuelepurtegreanmanlTic,lgawladon3.wrt0.5emn o.lali efrigi0 ricer en 2 operator aline lass Man.crodeolana Nem rank ioca.are nimmornmercial Mary for aaaeMg°P wastewater?(Pe.Won 3,Par...aalm 11.01,M)3.Me an:TP`aoegreaer Man sTx egreaer Mari 3TM(Pewkmn 3,Pert a Same.D zli rev aaatN-renmreeam pamnemat ISoum repuirm PPM,Is permit man. Colored,.aration section Pknl • ate transmission/storage Wary? tro continua.rim have indicted memerce am on u 2 Is ma produced enk'eoeea[sob,N gas*radon and pmaamn operamn,wdl produttbneckrcy,nand,ccopresor sotbnem navarai gasproceairy plants - Me Marta-cc on Pmiee Summary%ac 3.Is.pmtrvlwaer soxµ.mk a MI roofstorµe saki Y+:4=-p rnaurae o Are unarm.. greater than 6 ton per yea+oei iis¢:.%;Y�nw Teak ltna militate malabn T,SmbnlMl Imorne Tank it nor sublectro Piemia.n Sao.MI • vol • section -General Provisions for.PoEquipment and Prevention of EmeYon Section Priessfons ntrol MonitoringgProstrbn MM.=PewrdkmPng Acquirement s.Dom am waemom,.tank conob onl"memed'tip.? ,the M... t poidonsapply. �mm Tam once subject to PamiabnT5edbn%tit] m lacora em Peru..J.M.o.MM°.rna 5.rte,iryNt2. dre.ndboningMrstorage',notoeswitli ',Audem Control Equipment POUR Part aaseboert OCOO.Stenmimef Performance for Crude OR and Natural.Product.,'anemia-Op end MoribNlp¢ L Ischia produced row=rage vessel treated a s w ilty in me onshore oil and earal gm segment product. natal gas cr amming natural gm Pansmesbn and storage segment,to lMusepiducostoos unmoor r p.m rm. Wm ma prmn[el roan storage mama mmareams-Mattedreams-Matted,or modified Nee aenol-tons a0CPx,snz)Carom,August a,zm 18,2015,tana Yptember18,2015, n l,i an w aiu n PUPS 0000.Tnewlrwm ama ssen*mooue appeaeay wee I Me perm.Mx emissions'from a sewage easel greater manor equal'seas per year Storage Tank a no weezrev m00 a.mm ma produced vessel r storage a meettiedemmm or-etm.geveetd"'per 6a,a30i 0000 Seam./,Gen.vroAtkps per 45t54p5 Table 3 460,395-ErrMsbns control Standar.Mr PCM 460,113-Tmdng and Pratte res affil$355(e).Modnamn,PepornMam firnkmgnggmuaumeno 460x17-1-Ev er a ns abed veto Syeem Sur Imring Parvaenen b 4Pdx1T-Control Device Monitoring aryubtre n [Nam If aa.aya veils pmiardyaaenrined immbis to taps 0000 Mamoru*aoree tom peryeerVOCOntlempgueaaydaterminetienaelh Kelm.bremain sugar.torsos 0000 pareossss1eN11.aen it cotantialVOCernksfonadropte.6tonaprveari PAc'rravaa,nrquwdh Reguldonadm.mat apply AHohtha tank!silo thon0000.1 tam ore.If the tank nwebboeh mitad,,limn nriaw PACT requirements. Disclokrter 011010Misdocurroonlasrisleoperators...ierminingapplicabilfiya-envy rgiPnranls,'the Gran AC Ad,ifsvrylsrenti,requ64aT;and Air Quality Canbcl Gtrmisser rWulelibns.Thlsolocemanf nolo rule or regulation.and.amity.sdm may nolappy foe poKNarstudllon based upon the WA.wl fact sarrdcrcvmdercas.ilrt document does rwl change arbd/Iule laranylew, regu@Ib5,or anylIher legalybinrfrrg rg came',ed/enollemallyen5wabk.In 050050 r or anyoan151105Meen Melangrmged Na dxumenf mMIM language onhe clean Nrad„Rs inmlemanibg repo...,and AcpualcyCo',roi Commission rgklo5 the 5,5550011105151510 orreprle0n will cdmm4 The use olrgnmeMalarylerguapesrcn az'rewmrrentl;'may,' dwutl,"aM'pn,"Is intend0d Mtlescrdae AP.inlerplelelbns5M recommendations.MaMalo ...boy as"rnusr and,equ4errare Nen etl to des..wrbrol&g monk's..under Me leans°015004001 Air Ad 50000 Orally CuMrdG Twassbn regualb55 bN Nads'umenl ticesndedebis0 kpaly bindbg equvees040,5 and 0/AUC. COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION FACILITY EMISSION SUMMARY Company Name DCP Operating Company,LP County AIRS ID 123 History File Edit Date 10130/2018 Plant AIRS ID 9FBB Ozone Status Non-Attainment Facility Name Shelton Gas Plant EMISSIONS-Uncontrolled(tons per year) EMISSIONS With Controls(tons per year) POINT PERMIT Description PM10 PM2.6 H2S SO2 NOx VOC Fug CO Total PM10 PM2.5 H2S SO2 NOx VOC Fug CO Total REMARKS AIRS VOC HAPs VOC HAPs ID Previous FACILITY TOTAL 0.0 0.0 , 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 New Facility-No Previous Total Previous Permitted Facility total 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 001 18WE0465 Dehy-Train 1 0.0 0.0 0.1 29.2 0.3 6.0 0.0 0.0 0.1 1.5 0.3 0.3 002 18WE0465 Dehy-Train 2 0.0 0.0 0.1 29.2 0.3 6.0 0.0 0.0 0.1 1.5 0.3 0.3 003 18WE0465 Dehy-Plant Bypass 0.0 0.0 0.0 19.5 0.2 4.0 0.0 0.0 0.0 1.0 0.2 0.2 004 18WE0465 Heater-Train 1 Mol Sieve 0.4 0.4 0.0 3.4 0.4 5.7 0.1 0.4 0.4 0.0 3.4 0.4 5.7 0.1 005 18WE0465 Heater-Train 2 Mol Sieve 0.4 0.4 0.0 3.4 0.4 5.7 0.1 0.4 0.4 0.04 3.4 0.4 5.7 D.1 006 18WE0465 Heater-Train 1 Stabilizer 0.8 0.8 0.1 5.2 0.6 8.8 0.2 0.8 0.8 0.1 5.2 0.6 8.8 0.2 007 18WE0465 Heater-Train 2 Stabilizer 0.8 0.8 0.1 5.2 0.6 8.8 0.2 0.8 0.8 0.1 5.2 0.6 8.8 0.2 008 18WE0465 Heater-Train 1 Demethanizer 1.2 1.2 0.1 8.0 1.2 18.9 0.4 1.2 1.2 0.1 8.0 1.2 18.9 0.4 009 18WE0465 Heater-Train 2 Demethanizer 1.2 1.2 0.1 8.0 1.2 18.9 0.4 1.2 1.2 0.1 8.0 1.2 18.9 0.4 010 18WE0465 Condensate Tanks-Train 1 0.6 91.81 2.5 14.0 0.6 4.59 2.5 0.7 011 18WE0465 Condensate Tanks-Train 2 0.2 91.81 0.7 14.0 0.2 4.59 0.7 0.7 012 18WE0465 Condensate Loadout 0.8 203.09 3.5 30.9 0.4 10.2 1.6 1.5 013 18WE0465 Pressurized Unloading of Condensate 8.5 8.5 D14 18WE0465 Process Flare-Train 1&Bypass 0.010 0.010 0.0 1.75 355.04 7.64 0.010 0.010 0.0 1.75 17.76 7.64 015 18WE0465 Process Flare-Train 2 0.0 0.0 0.0 1.3 235.00 5.7 0.0 0.0 0.0 1.3 11.75 5.7 016 18WE0465 Fugitives(Train 1,2&Bypass) 273.9 43.8 017 18WE0465 Methanol Tank 0.62 0.62 018 18WE0466.XP Produced Water Tanks 5.90 5.90 Insignificant activities 0.1 0.1 0.8 4.60 0.7 0.1 0.1 0.8 4.60 0.7 FACILITY TOTAL 4.9 4.9 0.0 0.5 38.9 1,078.6 273.9 88.3 76.4 4.9 4.9 0.0 0.5 38.4 76.7 43.8 86.4 5.3 VOC: Syn Minor(NANSR and OP) NOx: Minor(NANSR and OP) CO: Minor(PSD and OP) HAPS: Syn Minor B,T,X,n-hex&Total HH: Syn Minor+affected Area 7777: Syn Minor Permitted Facility Total 4.8 4.8 0.0 0.5 38.1 1,068.1 273.9 87.6 76.4 4.8 4.8 0.0 0.5 37.6 66.2 43.8 85.7 5.3 Excludes units exempt from permits/APENs (A)Change in Permitted Emissions 4.8 4.8 0.0 0.5 37.6 66.2 43.8 85.7 Pubcom required based on A change in emissions and new syn minor limits.Modeling not required. Total VOC Facility Emissions(point and fugitive) 120.5 Facility is not eligible for GP02 because>90 tpy (A)Change in Total Permitted VOC emissions(point and fugitive) 110.0 _ Project emissions greater than 25 tpy Note 1 Note 2 4 Page 63 of 65 / Printed 11/5/2018 14 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY-HAPs Company Name DCP Operating Company,LP County AIRS ID 123 Plant AIRS ID 9FBB Facility Name Shelton Gas Plant Emissions - uncontrolled (lbs 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 18WE0465 Dehy-Train 1 4965 3153 1311 2522 3 7 6.0 002 18WE0465 Dehy-Train 2 4965 3153 1311 2522 3 7 6.0 003 18WE0465 Dehy-Plant Bypass 3300 2093 866 1684 2 5 4.0 004 18WE0465 Heater-Train 1 Mol Sieve 11 252 0.1 005 18WE0465 Heater-Train 2 Mol Sieve 11 252 0.1 006 18WE0465 Heater-Train 1 Stabilizer 16 1 386 0.2 007 18WE0465 Heater-Train 2 Stabilizer 16 1 386 0.2 008 18WE0465 Heater-Train 1 Demethanizer 35 1 2 834 0.4 009 18WE0465 Heater-Train 2 Demethanizer 35 1 2 834 0.4 010 18WE0465 Condensate Tanks-Train 1 2440 6761 504 5110 13127 10 14.0 011 18WE0465 Condensate Tanks-Train 2 2440 6761 504 5110 13127 10 14.0 012 18WE0465 Condensate Loadout 5398 14960 1114 11308 29047 22 30.9 013 18WE0465 Pressurized Unloading of Condensate 163 161 51 1364 51 014 18WE0465 Process Flare-Train 1 &Bypass 298 144 36 6910 11 015 18WE0465 Process Flare-Train 2 195 94 24 4520 7 016 18WE0465 Fugitives(Train 1,2&Bypass) 526 255 64 12191 15 017 18WE0465 Methanol Tank 1235 018 18WE0466.XP Produced Water Tanks 315 990 TOTAL(tpy) 0.1 0.0 0.0 12.5 18.8 1.1 12.6 45.5 0.6 0.1 0.0 0.0 91.2 *Total Reportable=all HAPs where uncontrolled emissions>de minimus values Red Text: uncontrolled emissions<de minimus 64 18WE0465.CP1.xlsm 11/5/2018 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY-HAPs Company Name DCP Operating Company,LP County AIRS ID 123 Plant AIRS ID 9FBB Facility Name Shelton Gas Plant Emissions with controls (lbs 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 18WE0465 Dehy-Train 1 248 158 66 126 0 0 0.3 002 18WE0465 Dehy-Train 2 248 158 66 126 0 0 0.3 003 18WE0465 Dehy-Plant Bypass 165 105 43 84 0 0 0.2 004 18WE0465 Heater-Train 1 Mol Sieve 11 252 0.1 005 18WE0465 Heater-Train 2 Mol Sieve 11 252 0.1 006 18WE0465 Heater-Train 1 Stabilizer 16 1 386 0.2 007 18WE0465 Heater-Train 2 Stabilizer 16 1 386 0.2 008 18WE0465 Heater-Train 1 Demethanizer 35 1 2 834 0.4 009 18WE0465 Heater-Train 2 Demethanizer 35 1 2 834 0.4 010 18WE0465 Condensate Tanks-Train 1 122 338 25 256 656 1 0.7 011 18WE0465 Condensate Tanks-Train 2 122 338 25 256 656 1 0.7 012 18WE0465 Condensate Loadout 270 748 56 565 1452 1 1.5 013 18WE0465 Pressurized Unloading of Condensate 163 161 51 1364 51 014 18WE0465 Process Flare-Train 1 &Bypass 15 7 2 348 1 015 18WE0465 Process Flare-Train 2 10 5 1 229 1 016 18WE0465 Fugitives(Train 1,2&Bypass) 84 41 10 1951 2 017 18WE0465 Methanol Tank 1235 018 18WE0466.XP Produced Water Tanks 315 990 TOTAL(tpy) 0.1 0.0 0.0 0.9 1.0 0.1 0.7 5.5 0.6 0.0 _ 0.0 0.0 8.8 65 18WE0465.CP1.xlsm 11/5/2018 do :*-11 qiilut, Co , rot Division DFpa r nt c Public I I n S Environment c. CONSTRUCTION PERMIT Permit number: 18WE0465 Issuance: 1 Date issued: Issued to: DCP Operating Company, LP Facility Name: Bighorn Gas Plant Plant AIRS ID: 123/9FBB Physical Location: Section 2, Township 3N, Range 65W County: Weld County General Description: Natural Gas Processing Plant Equipment or activity subject to this permit: Facility AIRS Equipment Point Equipment Description Emissions Control Description ID One (1) Triethylene glycol (TEG) natural The still vent and flash tank gas dehydration unit (Make: TBD, Model: streams are recycled to the plant TBD, Serial Number: TBD) with a design inlet via dedicated Vapor capacity of 365 MMscf per day. This Recovery Units (VRUs). emissions unit is equipped with two (2) During VRU downtime, still vent (Make: TBD, Model: TBD) electric driven emissions are routed to an air glycol pumps with a design capacity of 60 cooled condenser and then to D-01 001 gallons per minute (one (1) primary pump and one (1) backup). This dehydration the plant flare (Point 014). unit is equipped with a still vent and flash During VRU downtime, flash tank tank. This equipment is used for processing emissions are routed directly to Train 1. the plant flare (Point 014). The flash tank VRU has a maximum of 2% annual downtime. The still vent VRU has a maximum of 2% annual downtime. COP COLORADO �+ z Air Pollution Control Division Page 1 of 33 441 A ;f4 The still vent and flash tank streams are recycled to the plant 09'e (1) rieth4ne glcol (TEG) tural inlet via dedicated Vapor .w., �. �..__. -ga,90)y. rai9Rmi• 7ce: TBD, et: Recovery Units (VRUs). TBD, Serial Number: TBD) with a design capacity of 365 MMscf per day. This During VRU downtime, still vent emissions unit is equipped with two (2) emissions are routed to an air- D-02 002 (Make: TBD, Model: TBD) electric driven cooled condenser and then to glycol pumps with a design capacity of 60 the plant flare (Point 015). gallons per minute (one (1) primary pump During VRU downtime, flash tank and one (1) backup). This dehydration unit emissions are routed directly to is equipped with a still vent and flash tank. the plant flare (Point 015). The This equipment is used for processing Train flash tank VRU has a maximum of 2. 2% annual downtime. The still vent VRU has a maximum of 2% annual downtime. The still vent and flash tank streams are recycled to the plant One (1) Triethylene glycol (TEG) natural inlet via dedicated Vapor gas dehydration unit (Make: TBD, Model: Recovery Units (VRUs). TBD, Serial Number: TBD) with a design capacity of 230 MMscf per day. This During VRU downtime, still vent emissions unit is equipped with two (2) emissions are routed to an air- (Make: TBD, Model: TBD) electric driven cooled condenser and then to D-03 003 glycol pumps with a design capacity of 40 the plant flare (Point 014). gallons per minute (one (1) primary pump During VRU downtime, flash tank and one (1) backup). This dehydration unit emissions are routed directly to is equipped with a still vent and flash tank. the plant flare (Point 014). The This equipment is used for processing gas flash tank VRU has a maximum of that bypasses Train 1 and Train 2. 2% annual downtime. The still vent VRU has a maximum of 2% annual downtime. One (1) natural gas heater (Manufacturer: Tulsa Heaters Midstream, Model: SH01250, Serial Number: TBD) with a design heat H-1741 004 input rate of 23.33 MMBtu/hr. This unit is None equipped with low-NOx burners. This unit is used as a molecular sieve regeneration heater. One (1) natural gas fired heater (Manufacturer: Tulsa Heaters Midstream, Model: 5H01250, Serial Number: TBD) with H-2741 005 a design heat input rate of 23.33 None MMBtu/hr. This unit is equipped with low- NOx burners. This unit is used as a molecular sieve regeneration heater. One (1) natural gas fired heater (Manufacturer: Heatec, Model: HCI-18010- H-19000 006 50-Q-G, Serial Number: TBD) with a design None heat input rate of 25 MMBtu/hr. The unit is equipped with low-NOx burners. This unit DP COLORADO COLORADO jsv Air Pollution Control Division Page 2 of 33 TWT je sed as h0 oil h or the! ndensate ilizer 0 1 atura s fi heater (Mann acturer: eatec, odel: FtCI 18010- 50-Q-G, Serial Number: TBD) with a design H-29000 007 heat input rate of 25 MMBtu/hr. The unit is None equipped with low-NOx burners. This unit is used as a hot oil heater for the condensate stabilizer. One (1) natural gas fired heater (Manufacturer: Tulsa Heaters Midstream, Model: SHO4000, Serial Number: TBD) each H-1781 008 with a design heat input rate of 53.93 None MMBtu/hr. This unit is equipped with "ultra low-NOx burners".This unit is used as a hot oil heater for the demethanizer. One (1) natural gas fired heater (Manufacturer: Tulsa Heaters Midstream, Model: SHO4000, Serial Number: TBD) each H-2781 009 with a design heat input rate of 53.93 None MMBtu/hr. This unit is equipped with "ultra low-NOx burners".This unit is used as a hot oil heater for the demethanizer. Four (4) 1,000 barrel fixed roof condensate TANKS-1 010 storage vessels connected via liquid Enclosed Combustor. manifold. Tanks store stabilized condensate. Four (4) 1,000 barrel fixed roof condensate TANKS-2 011 storage vessels connected via liquid Enclosed Combustor. manifold. Tanks store stabilized condensate. LO 012 Loadout of stabilized natural gas Enclosed Combustor. condensate to tank trucks. Unloading of unstabilized condensate from pressurized tank trucks to pressurized UL 013 condensate feed tanks using vapor None balance. Emissions are result of gas that is vented during hose disconnect. One (1) open flare (Make: TBD, Model: TBD, SN: TBD) used to control emissions for blowdowns, maintenance, and FLARE-1 014 malfunctions for "Train 1". This open flare Open Flare also controls emissions from Points 001 (D- 01) and 003 (D-03) during vapor recovery unit (VRU) downtime. eis, COLORADO CO Air Pollution Control Division c << Page 3 of 33 "A z AA c- ne (1) o en'flare (M*�'TBD, Me"del: D, SN ,TE sed to control emts `B ions for FLARE 2 01 blowdoviis, m'ateni ce and ma nctions Open Flare *.,<_4.*m gazArd for!4Train 2"._zTh flare aisticontrols emissions from Point 002 (D-02) during vapor recovery unit (VRU) downtime. Fugitive emissions from components FUG 016 associated with "Train 1", "Train 2" and None "Plant Bypass". METHANOL 017 Two (2) 400 barrel fixed roof storage None vessels used to store methanol. 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. Point 001, 002, 003: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • The dehydrator manufacturer name, model number and serial number • The glycol circulation pump manufacturer name and model number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation Number 3, Part B, III.E.) ,t,„ ece COLORADO Air Pollution Control Division '` Page 4 of 33 , 6. oint 0€4, O6, 007 0arirri N 009: es ollowi iinformation shall be provided to the Division ithin fi tee f l days o he titter aicornmenc lent of operation or issuance of this permit. k4 ;''ma fac er • m urb • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation Number 3, Part B, III.E.) 7. 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 8. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) • Monthly Limits: Facility Pounds per Month Emission ui ment ID AIRS Point E Type Equipment PM2.5 NO, CO yP H-1741 004 --- 579 --- 972 Point H-2741 005 --- 579 --- 972 Point H-19000 006 --- 886 --- 1488 Point H-29000 007 --- 886 --- 1488 Point H-1781 008 --- 1365 211 3210 Point H-2781 ' 009 --- 1365 211 3210 Point TANKS-1 010 --- --- 780 --- Point TANKS-2 011 --- --- 780 --- Point UL 012 --- --- 1435 --- Point FUG 016 --- --- 7445 --- Fugitive Note: Monthly limits are based on a 31-day month. The owner or operator shall calculate monthly emissions based on the calendar month. Facility-wide emissions of each individual hazardous air pollutant shall not exceed 1,359 pounds per month. Facility-wide emissions of total hazardous air pollutants shall not exceed 3,398 pounds per month. The facility-wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. jok cnr: COLORADO co 0 As Pollution Control Division Page 5 of 33 a tnnuaIt1mi1fr 0 J Eons per Year Emission IAIRS�Point i Eqcfill mID P VOC CO Type D-01 001 --- --- 1.5 --- Point D-02 002 --- --- 1.5 --- Point D-03 003 --- --- 1.0 --- Point H-1741 004 -- 3.5 --- 5.8 Point H-2741 005 --- 3.5 --- 5.8 Point H-19000 006 --- 5.3 --- 8.8 Point H-29000 007 --- 5.3 --- 8.8 Point H-1781 008 1.3 8.1 1.3 18.9 Point H-2781 009 1.3 8.1 1.3 18.9 Point TANKS-1 010 --- --- 4.6 2.5 Point TANKS-2 011 --- --- 4.6 --- Point LO 012 --- --- 10.2 --- Point UL 013 --- --- 8.5 --- Point FLARE-1 014 --- 1.8 17.8 7.7 Point FLARE-2 015 1.3 11.8 5.7 Point FUG 016 --- --- 43.9 --- Fugitive Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility-wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility-wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual limits, for criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. DA COLORADO CO Air Pollution Control Division �•. �., �, Page 6 of 33 aim 9. kPoint , 0 , `3: Cord(i ce wit e emissi' limits in this permit shall be demonstrated Eby runng t 1 GlyCal4,1 el versa n 4.0 or hig er on a monthly basis using the most recent Ixtended w g � analiis a recojded opera j nal values, including: dehydrator inlet or el-4 tor oltlet as rough t Ana glycol r irculation rate, vapor recovery unit (VRU) tbwntime, s tan empera ure°an pressure; wet gas inlet temperature, and wet gas inlet pressure. The volume of gas throughput measured using a flow meter at either the inlet or outlet of the dehydrator shall be considered equal to the "Dry Gas Flow Rate" for purposes of the GRI GlyCalc model. Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into the model and be provided to the Division upon request. 10. Point 001, 002, 003: On a weekly basis, the owner or operator shall monitor and record operational values including: vapor recovery unit (VRU) downtime, flash tank temperature and pressure, wet gas inlet temperature and pressure. These records shall be maintained for a period of five years. 11. Point 016: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent extended gas analysis, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. 12. The owner or operator shall operate and maintain the emission points in the table below with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility AIRS Control Device Pollutants Equipment ID Point Controlled Still Vent: Open Flare (during still vent VRU VOC and downtime - up to 2%annually) HAP D-01 001 Flash Tank: Open Flare (during flash tank VRU VOC and downtime- up to 2%annually) HAP Still Vent: Open Flare (during still vent VRU VOC and downtime- up to 2%annually) HAP D-02 002 Flash Tank: Open Flare (during flash tank VRU VOC and downtime - up to 2%annually) HAP Still Vent: Open Flare (during still vent VRU VOC and downtime- up to 2%annually) HAP D-03 003 Flash Tank: Open Flare (during flash tank VRU VOC and downtime- up to 2%annually) HAP TANKS-1 010 Enclosed Combustor VOC and HAP TANKS-2 011 Enclosed Combustor VOC and HAP LO 012 Enclosed Combustor VOC and HAP 13. Point 001, 002, 003: Except during periods of VRU downtime, the owner or operator shall operate and maintain these emission points as a closed loop system and shall recycle 100% of emissions (Regulation Number 3, Part B, Section III.E.) 71 COLORADO COLORADO CO G Air Pollution Control Division Page 7 of 33 tea . 741,71, r 1 I 14. Point O4, 15 ,missions malt enance act ities and purge gas shall be collected and fcontr i d b flake in p der t edu the emissions of volatile organic compounds to the level tis n this�stior`„.a. e. _- PROCESS LIMITATIONS AND RECORDS 15. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility AIRS Monthly Limit Equipment Point Process Parameter Annual Limit (31 days) ID Gas Throughput 133,225.00 MMscf 11,315.00 MMscf Gas Throughput During D-01 001 Still Vent VRU 2,664.50 MMscf --- downtime Gas Throughput During Flash Tank VRU 2,664.50 MMscf --- downtime Gas Throughput 133,225.00 MMscf 11,315.00 MMscf Gas Throughput During Still Vent VRU 2,664.50 MMscf --- D-02 002 downtime Gas Throughput During Flash Tank VRU 2,664.50 MMscf --- downtime Gas Throughput 83,950.00 MMscf 7,130.00 MMscf Gas Throughput During Still Vent VRU 1,679.00 MMscf --- D-03 003 downtime Gas Throughput During Flash Tank VRU 1,679.00 MMscf --- downtime H-1741 004 Consumption of Natural 136.25 MMscf 11.60 MMscf Gas as Fuel H-2741 005 Consumption of Natural 136.25 MMscf 11.60 MMscf Gas as Fuel H-19000 006 Consumption of Natural 208.57 MMscf 17.72 MMscf Gas as Fuel H-29000 007 Consumption of Natural 208.57 MMscf 17.72 MMscf Gas as Fuel H-1781 008 Consumption of Natural 449.93 MMscf 38.22 MMscf Gas as Fuel H-2781 009 Consumption of Natural 449.93 MMscf 38.22 MMscf Gas.as Fuel enrHE COLORADO CO Au iv Pollution Control B ,s on Page 8 of 33 Fa lit IR$ At- Monthly Limit Equt me / I&ess Patar>;eter Annual Limit Au Point (31 days) ...; ou ut of vaLaav Stabs ized ondensate 1,971,000 barrels 167,400 barrels TANKS-1 010 Combustion of Assist Gas in Enclosed 10.51 MMscf Combustor TANKS-2 011 Throughput of 1,971,000 barrels 167,400 barrels Stabilized Condensate LO 012 Throughput of 2,007,500 barrels --- Stabilized Condensate UL 013 Pressurized Unloading 8,760 loads 730 loads Events Combustion of maintenance gas and 37.13 MMscf FLARE-1 014* purge gas Combustion of pilot 1.71 MMscf fuel Combustion of maintenance gas and 28.13 MMscf FLARE-2 015* purge gas Combustion of pilot 1.71 MMscf fuel METHANOL 017 Throughput of 9,600 barrels Methanol *Note: This flare will handle gas from maintenance events and blowdowns, as well as gas from glycol dehydrators (Point 001, 002 Et 003) during primary control device downtime. In addition, gas will be routed to this flare during any events that qualify as a malfunction per Common Provisions, Section II.E. The owner or operator shall monitor monthly process rates based on the calendar month. During the first twelve (12) months of operation, compliance with both the monthly and annual throughput limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 16. Point 001, 002: The owner or operator shall continuously monitor and record the volume of gas throughput to this dehydrator using an operational continuous flow meter at either the inlet or the outlet of the dehydrator. 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. During flow meter downtime, a gas throughput of 365 MMscf/day shall be assumed until the flow meter is repaired and/or operational. 17. Point 003: The owner or operator shall continuously monitor and record the volume of gas throughput to this dehydrator using an operational continuous flow meter at either the inlet or the outlet of the dehydrator. 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. During flow meter downtime, a gas throughput of 230 MMscf/day shall be assumed until the flow meter is repaired and/or operational. 18. Point 001, 002: This unit shall be limited to the maximum lean glycol circulation rate of 60 gallons per minute. The lean glycol recirculation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. Glycol recirculation rate DPKE' COLORADO IA CO "vcr Air Pollution Control Division Page 9 of 33 a . a Y shall b4lhoIPy one 6f - folio ng nethodi assuming maximum design pump rate, using lycol mw rile'-'144s), or ri cor„In st ke per minute and converting to circulation rate. This axim;� gigot culati n rat dloes t preclude ompliance with the optimal glycol circulation fate ( Pt) prritvisiorts under MACtHH (Reference'≥ Regulation Number 3, Part B, II.A.4) 19. Point 003: This unit shall be limited to the maximum lean glycol circulation rate of 40 gallons per minute. The lean glycol recirculation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. Glycol recirculation rate shall be monitored by one of the following methods: assuming maximum design pump rate, using glycol flow meter(s), or recording strokes per minute and converting to circulation rate. This maximum glycol circulation rate does not preclude compliance with the optimal glycol circulation rate (loot) provisions under MACT HH. (Reference: Regulation Number 3, Part B, II.A.4) 20. Point 001, 002, 003: The owner or operator shall monitor and record still vent vapor recovery unit (VRU) downtime on a daily basis. Still vent VRU downtime shall be defined as times when the waste gas vented from the dehydrator still vent is routed to the open flare rather than the VRU. The total hours of still vent VRU downtime and gas throughput to the dehydrator during still vent VRU downtime shall be recorded on a monthly basis. The owner or operator shall demonstrate that gas throughput to the dehydrator during still vent VRU downtime does not exceed two percent (2%) of the total gas throughput to the dehydrator on a rolling twelve (12) month total basis. 21. Point 001, 002, 003: The owner or operator shall monitor and record flash tank vapor recovery unit (VRU) downtime on a daily basis. Flash tank VRU downtime shall be defined as times when the waste gas vented from the dehydrator flash tank vent is routed to the open flare rather than the VRU. The total hours of flash tank VRU downtime and gas throughput to the dehydrator during flash tank VRU downtime shall be recorded on a monthly basis. The owner or operator shall demonstrate that gas throughput to the dehydrator during flash tank VRU downtime does not exceed two percent (2%) of the total gas throughput to the dehydrator on a rolling twelve (12) month total basis. 22. Point 004, 005, 006, 007, 008, 009: The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas combusted as fuel for each heater using an operational continuous flow meter at the inlet. 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. 23. Point 014: The owner or operator shall continuously monitor and record the volumetric flow rate of process gas and purge gas routed to the flare using flow meters. Each header to the flare, including but not limited to, the cold flare header and warm flare header, shall be equipped with a meter. While the flare is operational, a purge gas flow rate of 290 scfh for each warm flare header and 980 scfh for each cold flare header shall be assumed at all times that the metered volume is below the detection level of the meter. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. Compliance shall be demonstrated based on the sum of all inlets to the flare. 24. Point 015: The owner or operator shall continuously monitor and record the volumetric flow rate of process gas and purge gas routed to the flare using flow meters. Each header to the flare, including but not limited to, the cold flare header and warm flare header, shall be equipped with a meter. While the flare is operational, a purge gas flow rate of 290 scfh for each warm flare header and 980 scfh for each cold flare header shall be assumed at all times that the metered volume is below the detection level of the meter. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. Compliance shall be demonstrated based on the sum of all inlets to the flare. COPHE COLORADO cc s, Air Pollution Control Divas on �# Page 10 of 33 c /* I -0 STATE ND FE ,ERAVRELATO ' QUIREMENS 25 he petit m r and n"! 't AIR ID 12umber assigned by the Division (e.g. 123/4567/001) hall mar d o? he st jecte uip nt for eas ' f identification. (Regulation Number 3, Part E .Sc lion ( ,qtly en eal ,e) ,.---7.2.2-m, 26. No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Regulation Number 1, Section II.A.5.) 27. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Reference: Regulation Number 1, Section II.A.1. Et 4.) 28. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) TEG Glycol Dehydrators 29. Point 001, 002, 003: This source is subject to Regulation Number 7, Section XII.H. The operator shall comply with all applicable requirements of Section XII and, specifically, shall: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for glycol natural gas dehydrators; and • Ensure uncontrolled actual emissions of volatile organic compounds from the still vent and vent from any gas-condensate-glycol(GCG)separator(flash separator or flash tank), if present, shall be reduced by at least 90 percent on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. (Regulation Number 7, Section XII.H.1.) 30. Point 001, 002, 003, 014, 015: The open flare covered by this permit has been approved as an alternative emissions control device under Regulation Number 7, Section XVII.B.2.e. The open flare must have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.17, and be designed so that an observer can, by means of visual observation from the outside of the open flare, or by other convenient means approved by the Division, determine whether it is operating properly. This open flare must be equipped with an operational auto-igniter upon installation of the combustion device. 31. Point 001, 002, 003: The glycol dehydration unit covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.D.3. Beginning May 1, 2015, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas-processing plant subject to control requirements pursuant to Section XVII.D.4., shall reduce uncontrolled actual emissions of hydrocarbons by at least 95% on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. 32. Point 001, 002, 003: The glycol dehydration unit at this facility is subject to National Emissions Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities, Subpart HH. This facility shall be subject to applicable area source provisions of this regulation, as stated in 40 C.F.R Part 63, Subpart A and HH. (Regulation Number 8, Part E, Subpart A and HH) 4, DA, COLORADO CO Air Pollution Control Division Page 11 of 33 i , �' E MA HH A he 4rea Source ezerA €equireen74. 84enzen-' missions exemption ,._,._._. ''§835164 (e}( wner o operator is exempt from the requirements of paragraph (d) of this section if the criteria listed in paragraph (e)(1)(i) or (ii) of this section are met, except that the records of the determination of §63.764 - General these criteria must be maintained as required in §63.774(d)(1). Standards §63.764 (e)(1)(ii) -The actual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere are less than 0.90 megagram per year, as determined by the procedures specified in §63.772(b)(2) of this subpart. §63.772(b) - Determination of glycol dehydration unit flowrate or benzene emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate or benzene emissions to meet the criteria for an exemption from control requirements under§63.764(e)(1). §63.772(b)(2) -The determination of actual average benzene emissions from a glycol dehydration unit shall be made using the procedures of either paragraph (b)(2)(i) or (b)(2)(ii) of this section. Emissions shall be determined either uncontrolled, or with federally enforceable controls in place. §63.772 -Test §63.772(b)(2)(i) -The owner or operator shall determine actual average Methods, Compliance benzene emissions using the model GRI-GLYCaIc TM, Version 3.0 or higher, Procedures and and the procedures presented in the associated GRI-GLYCaIc TM Technical Compliance Reference Manual. Inputs to the model shall be representative of actual Demonstration operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI-95/0368.1); or §63.772(b)(2)(ii) -The owner or operator shall determine an average mass rate of benzene emissions in kilograms per hour through direct measurement using the methods in §63.772(a)(1)(i) or (ii), or an alternative method according to§63.7(f). Annual emissions in kilograms per year shall be determined by multiplying the mass rate by the number of hours the unit is operated per year. This result shall be converted to megagrams per year. §63.774 (d)(1) -An owner or operator of a glycol dehydration unit that meets the exemption criteria in §63.764(e)(1)(i) or§63.764(e)(1)(ii) shall maintain the records specified in paragraph (d)(1)(i) or paragraph (d)(1)(ii) §63.774 - of this section, as appropriate, for that glycol dehydration unit. Recordkeeping Requirements §63.774 (d)(1)(ii) -The actual average benzene emissions (in terms of benzene emissions per year) as determined in accordance with §63.772(b)(2). Heaters 33. Point 004, 005, 006, 007, 008, 009: These sources are subject to the New Source Performance Standards requirements of Regulation Number 6, Part A Subpart Dc, Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units including, but not limited to, the following: a. The owner or operator of the facility shall record and maintain records of the amount of fuel combusted during each month (40 CFR Part 60.48c(g)). CDP Eie COLORADO COw Air Pollution Control Division V Page 12 of 33 n$ Al A on Aaords cif fuel coJI sted regtj red under the previous condition shall be .tnairl . ' by theowher or o. eraor of the facility for a period of two years following he p to such '"ecor 40 CT Part 60.48 (i)). mat Conderisa e Storage's arks 34. Point 010, 011: 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. 35. Point 010, 011: 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. 36. Point 010, 011: This source is subject to the New Source Performance Standards, Standards of Performance for Volatile Organic Liquid Storage Vessels for which construction, reconstruction or modification commenced after July 23, 1984, Subpart Kb. This facility shall be subject to all provisions of this regulation, as stated in 40 C.F.R Part 60, Subparts A and Kb. (Regulation Number 6, Part A, Subparts A and Kb) 37. Point 010, 011: This source is subject to the New Source Performance Standards requirements of Regulation Number 6, Part A, Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels for which construction, reconstruction or modification commenced after July 23, 1984, including, but not limited to, the following (Regulation Number 6, Subparts A and Kb): • 40 CFR, Part 60, Subpart A - General Provisions • $60.112b- Standard for volatile organic compounds (VOC) o $60.112b(a) The owner or operator of each storage vessel with a....design capacity greater than or equal to 151 m3 containing a VOL that, as stored, has a maximum true vapor pressure equal to or greater than 5.2 kPa but less than 76.6 kPa, shall equip each storage vessel with one of the following: ■ $60.112b(a)(3) A closed vent system and control device meeting the following specifications: • $60.112b(a)(3)(i)The closed vent system shall be designed to collect all VOC vapors and gases discharged from the storage vessel and operated with no detectable emissions as indicated by an instrument reading of less than 500 ppm above background and visual inspections, as determined in part 60, subpart VV, §60.485(b). • $60.112b(a)(3)(ii)The control device shall be designed and operated to reduce inlet VOC emissions by 95 percent or greater. If a flare is used as the control device, it shall meet the specifications described in the general control device requirements (§60.18) of the General Provisions. COPE COLORADO T t CO ;o- Air Pollution Control Division Page 13 of 33 d - o —',.S60.1I Testi a prod, es The owner or operator of each storage vessel as specified in §60.112b(a) shall meet the requirements of paragraph (a), (b), or (c) of this section. The applicable paragraph for a particular storage vessel depends on the control equipment installed to meet the requirements of§60.112b. • §60.113b(c)The owner or operator of each source that is equipped with a closed vent system and control device as required in §60.112b (a)(3) or (b)(2) (other than a flare) is exempt from §60.8 of the General Provisions and shall meet the following requirements. • §60.113b(c)(1) Submit for approval by the Administrator as an attachment to the notification required by §60.7(a)(1) or, if the facility is exempt from §60.7(a)(1), as an attachment to the notification required by §60.7(a)(2), an operating plan containing the information listed [in §60.113b(c)(1)(i) and §60.113b(c)(1)(ii)]. • §60.113b(c)(2) Operate the closed vent system and control device and monitor the parameters of the closed vent system and control device in accordance with the operating plan submitted to the Administrator in accordance with paragraph (c)(1) of this section, unless the plan was modified by the Administrator during the review process. In this case, the modified plan applies. o §60.115b- Reporting and recordkeeping requirements • $60.115b(c) After installing control equipment in accordance with §60.112b (a)(3) or (b)(1) (closed vent system and control device other than a flare), the owner or operator shall keep the following records. • §60.115b(c)(1) A copy of the operating plan. • §60.115b(c)(2)A record of the measured values of the parameters monitored in accordance with §60.113b(c)(2). o §60.116b - Monitoring of operations • §60.116b(a) The owner or operator shall keep copies of all records required by this section, except for the record required by paragraph (b) of this section, for at least 2 years. The record required by paragraph (b) of this section will be kept for the life of the source. • §60.116b(b) The owner or operator of each storage vessel as specified in §60.110b(a) shall keep readily accessible records showing the dimension of the storage vessel and an analysis showing the capacity of the storage vessel. • §60.116b(g) The owner or operator of each vessel equipped with a closed vent system and control device meeting the specification of §60.112b or with emissions reductions equipment as specified in 40 CFR 65.42(b)(4), (b)(5), (b)(6), or (c) is exempt from the requirements of paragraphs (c) and (d) of this section Loadout of Stabilized Condensate and UntoadinR of Pressurized Condensate 38. Point 012, 013: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable (Reference: Regulation 3, Part B, III.E). caPE COLORADO > Air Pollution Control Division Page 14 of 33 afi,� , m Vi 39 oint 0 1e cOner or cpetator sh allow loading procedures that minimize the leakage of OCs to°the aisphere including, bu ,no limited4 o (Reference: Regulation 3, Part B, III.E): The ne(•-�or o erato hall. spect onset loading equipment to ensure that hoses, -�' coup s, .eves. rnal wined tolirevent dripping, leaking, or other liquid or vapor loss during loading and unloading. The inspections shall occur at least monthly. Each inspection shalt be documented in a log available to the Division on request. b. All compartment hatches at the facility (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. Inspect thief hatch seats annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. d. 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 not vented through the PRD under normal operating conditions. e. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. f. Install and operate vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. g. Include devices to prevent the release of vapor from vapor recovery hoses not in use. h. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. i. Operate all recovery and disposal equipment at a back-pressure less than the pressure of the relieve valve setting of transport vehicles. 40. Point 013: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Regulation Number 3, Part B, Section III.E.): a. 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. b. 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 vapors are not vented through the PRD under normal operating conditions. c. Document annual inspections of the PRD with an indication of status, a description of any problems found, and their resolution. d. Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. e. Include devices to prevent the release of vapor from vapor recovery hoses not in use. f. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. "HE COLORADO At 1( Air Pollution Control Dwision Page 15 of 33 ba � g 774 e te irecov lty ataxm and disprts l equipm t at a back-pressure less than the pressure deli ,vatve setting of,transpo ve icles # Plant Flare 41. Point 014, 015: This flare shall comply with the New Source Performance Standards requirements of Subpart A Section §60.18, General Control Device and Work Practice Requirements, including, but not limited to, the following: • §60.18(b) Flares. Paragraphs (c) through (f) apply to flares. • $60.18(c)(1) Flares shall be designed for and operated with no visible emissions as determined by the methods specified in paragraph (f), except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. • §60.18(c)(2) Flares shall be operated with a flame present at all times, as determined by the methods specified in paragraph (f). • §60.18(c)(3) An owner/operator has the choice of adhering to either the heat content specifications in paragraph (c)(3)(ii) of this section and the maximum tip velocity specifications in paragraph (c)(4) of this section, or adhering to the requirements in paragraph (c)(3)(i) of this section. o $60.18(c)(3)(i)(A) Flares shall be used that have a diameter of 3 inches or greater, are non-assisted, have a hydrogen content of 8.0 percent (by volume), or greater, and are designed for and operated with an exit velocity less than 37.2 m/sec (122 ft/sec) and less than the velocity, Vmax, as determined by the following equation: Vmax = (XH2-K1)" K2 Where: Vmax = Maximum permitted velocity, m/sec. K1 = Constant, 6.0 volume-percent hydrogen. K2 = Constant, 3.9(m/sec)/volume-percent hydrogen. XH2 = The volume-percent of hydrogen, on a wet basis, as calculated by using the American Society for Testing and Materials (ASTM) Method D1946-77. (Incorporated by reference as specified in $60.17). o §60.18(c)(3)(i)(B) The actual exit velocity of a flare shall be determined by the method specified in paragraph (f)(4) of this section. o §60.18(c)(3)(ii) Flares shall be used only with the net heating value of the gas being combusted being 11.2 MJ/scm (300 Btu/scf) or greater if the flare is steam-assisted or air-assisted; or with the net heating value of the gas being combusted being 7.45 MJ/scm (200 Btu/scf) or greater if the flare is nonassisted. The net heating value of the gas being combusted shall be determined by the methods specified in paragraph (f)(3) of this section. • §60.18(c)(5)Air-assisted flares shall be designed and operated with an exit velocity less than the velocity, Vmax, as determined by the method specified in paragraph (f)(6). • §60.18(c)(6) Flares used to comply with this section shall be steam-assisted, air-assisted, or nonassisted. • §60.18(d) Owners or operators of flares used to comply with the provisions of this subpart shall monitor these control devices to ensure that they are operated and maintained in conformance with their designs. Applicable subparts will provide provisions stating how owners or operators of flares shall monitor these control devices. • §60.18(e) Flares used to comply with provisions of this subpart shall be operated at all times when emissions may be vented to them. le COLORADO CO Cf Air Poltutsan Control Bivssson Page 16 of 33 1 ,i mgr ;. _x a r' Ko §6 " 8( )Method 2 ofF ppend1 o this pit shall be used to determine the compliance of flares 'it*the visit ,ssion provisions of:I is subpart. The observation period is 2 hours anc. hal e used ac rdin to Me, od 22. t fp §60.1842) T fs..-. ncez fth- pilot flaniershall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame. • 560.18(f)(3) The net heating value of the gas being combusted in a flare shall be calculated using the following equation: r) NT . K Z CHI f=1 Where: HT = Net heating value of the sample, MJ/scm; where the net enthalpy per mole of offgas is based on combustion at 25 °C and 760 mm Hg, but the standard temperature for determining the volume corresponding to one mole is 20 °C; K = Constant, _} 1 9 mole) tfi.] 1.740 x 10 1ppm" scm ) cEFiT, where the standard temperature for fq mole) is 20"C; 1 scm Ci = Concentration of sample component i in ppm on a wet basis, as measured for organics by Reference Method 18 and measured for hydrogen and carbon monoxide by ASTM D1946-77 or 90 (Reapproved 1994) (Incorporated by reference as specified in §60.17); and Hi = Net heat of combustion of sample component i, kcal/g mole at 25 °C and 760 mm Hg. The heats of combustion may be determined using ASTM D2382-76 or 88 or D4809-95 (incorporated by reference as specified in §60.17) if published values are not available or cannot be calculated. • §60.18(f)(4)The actual exit velocity of a flare shall be determined by dividing the volumetric flowrate (in units of standard temperature and pressure), as determined by Reference Methods 2, 2A, 2C, or 2D as appropriate; by the unobstructed (free) cross sectional area of the flare tip. • §60.18(f)(5) The maximum permitted velocity, Vmax, for flares complying with paragraph (c)(4)(iii) shall be determined by the following equation. Log10 (Vmax)=(HT+28.8)/31.7 Vmax = Maximum permitted velocity, M/sec 28.8=Constant 31.7=Constant HT = The net heating value as determined in paragraph (f)(3). §60.18(f)(6) The maximum permitted velocity, Vmax, for air-assisted flares shall be determined by the following equation. Vmax = 8.706+0.7084 (HT) Vmax = Maximum permitted velocity, m/sec 8.706=Constant 0.7084=Constant HT = The net heating value as determined in paragraph (f)(3). Fugitive Emissions 42. Point 016: This source is subject to Regulation No. 7, Section XII.G.1 (State only enforceable). For fugitive V0C emissions from leaking equipment, the leak detection and repair(LDAR) program as provided at 40 CFR Part 60, Subpart 0000 (July 1, 2017) applies, regardless of the date of cOP COLORADO CO Air Pollution Control Division Page 17 of 33 9 onstr ion f affected *ility, 4jss subjecto the LDAR program provided at 40 CFR Part b0, Sub rt 61300,a, (July , 20 ).The .petator shall comply with all applicable requirements of echo I I y� ZA '. � Requirements Covering`Multipre Sources 43. Point 004, 005, 006, 007, 008, 009: These sources are subject to the Particulate Matter and Sulfur Dioxide Emission Regulations of Regulation 1, and the New Source Performance Standards requirements of Regulation 6, Part B, including, but not limited to, the following: a. No owner or operator shall cause or permit to be emitted into the atmosphere from any fuel-burning equipment, particulate matter in the flue gases which exceeds the following (Regulation 1, Section III.A.1 and Regulation 6, Part B, Section II): (1) For fuel burning equipment with designed heat inputs greater than 1x106 BTU per hour, but less than or equal to 250x106 BTU per hour heat input, the following equation will be used to determine the allowable particulate emission limitation. PE = 0.5(FI).0.26 Where: PE = Particulate Emission in Pounds per million BTU heat input. Fl = Fuel Input in Million BTU per hour b. Greater than 20 percent opacity. (Regulation 6, Part B, II.C.3) 44. Point 004, 005, 006, 007, 008, 009, 010, 011, 014, 015, 016: These sources are subject to the requirements of Regulation Number 6, Part A, Subpart A, General Provisions, including, but not limited to, the following: a. At all times, including periods of start-up, shutdown, and malfunction, the facility and control equipment shall, to the extent practicable, be maintained and operated in a manner consistent with good air pollution control practices for minimizing emissions. Determination of whether or not acceptable operating and maintenance procedures are being used will be based on information available to the Division, which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. (Reference: Regulation 6, Part A. General Provisions from 40 CFR 60.11(d)) b. No article, machine, equipment or process shall be used to conceal an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in the gases discharged to the atmosphere. (§60.12) c. Written notification of construction and initial startup dates shall be submitted to the Division as required under §60.7. d. Records of startups, shutdowns, and malfunctions shall be maintained, as required under §60.7. e. Written notification of opacity observation or monitor demonstrations shall be submitted to the Division as required under § 60.7. f. Excess Emission and Monitoring System Performance Reports shall be submitted as required under§ 60.7. g. Performance tests shall be conducted as required under§60.8. h. Compliance with opacity standards shall be demonstrated according to § 60.11. CDPHE COLORADO C�+h �0, Aix Pollution Control Division CO Page 18 of 33 z VA te f =hall be ces≥ ed a gyrated, rd records and reports shall be furnished, as q "e` ,nder§ 45 his s_, rce 1� loc d inan ozo� no attainmen ,r attainment-maintenance area and subject i Reas ly iaf le rol nologylf#ACT) requirements of Regulation Number 3, Part B, III.D.2.b. The following requirements were determined to be RACT for this source: Facility AIRS RACT Pollutants Equipment ID - Point Still Vent: Recycled to Plant Inlet via VRU. Routed to open flare during VRU downtime. D-01 001 VOC Flash Tank: Recycled to Plant Inlet with a VRU. Routed to open flare during VRU downtime. Still Vent: Recycled to Plant Inlet via VRU. Routed to open flare during VRU downtime. D-02 002 VOC Flash Tank: Recycled to Plant Inlet with a VRU. Routed to open flare during VRU downtime. Still Vent: Recycled to Plant Inlet via VRU. Routed to open flare during VRU downtime. D-03 003 VOC Flash Tank: Recycled to Plant Inlet with a VRU. Routed to open flare during VRU downtime. H-1741 004 Natural gas as fuel, low NOx burners, good NOx, VOC combustion practices H-2741 005 Natural gas as fuel, low NOx burners, good NOx, VOC combustion practices H-19000 006 Natural gas as fuel, low NOx burners, good NOx, VOC combustion practices H-29000 007 Natural gas as fuel, low NOx burners, good NOx, VOC combustion practices H-1781 008 Natural gas as fuel, ultra low NOx burners, good NOx, VOC combustion practices H 2781 009 Natural gas as fuel, ultra low NOx burners, good NOx, VOC combustion practices TANKS-1 010 Enclosed Combustor VOC TANKS-2 011 Enclosed Combustor VOC LO 012 Submerged Fill, Enclosed Combustor VOC UL 013 Unloading using pressurized vessels and vapor VOC balance FUG 016 LDAR as provided at 40 CFR Part 60 Subpart 0000a VOC t COLORADO CO a =Air Pollution Control Divis"ton Page 19 of 33 vi OPERA"NG Et MAINTENANCE RE IREMENTS , a 46. Point OO1, (V2,1.403, 0 , , 014 01'4, 015 uUpon startup of these points, the owner or vperatd shag follow the frost r4ent berating an ?maintenance (O&M) plan and record keeping mat apps bV.I.he Divisi reder to dembstrate 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 47. Point 001, 002, 003: The owner or operator shall complete the initial extended wet gas analysis within one hundred-and eighty days(180)of the latter of commencement of operation or issuance of this permit. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limits. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self-certification process. (Reference: Regulation Number 3, Part B, Section III.E.) 48. Point 004, 005, 006, 007, 008, 009: A source initial compliance test shall be conducted on this heater to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits contained 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 Number 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. 49. Point 014, 015: The owner/operator shall complete initial site specific extended gas analyses ("Analyses") within one hundred and eighty days (180) after commencement of operation or issuance of this permit, whichever comes later, of the plant inlet gas stream and residue gas stream routed to this emissions unit in order to verify the VOC content (weight fraction) of this emission stream. Results of the Analyses shall be used to calculate a site-specific emission factor for VOC (in units of lb/MMSCF gas vented) using Division approved methods. Results of the Analyses shall be submitted to the Division as part of the self-certification and must demonstrate the emissions factor established through the Analyses is less than or equal to, the emissions factor submitted with the permit application and established herein in the "Notes to Permit Holder" for Process 01 for this emissions point. If the site specific emissions factor developed through these Analyses is greater than the emissions factor submitted with the permit application and established in the "Notes to Permit Holder" for Process 01, the operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this inaccuracy. 50. Point 016:Within one hundred and eighty days (180)of the latter of commencement of operation or issuance of this permit, the owner or operator shall complete the initial extended gas analysis of gas samples that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the extended gas analysis and emission calculations to the Division as part of the self-certification process to ensure compliance with emissions limits. DP}iE COLORADO Air Pollution Control Division Page 20 of 33 " ': m ‘ , e 4 51. oint 0', ne hun re nd eid gays (180 of the latter of commencement of operation r issuance permttt erato �s 4ll compte a hard count of components at the source ��, nd es lis he n9mberof cornponerp that are*rated in "heavy liquid service", "light liquid -e iq "water/4 se ice" a "gaaservice" the operator shall submit the results to the s rvision as*Oa of tie set-cer i icat in"'process fo ensure compliance with emissions limits. Periodic Testing Requirements 52. Point 001, 002, 003: The owner or operator shall complete an extended wet gas analysis prior to the inlet of the dehydration unit on an annual basis. Results of the wet gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit and be provided to the Division upon request. 53. Point 016: On an annual basis, the permittee shall complete an extended gas analysis of gas samples that are representative of volatile organic compounds(VOC)and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. ALTERNATIVE OPERATING SCENARIOS 54. Point 001, 002, 003: The electric glycol pumps may be replaced with another electric glycol pump in accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a revision to this permit or obtaining a new construction permit.The maximum glycol recirculation rate of a replacement pump shalt not exceed the glycol recirculation rate as authorized in this permit. 55. Point 001, 002, 003: The owner or operator shall maintain a log on-site or at a local field office to contemporaneously record the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of the replacement pump. 56. Point 001, 002, 003: All pump replacements installed and operated per the alternate operating scenarios authorized by this permit must comply with all terms and conditions of this construction permit. ADDITIONAL REQUIREMENTS 57. A revised Air Pollutant Emission Notice (APEN)shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO),) in ozone nonattainment areas emitting less than 100 tons of VOC or NO„ per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or copu COLORADO 4..0 0C Air Pollution Control Division i Page 21 of 33 ;ry • heneve riew contraiequipmetgis inst ed, or whenever a different type of control equiiek replac .a existi n type of corol equipment; or 1 • IVVheiiever4,per,rtilt limy anon ust be modified; or • No later than 30-days before the existing APEN expires. 58. The requirements of Colorado Regulation Number 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, V.A.7.B). GENERAL TERMS AND CONDITIONS 59. 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. 60. 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. 61. 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. 62. 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. 63. 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. 64. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 65. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. CDP liE COLORADO Air Pollution Control Division Page 22 of 33 1 i 1 e • 060.).- y ; Bradfiey Eades Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to DCP Operating Company, LP cnntt - COLORADO O Air Pollution Control Division Page 23 of 33 7,17z,\,,,, 7'k ,.k 0,,,,w7orl gis!,,, ,,,43 yr 3 Notes ti$Permit told rI. .at Me tim orthis permttisuance ' . 1) Thepermit bolder is s quired, p fees ff f the processing time for this permit. An invoice for these feewill b ssu afte theiermi issued. The peat holder shall pay the invoice within 30 days o u eiprof nvoice AEailure� paiiktthe invoie;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 AIRS Uncontrolled Controlled Pollutant CAS# Emissions Emissions Equipment ID Point (Ib/yr) (lb/yr) Benzene 71432 4,965 248 Toluene 108883 3,153 158 D-01 001 Xylenes 1330207 1,311 66 n-Hexane 110543 2,522 126 2,2,4- 540841 3 <1 Trimethylpentane Benzene 71432 4,965 248 Toluene 108883 3,153 158 D-02 002 Xylenes 1330207 1,311 66 n-Hexane 110543 2,522 126 2,2,4- 540841 3 <1 Trimethylpentane Benzene 71432 3,300 165 Toluene 108883 2,093 105 D-03 003 Xylenes 1330207 866 43 n-Hexane 110543 1,684 84 2,2,4- 540841 2 <1 Trimethylpentane Formaldehyde 50000 10 10 H-1741 004 Benzene 71432 <1 <1 is, COLORADO co Air Pollution Control.P,ivislon Page 24 of 33 ..a! .N„,,,,,, it" , , 1 I i7' 1 p�luene 10si 83 1 1 n ' xane 11 3 245 245 x a .;;2�. 4 ,.2+seS2f or mdde KAfel 5O0 0 10 10 Benzene 71432 <1 <1 H-2741 005 Toluene 108883 1 1 n-Hexane 110543 245 245 Formaldehyde 50000 16 16 Benzene 71432 <1 <1 H-19000 006 Toluene 108883 1 1 n-Hexane 110543 375 375 Formaldehyde 50000 16 16 Benzene 71432 <1 <1 H-29000 007 Toluene 108883 1 1 n-Hexane 110543 375 375 Formaldehyde 50000 34 34 Benzene 71432 1 1 H-1781 008 Toluene 108883 2 2 n-Hexane 110543 810 810 Formaldehyde 50000 34 34 Benzene 71432 1 1 H-2781 009 Toluene 108883 2 2 n-Hexane 110543 810 810 Benzene 71432 2,440 122 Toluene 108883 6,761 338 Ethylbenzene 100414 504 25 TANKS-1 010 Xylenes 1330207 5,110 256 n-Hexane 110543 13,127 656 2,2,4- 540841 10 <1 Trimethylpentane Benzene 71432 2,440 122 Toluene 108883 6,761 338 Ethylbenzene 100414 504 25 TANKS-2 011 Xylenes 1330207 5,110 256 n-Hexane 110543 13,127 656 2,2,4- 540841 10 <1 Trimethylpentane cDik COLORADO co ±S` Air Pollution Control Division Page 25 of 33 ' 0 Borizene,04 711 2 5,398 270 -t:'--- f� 4 Touene a � 1083 14,959 748 u - Ethyl ze 'e 10Oai4 1,115 56 LO 012 Xylenes 1330207 11,308 565 n-Hexane 110543 29,046 1,452 2,2,4- 540841 22 1 Trimethylpentane Benzene 71432 163 163 Toluene 108883 161 161 Ethylbenzene 100414 8 8 UL 013 Xylenes 1330207 51 51 n-Hexane 110543 1,365 1,365 2,2,4- 540841 51 51 Trimethylpentane Benzene 71432 298 15 Toluene 108883 144 7 FLARE-1 014 Xylenes 1330207 36 2 n-Hexane 110543 6,910 348 2'2'4 540841 11 1 Trimethylpentane Benzene 71432 195 10 Toluene 108883 94 5 FLARE-2 015 Xylenes 1330207 24 1 n-Hexane 110543 4,520 229 2,2,4- 540841 7 <1 Trimethylpentane Benzene 71432 526 84 Toluene 108883 255 41 FUG 016 Xylenes 1330207 64 10 n-Hexane 110543 12,191 1,951 2,2,4- 540841 20 3 Trimethylpentane METHANOL 017 Methanol 67561 1,235 1,235 Note: All non-criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. COPHE COLORADO Air Pollution Control Division ,,. Page 26 of 33 447444 44, ,47440 ., 5) Th•;emissi• lev�tntained s perm le basedn the following emission factors: Pot 001, b2,103` Thk(crn le is c ai•n.'�d •in t er M it are basn information provided in the application afTeti�e GRI G yCatc 4. mo el. Coif oTte' e o flash tarir and still vent emissions are based on 100% control efficiency when emissions are routed to the VRU and 95% control efficiency when emissions are routed to the open flare during VRU downtime. The VRUs are permitted based on a maximum of 2% annual downtime for the still vent VRU and 2% annual downtime for the flash tank VRU. Point 004, 005: Emission Factors CAS # Pollutant Uncontrolled Source lb/MMscf NOx 50 AP-42 Chapter 1 Table 1.4-1 CO 84 AP-42 Chapter 1 Table 1.4-1 Note: Emission factors are based on a rated heat input of 23.33 MMBtu/hr, a higher heating value of 1,050 Btu/scf and an annual fuel use limit of 136.25 MMscf/yr (i.e. limited to 70% of capacity). Point 006, 007: Emission Factors CAS # Pollutant Uncontrolled Source lb/MMscf NOx 50.0 AP-42 Chapter 1 Table 1.4-1 CO 84.0 AP-42 Chapter 1 Table 1.4-1 110543 n-Hexane 1.8 Ap-42 Table 1.4-3 Note: Emission factors are based on a rated heat input of 25 MMBtu/hr, a higher heating value of 1,050 Btu/scf and 8,760 hours of operation per year. Point 008, 009: Emission Factors CAS # Pollutant Uncontrolled Source lb/MMscf NOx 35.70 Manufacturer CO 84.0 AP-42 Chapter 1 Table 1.4-1 110543 n-Hexane 1.8 Ap-42 Table 1.4-3 Note: Emission factors are based on a rated heat input of 53.93 MMBtu/hr, a higher heating value of 1,050 Btu/scf and 8,760 hours of operation per year. coats COLORADO ►.O s Air Pollution Control Division h._ ,,. . •,� Page 27 of 33 '''''i 'I\ ','N, A :: 5.. r ..„ Poet 010 '5 = aj "i c .1.L-'" i urcbnerolled Controlled pas# Polttant9 � �',Emison Factor Emission Factors Source Ef-. ,W ':;Y 5,2';1b/bbl cfAkm lb/bbl N0x 0.0002 0.0002 AP-42 CO 0.0008 0.0008 Chapter 13.5 V0C 0.0932 0.0047 71432 Benzene 0.0012 0.0001 108883 Toluene 0.0034 0.0002 EPA TANKS 100414 Ethylbenzene 0.0003 1.3E-5 4.0.9d 1330207 Xylene 0.0026 0.0001 110543 n-Hexane 0.0067 0.0003 Note: The controlled emissions factors for this point are based on the enclosed combustor control efficiency of 95%.The N0x and CO emissions factors(EF)in the table above are based on the AP-42 Chapter 13.5 emissions factors of 0.068 lb/MMBtu and 0.310 lb/MMBtu respectively. The emissions factors were converted to units of lbs/bbl using a waste gas heating value of 3,677 Btu/scf and a volumetric emission rate of 0.64 scf/bbl. Combustion of Assist Gas: Uncontrolled Controlled Pollutant CAS # Emission Factors Emission Factors Source lb/MMscf lb/MMscf N0x 71.40 71.40 AP-42 Chapter 13.5 CO 325.50 325.50 The N0x and CO emissions factors (EF) in the table above are based on the AP-42 Chapter 13.5 emissions factors of 0.068 lb/MMBtu and 0.310 lb/MMBtu respectively. The emissions factors were converted to units of lbs/MMscf using an assist gas heating value of 1,050 Btu/scf. Point 011: Uncontrolled Controlled CAS# Pollutant Emission Factors Emission Factors Source lb/bbl lb/bbl V0C 0.0932 0.0047 71432 Benzene 0.0012 0.0001 108883 Toluene 0.0034 0.0002 EPA TANKS 100414 Ethylbenzene 0.0003 1.3E-5 4.0.9d 1330207 Xylene 0.0026 0.0001 110543 n-Hexane 0.0067 0.0003 Note: The controlled emissions factors for this point are based on the enclosed combustor control efficiency of 95%. Point 012: Uncontrolled Controlled Pollutant CAS# Emission Factors Emission Factors Source lb/bbl lb/bbl V0C 2.02E-1 1.01E-2 Benzene 71432 2.69E-3 1.34E-4 Toluene 108883 7.45E-3 3.73E-4 AP-42: Chapter Ethylbenzene _ 100414 5.55E-4 2.78E-5 5.2, Equation 1 Xylene 1330207 5.63E-3 2.82E-4 n-Hexane 110543 1.45E-2 7.23E-4 The uncontrolled V0C emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: Sir COLORADO 0 Air Pollution Control Division Page 28 of 33 1 46* *M/T ie' 0.6 (Su d load ` dedicated_normal service) rue v rsure) . .0 psia M y por olecul weig ) = 66 lb/lb4lol mi T(., raiture• ui ded) = 5.. °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the stabilized condensate by the VOC emission factor. Controlled emission factors are based on a combustor control efficiency of 95%. Point 013: Emissions associated with the pressurized unloading of condensate result from gasses that are released from hoses during disconnect. Emission factors in the table below are based on vapor and liquid line volumes and specific gravity of the liquid unloaded. Emission Factors - Uncontrolled CAS Pollutant (Ib/loadout) Source VOC 1.93 Engineering Calculation 110543 n-Hexane 0.16 Emission factors are based on liquid and vapor line volumes of 0.0491 ft3/hose. Point 014: Emissions associated with the open flare result from the combustion of maintenance gas (inlet, residue, and refrigerant system), purge gas (residue), and pilot light gas. Total actual emissions are based on the sum of the emissions calculated for the combustion of maintenance gas and purge gas (process 01) and the combustion of pilot light gas (process 02). Process 01: Combustion of maintenance (residue, inlet, refrigerant) gas Emission Emission Factors CAS # Pollutant Factors Controlled Source Uncontrolled lb/MMscf lb/MMscf NOx 95.73 95.73 AP-42 Chapter CO 436.42 436.42 13.5 VOC 26,689.26 1334.46 110543 n-Hexane 265.68 13.28 Representative Gas Analysis 71432 Benzene 11.46 0.57 Note: The uncontrolled VOC and HAP emissions from combustion of "maintenance gas" were calculated using a weighted average of a residue gas analysis obtained from meter data at a representative DCP facility, an inlet gas sample obtained from the O'Connor gas plant (sampled 10/27/16), and a refrigerant system gas composition of 100% propane. The weighted average is based on the relative contribution of 17% residue gas, 71% inlet gas and 12% refrigerant system gas. The controlled VOC and HAP emission factors are based on the flare control efficiency of 95%. NOx and CO emission factors are based on a weighted heating value of 1,408 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the total gas flow routed to this flare as measured by flow meter, minus the volume of purge gas routed to this flare, based on a purge rate of 1,270 scf/hr. stile COLORADO CO 1 Air Pollution Control Division Page 29 of 33 r,w rocessO1 gpmOstion of u e gas fy Emissibn Al Facts Er ssion Factors C Polttant controlled Source lb/MMscf lb/MMscf NOx 74.66 74.66 AP-42 Chapter CO 340.38 340.38 13.5 VOC 1,452.44 72,62 Representative Gas Analysis Note: The uncontrolled VOC emissions from combustion of purge gas were calculated using the residue gas analysis obtained from meter data at a representative DCP facility and a purge rate of 1,270 scf/hr. The controlled VOC emission factors are based on the flare control efficiency of 95%. NOx and CO emission factors are based on a heating value of 1,098 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the purge flow to the flare based on purge rate (1,270 scf/hr). Process 02: Combustion of pilot light fuel Emission CAS # Pollutant Factors Source Uncontrolled lb/MMscf NOx 100 AP-42 Chapter 1 Table 1.4-1 CO 84 AP-42 Chapter 1 Table 1.4-1 VOC 5.5 AP-42 Chapter 1 Table 1.4-2 110543 n-Hexane 1.8 AP-42 Chapter 1 Table 1.4-3 Note: Emission factors are based on a higher heating value of 1,050 Btu/scf and 8,760 hours of operation a year. The pilot light fuel has a constant rate of 195 scf/hr. Point 015: Emissions associated with the open flare result from the combustion of maintenance gas (inlet, residue, and refrigerant system), purge gas (residue), and pilot light gas. Total actual emissions are based on the sum of the emissions calculated for the combustion of maintenance gas and purge gas (process 01) and the combustion of pilot light gas (process 02). Process 01: Combustion of maintenance (residue, inlet, refrigerant) gas Emission Emission Factors CAS# Pollutant Factors Controlled Source Uncontrolled lb/MMscf lb/MMscf NOx 95.73 95.73 AP-42 Chapter CO 436.42 436.42 13.5 VOC 26,690.82 1,334.54 Representative 110543 n-Hexane 265.64 13.28 Gas Analysis Note: The uncontrolled VOC and HAP emissions from combustion of "maintenance gas" were calculated using a weighted average of a residue gas analysis obtained from meter data at a representative DCP facility, an inlet gas sample obtained from the O'Connor gas plant (sampled 10/27/16), and a refrigerant system gas composition of 100% propane. The weighted average is based on the relative contribution of 17% residue gas, 71% inlet 4„, 1E COLORADO ir Pollution Control Division COrLf Page 30 of 33 s s L refrig.ra syste The ntrolled VOC and HAP emission factors are � o, ase e flar_ l effi eney of 95 NOx and CO emission factors are based on a itkeigkted j atin alue4 f 1,4 Btu/scf tual emissions are calculated by multiplying he enissrt fa- ors in e ty° le above the total gas flow routed to this flare as measured by now meter, minus tie volume o purge gas routed to this flare, based on a purge rate of 1,270 scf/hr. Process 01: Combustion of purge gas Emission Emission Factors CAS# Pollutant Factors Controlled Source Uncontrolled lb/MMscf lb/MMscf NOx 74.66 74.66 AP-42 Chapter CO 340.38 340.38 13.5 VOC 1,452.44 72.62 Representative Gas Analysis Note: The uncontrolled VOC emissions from combustion of purge gas were calculated using the residue gas analysis obtained from meter data at a representative DCP facility and a purge rate of 1,270 scf/hr. The controlled VOC emission factors are based on the flare control efficiency of 95%. NOx and CO emission factors are based on a weighted heating value of 1,098 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the purge flow to the flare based on purge rate (1,270 scf/hr). Process 02: Combustion of pilot light fuel Emission CAS # Pollutant Factors Source Uncontrolled lb/MMscf NOx 100 AP-42 Chapter 1 Table 1.4-1 CO 84 AP-42 Chapter 1 Table 1.4-1 VOC 5.5 AP-42 Chapter 1 Table 1.4-2 110543 n-Hexane 1.8 AP-42 Chapter 1 Table 1.4-3 Note: Emission factors are based on a higher heating value of 1,050 Btu/scf and 8,760 hours of operation a year. The pilot light fuel has a constant rate of 195 scf/hr. Point 016: Component Gas Service Gas Control % Light Oil Light Liquid Control Connectors 30,516 30 5,048 30 Flanges 2,062 30 988 30 Open-ended Lines 0 75 0 Pump Seals 0 --- 72 88 Valves 7,304 95 2,448 95 Other* 122 75 28 75 Relief Valves 0 95 0 95 VOC Content (wt. %) 28.95% --- 100% Benzene Content (wt. %) 0.0278% --- 0.0961% 011 COLORADO CO 1 Air Pollution Control Division Page 31 of 33 97; Toluene ant %) 40135% , -- 0.0466% XZlenes ntet t`ryk. 44,0034%4k 1-- 0.0116% it-Hexane Con ent (wt. ,t 0 443% ' 2.2254% 2,2,4-TMP Content (wt. 0.0011% 0.0036% %) *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): Component Gas Service Heavy Oil Light Oil ervi S Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Relief Valves 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 Table 2-4 Note that the emission limits included in this permit are derived by multiplying the emissions resulting from the component counts in the table above by a factor of 1.4 (i.e. 40% increase) to accommodate other minor changes to the facility and to provide a conservative estimate of facility- wide emissions. Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent extended gas analysis. Point 017: Emission Factors CAS# Pollutant Uncontrolled Source lb/bbl 67561 Methanol 0.129 EPA TANKS 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 glycol dehydration unit and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(B) when applicable. CAE COLORADO Air Pollution Control Division �;, , •„ Page 32 of 33 8) Thy facilit cl sit as foil ws s! A he let + puire nt Status Operating Permit Synthetic Minor Source of: V0C, HAPs NANSR Synthetic Minor Source of: V0C MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Applicable 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A- Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ- Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980-End Subpart NNNNN - Subpart XXXXXX SOP£€£ COLORADO CO Air Pollution Control Division Page 33 of 33 • P,r 3:J\≥ "v ) 00C- 3W() ,(1)A -coma �. Glycol Dehydration Unit APEN - Form APCD-202 Air Pollutant Emission Notice (APEN) and COw Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www.colorado.Rov/cdphe/apcd. This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 18WE0465 AIRS ID Number: 123 / 9FBB / 001 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Company equipment Identification: D-01 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Bighorn Natural Gas Processing Plant Site Location Site Location: Section 2, Township 3N, Range 65W County: Weld La Salle, CO 80645 NAICS or SIC Code: 1321 Mailing Address: 370 17th St, Suite 2500 (Include Zip Code) Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E-Mail Address2: RShankaran@dcpmidstream.com '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. _ _..._. _....... COLORADO.. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017 Permit Number: 18WE0465 AIRS ID Number: 123 /9FBB# 001 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 2- Requested Action 0 NEW permit OR newly-reported emission source -OR- ❑ MODIFICATION to existing permit (check each box below that applies) to existing permit E] Change fuel or equipment ❑ Change company name ❑ Add point El Change permit limit ❑ Transfer of ownership3 ❑ Other(describe below) -OR APEN submittal for update only (Please note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ❑ Limit Hazardous Air Pollutants (HAPs)with a federally-enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: The still vent stream and flash tank stream are recycled back to the plant inlet via dedicated VRUs 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: Natural Gas Triethylene Glycol Dehydration Unit for Train 1 Facility equipment Identification: D-01 For existing sources, operation began on: For new or reconstructed sources, the projected TBD / start-up date is: • ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: day s/week weeks/year hours/day y Normal Hours of Source Operation: Will this equipment be operated in any NAAQS nonattainment Yes ❑ No area Q No Is this unit located at a stationary source that is considered a [11 Yes Major Source of (HAP) Emissions Form APCD-202-Glycol Dehydration Unit APEN - Revision 02/2017 Permit Number: 18WE0465 AIRS ID Number: 123 /9FBB' 001 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: TBD Model Number: TBD Dehydrator Serial TBD Reboiler Rating: Indirect MMBTU/hr Number: Ethylene Glycol ❑ DiEthylene Glycol O TriEthylene Glycol Glycol Used: ❑ (EG) (DEG) (TEG) Glycol Pump Drive: ✓❑ Electric ❑ Gas If Gas, injection pump ratio: Acfm/gpm Pump Make and Model: TBD #of pumps: 1 (+1 BU) Glycol Recirculation rate (gal/min): Max: Requested: 60 Lean Glycol Water Content: 1 .5 Wt.% Design Capacity: 365 MMSCF/day Dehydrator Gas Throughput: 133,225MMSCF/yearMMSCF/year Requested: Actual: Y Inlet Gas: Pressure: 878 psig Temperature: 80 °F Water Content: Wet Gas: lb/MMSCF 0 Saturated Dry gas: 1 .6 lb/MMSCF psig Temperature: 147 F ❑ NA Flash Tank: Pressure: 60 P g • Cold Separator: Pressure: psig Temperature: °F ✓❑ NA Stripping Gas: (check one) ❑✓ None ❑ Flash Gas ❑ Dry Gas ❑ Nitrogen Flow Rate: scfm Additional Required Information: O Attach a Process Flow Diagram O Attach GRI-GLYCalc 4.0 Input Report a Aggregate Report (or equivalent simulation report/test results) O Attach the extended gas analysis (including BTEX Et n-Hexane, temperature, and pressure) .....__........... .......__.......__. -...__. Form APCD-202-Glycol Dehydration Unit APEN - Revision 02/2017 C_ Permit Number: 18WE0465 AIRS ID Number: 123 /9FBB 001 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 5 - Stack Information Geographical Coordinates (LatitudelLongitude or UTM) 40.258034, -104.625389 Discharge Height "C}pe�ator - Temp F1ovJ hate Velocity'. Above Ground Level Stack ID"tdo �' ) �ACFAh) (ft/sec)(Feet) D-01 120 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑ Other(describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): 16 ElSquare/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other(describe): Awi COLORADO Form APCD-202-Glycol Dehydration Unit APEN - Revision 02/2017 °=n6£ _ _ Permit Number: 18WE0465 AIRS ID Number: 123 /9FBB 001 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 6 - Control Device Information Used for control of: Type: Make/Model: ❑ Condenser: Maximum Temp Average Temp Requested Control Efficiency Used for control of: VOC and HAPs from still vent and flash tank streams Size: Make/Model: VRU: Requested Control Efficiency 1 00 VRU Downtime or Bypassed 2 Used for control of: VOC/HAPs from still vent and flash tank streams Rating: MMBtu/hr Type: Plant Flare Make/Model:TBD ❑ Combustion Requested Control Efficiency: 95 Device: Manufacturer Guaranteed Control Efficiency Minimum Temperature: Waste Gas Heat Content 2,192 Btu/scf Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating 0.20 MMBtu/hr Used for control of: Closed ❑ Loop Description: System: System Downtime Used for control of: VOC/HAP for still vent/flash tank (2%VRU DT only) ✓❑ Other: Description: Plant Flare Control Efficiency Requested 95 ° co�oaano Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 5 ��?.nb.. µ;, Permit Number: 18WE0465 AIRS ID Number: 123 /9FBB 001 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? Q Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency(% reduction): Overall Requested Control Pollutant Control Equipment Description Efficiency (%reduction in emissions) PM SOX NO„ CO VOC VRUs to control still vent and flash tank streams 100(2%downtime to plant flare) HAPs VRUs to control still vent and flash tank streams 100(2%downtime to plant flare) 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.) Emission Requested Annual Permit Uncontrolled Emission Factor Actual Annual Emissions 4 Pollutant Emission Factor Source Emfssfiort Lirni {s� Factor Units (AP-42, Uncontrolled Controlled5 Uncontrolled Controlled Mfg.etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) PM SOX 1.10E-04 lb/MMscf Mass Balance -- 0.01 NO, 0.068 Ib/MMBtu AP-42 0.07 0.07 CO 0.310 lb/MMBtu AP-42 0.30 0.30 VOC 0.457 lb/MMscf GlyCalc 29.18 1.46 Benzene 0.039 lb/MMscf GlyCalc 2.48 0.12 Toluene 0.025 lb/MMscf GlyCalc 1.58 0.08 Ethylbenzene Xylenes 0.010 lb/MMscf GlyCalc 0.66 0.03 n-Hexane 0.020 lb/MMscf GlyCalc 1.26 0.06 2,2,4- Trimethylpentane Other: 4 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-202-Glycol Dehydration Unit APEN - Revision 02/2017 6 I Ayr Permit Number: 18WE0465 AIRS ID Number: 123 /9FBB1 001 [Leave blank unless APCD has already assigned a permit"and MRS#0] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete,true and correct_ .� fry �i .__. t leis Signature of Legally Authorized Person(not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance I Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and for 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 Air Pollution Control Division (303)692-3175 or(303)692-3148 APCD-SS-B 1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver,CO 80246-1530 https://www.colorado.gov/cdphe/apcd Make check payable to: Colorado Department of Public Health and Environment Telephone: (303)692-3150 COLORADO Form AP C0-2302 Glycol 0ehydraUon Unit.APEy - Rev.sign 0212017 7 I © CDPHE'" Glycol Dehydration Unit APEN - Form APCD-202 Air Pollutant Emission Notice (APEN) and ',✓ Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www.colorado.00v/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: 18WE0465 AIRS ID Number: 123 / 9FBB / 002 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Company equipment Identification: D-02 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': DCP Operating Company, LP P Y p g Site Name: Bighorn Natural Gas Processing Plant Site Location Site Location: Section 2, Township 3N, Range 65W County: Weld La Salle, CO 80645 NAICS or SIC Code: 1321 Mailing Address: (Include Zip Code) 370 17th St, Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E-Mail Address2: RShankaran@dcpmidstream.com 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. ANT Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 1 I ;n; Permit Number: 18WE0465 AIRS ID Number: 123 /9FBB/ 002 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 2- Requested Action ✓❑ NEW permit OR newly-reported emission source -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other(describe below) -OR • APEN submittal for update only (Please note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info if Notes: The still vent stream and flash tank stream are recycled back to the plant inlet via dedicated VRUs 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: Natural Gas Triethylene Glycol Dehydration Unit for Train 2 Facility equipment Identification: D-02 For existing sources, operation began on: For new or reconstructed sources, the projected TBD / / start-up date is: ❑� Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Will this equipment be operated in any NAAQS nonattainment Yes ❑ No area Is this unit located at a stationary source that is considered a ❑ Yes ❑✓ No Major Source of(HAP) Emissions Aws Form APCD-202-Glycol Dehydration Unit APEN - Revision 02/2017 2 I Permit Number: 18WE0465 AIRS ID Number: 123 /9FBB/ 002 [Leave blank unless APCD has already assigned a permit tt and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: TBD Model Number: TBD Dehydrator Serial TBD Reboiler Rating: Indirect MMBTU/hr Number: Ethylene Glycol DiEthylene Glycol TriEthylene Glycol Glycol Used: ❑ (EG) ❑ (DEG) ❑� (TEG) Glycol Pump Drive: ❑ Electric ❑ Gas If Gas, injection pump ratio: Acfm/gpm Pump Make and Model: TBD #of pumps: 1 (+1 BU) Glycol Recirculation rate (gal/min): Max: Requested: 60 Lean Glycol Water Content: 1 .5 Wt.% Design Capacity: 365 MMSCF/day Dehydrator Gas Throughput: Requested: 133,225 MMSCF/year Actual: MMSCF/year Inlet Gas: Pressure: 878 psig Temperature: 80 °F Water Content: Wet Gas: lb/MMSCF E Saturated Dry gas: 1 .6 lb/MMSCF Flash Tank: Pressure: 60 psig Temperature: 1 47 °F ❑ NA Cold Separator: Pressure: psig Temperature: °F ✓❑ NA Stripping Gas: (check one) 0 None ❑ Flash Gas ❑ Dry Gas ❑ Nitrogen Flow Rate: scfm Additional Required Information: ❑r Attach a Process Flow Diagram O Attach GRI-GLYCalc 4.0 Input Report Et Aggregate Report (or equivalent simulation report/test results) ❑✓ Attach the extended gas analysis (including BTEX a n-Hexane, temperature, and pressure) -- aice OlORl.➢O Form APCD-202-Glycol Dehydration Unit APEN - Revision 02/2017 3 G v:.,,,.'; Permit Number: 18WE0465 AIRS ID Number: 123 /9FBB 002 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.258034, -104.625389 DischargGe HeightLevelTemp., ,Operator Flow Rate Velocity Above round Stack-; ID Na �. � �;� . ('F) (ACFM) ffIsec) Feet D-02 120 Indicate the direction of the stack outlet: (check one) [1 Upward [II Downward El Upward with obstructing raincap El Horizontal [1 Other (describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): 16 E] Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): -COLORADO Form APCD-202-Glycol Dehydration Unit APEN - Revision 02/2017 4 I ',`,:":,-.7-;-7::.„1,':::.-.`',4, Permit Number: 18WE0465 AIRS ID Number: 123 /9FBB 002 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 6 - Control Device Information Used for control of: Type: Make/Model: ❑ Condenser: Maximum Temp Average Temp Requested Control Efficiency Used for control of: VOC and HAPs from still vent and flash tank streams Size: Make/Model: ❑� VRU: Requested Control Efficiency 1 00 VRU Downtime or Bypassed 2 Used for control of: VOC/HAPs from still vent and flash tank streams Rating: MMBtu/hr Type: Plant Flare Make/Model:TBD ✓0 Combustion Requested Control Efficiency: 95 % Device: Manufacturer Guaranteed Control Efficiency Minimum Temperature: Waste Gas Heat Content 2,192 Btu/scf Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating 0.20 MMBtu/hr Used for control of: Closed ❑ Loop Description: System: System Downtime Used for control of: VOC/HAP for still vent/flash tank (2%VRU DT only) ✓❑ Other: Description: Plant Flare Control Efficiency 0- Requested 95 .. .. ....__..._.......___.... .__.. cotoaxno Form APCD-202-Glycol Dehydration Unit APEN - Revision 02/2017 5 1 A !. bF.4 15'ari1 Permit Number: 18WE0465 AIRS ID Number: 123 /9FBB 002 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Control Equipment Description Efficiency (%reduction in emissions) PM SOx NO„ CO VOC VRUs to control still vent and flash tank streams 100(2%downtime to plant flare) HAPs VRUs to control still vent and flash tank streams 100(2%downtime to plant flare) 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.) Emission Requested Annual Permit Uncontrolled Emission Factor Actual Annual Emissions a s Emision Limits) Pollutant Emission Factor Source Factor Units (AP-42 Uncontrolled Controlled s Uncontrolled Controlled Mfg.etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) PM SOx 1.10E-04 lb/MMscf Mass Balance -- 0.01 NO„ 0.068 Ib/MMBtu AP-42 0.07 0.07 CO 0.310 lb/MMBtu AP-42 0.30 0.30 VOC 0.457 lb/MMscf GlyCalc 29.18 1.46 Benzene 0.039 lb/MMscf GlyCalc 2.48 0.12 Toluene 0.025 lb/MMscf GlyCalc 1.58 0.08 Ethylbenzene Xylenes 0.010 lb/MMscf GlyCalc 0.66 0.03 n-Hexane 0.020 lb/MMscf GlyCalc 1.26 0.06 2,2,4- Trimethylpentane Other: 4 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-202-Glycol Dehydration Unit APEN - Revision 02/2017 6 I Permit Number: 18WE0465 AIRS iD Number: 123 /9FBB' 002 [Leave blank unless APCD has aireacy assfnned a permit 4 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. r♦ 5 2 OS . Signature of Legally Authorized Person(not a vendor or consultant) Date Roshini Shankaran 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 5152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 or(303)692-3148 APCD-SS-B1 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 �j colopiDO Fern-,APCD-2O2 Glycol Dehydration Unit A�EN Revision 02:2017 �i3:Av re IIFff! III`r', ' RECEIVEI? 4' 9. I I uGr,; MAY -4 ma IT: ;-Pomona' CDPHE. Glycol Dehydration Unit APEN - Form APCD-202 Sources , Air Pollutant Emission Notice (APEN) and H. Co = Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: AIRS ID Number: i 23 /a F3 a/Q 03 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Company equipment Identification: 0-03 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information 0r tea' Company Name': DCP Operating Company, LP Q Uic rrl t c,S �a-NA' Site Name: Sfleitell latuai-Ga s-P-r-eoessi#ig--Want- Site Location Site Location: Section 2, Township 3N, Range 65W county: Weld La Salle, CO 80645 NAICS or SIC Code: 1321 Mailing Address: (Include Zip Code) 370 17th St, Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E-Mail Address2: RShankaran@dcpmidstream.com 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. 380082 COLORADO Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017 1 I �� °`a °` u`�°`Fie�l:P 6 EM1VIA„i f, II naf IaL•fi Permit Number: AIRS ID Number: / / 033 [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) l' ❑ Change fuel or equipment 0 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 - 111 Limit Hazardous Air Pollutants (HAPs)with a federally-enforceable limit on Potential To Emit (PTE) Additional Info a Notes: The still vent stream and flash tank stream are recycled back to the plant inlet via dedicated VRUs 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: Natural Gas Triethylene Glycol Dehydration Unit for Bypass Facility equipment Identification: D-03 For existing sources, operation began on: / / For new or reconstructed sources, the projected start-up date is: TBD / / 0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Will this equipment be operated in any NAAQS nonattainment Yes ❑ No area Is this unit located at a stationary source that is considered a ❑ Yes No Major Source of(HAP) Emissions A COLORADO Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 2 �� °" °^`°'"°'°`e:i!L cnvin ,f, I!;I i Iii' Permit Number: AIRS ID Number: / I 003 ITi ily [Leave blank unless APCD has already assigned a permit#and AIRS ID] 15 ; Section 4 - Dehydration Unit Equipment Information !tea Manufacturer: TBD Model Number: TBD Dehydrator Serial Reboiler Rating: °I''_ Number: TBD Indirect MMBTU/hr ,!-,, Ethylene Glycol DiEthylene Glycol TriEthylene Glycol 'I`l' Glycol Used: ❑ (EG) ❑ (DEG) 0 (TEG) Glycol Pump Drive: ✓❑ Electric 0 Gas If Gas, injection pump ratio: Acfm/gpm Pump Make and Model: TBD #of pumps: 1 (+1 BU) Glycol Recirculation rate (gal/min): Max: Requested: 40 Lean Glycol Water Content: 1.5 Wt.% Design Capacity: 230 MMSCF/day Dehydrator Gas Throughput: Requested: $3,950 MMSCF/year Actual: MMSCF/year Inlet Gas: Pressure: 878 psig Temperature: 80 °F Water Content: Wet Gas: lb/MMSCF 0 Saturated Dry gas: 1 .6 lb/MMSCF Flash Tank: Pressure: 60 psig Temperature: 147 T F 0 NA Cold Separator: Pressure: psig Temperature: °F 0 NA Stripping Gas: (check one) 0 None ❑ Flash Gas ❑ Dry Gas ❑ Nitrogen Flow Rate: scfm Additional Required Information: 0 Attach a Process Flow Diagram 0 Attach GRI-GLYCaIc 4.0 Input Report Et Aggregate Report(or equivalent simulation report/test results) 0 Attach the extended gas analysis (including BTEX Et n-Hexane, temperature, and pressure) RADO Form APCD-202-Glycol Dehydration Unit APEN - Revision 02/2017 3 �� 1:.r7O 6E°= '=n ufj 1yt, ON,; IIryf; q ntit Permit Number: AIRS ID Number: / /( )3 r [Leave blank unless APCD has already assigned a permit#and AIRS ID] I[sl Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.258034, -104.625389 Discharge Height Operator- Temp. Flow Rate Velocity Above Ground Level Stack ID No. ('F) (ACFM) (ft/sec) (Feet) D-03 120 Indicate the direction of the stack outlet: (check one) E Upward D Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑ Other(describe): Indicate the stack opening and size: (check one) E Circular Interior stack diameter (inches): 16 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other(describe): �aj COLORADO Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 4 I m� Permit Number: AIRS ID Number: / /cx,3 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 6 - Control Device Information Used for control of: Type: Make/Model: ❑ Condenser: ;la Maximum Temp Average Temp Requested Control Efficiency Used for control of: VOC and HAPs from still vent and flash tank streams Size: Make/Model: 0 VRU: Requested Control Efficiency 100 % VRU Downtime or Bypassed 2 Used for control of: VOC/HAPs from still vent and flash tank streams Rating: MMBtu/hr Type: Plant Flare Make/Model:TBD (2_11 Requested Requested Control Efficiency: 95 % Device: Manufacturer Guaranteed Control Efficiency Minimum Temperature: Waste Gas Heat Content 2,191 Btu/scf Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating 0.20 MMBtu/hr Used for control of: Closed ❑ Loop Description: System: System Downtime Used for control of: VOC/HAP for still vent/flash tank (2%VRU DT only) ✓❑ Other: Description: Plant Flare Control Efficiency %Requested 95 Ay COLORADO Form APCD-202-Glycol Dehydration Unit APEN - Revision 02/2017 5 m °`�"^ """""HMfh 6 Ehv:tohmvht Ir,�sl n.m?, q uk, Permit Number: AIRS ID Number: / /O03 II ! [Leave blank unless APCD has already assigned a permit 11 and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Lf, Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency(% reduction): Overall Requested Control Pollutant Control Equipment Description Efficiency (%reduction in emissions) PM SOx NOx CO VOC VRUs to control still vent and flash tank streams 100(2%downtime to plant flare) HAPs VRUs to control still vent and flash tank streams 100(2%downtime to plant flare) 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.) Emission Requested Annual Permit Uncontrolled Emission Factor Actual Annual Emissions 4 Pollutant Emission Factor Source Emission Limit(s) Factor Units (AP-42, Uncontrolled Controlled' Uncontrolled Controlled Mfg.etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) PM SOx 1.11E-04 lb/MMscf Mass Balance -- 0.005 NOx 0.068 lb/MMBtu AP-42 0.04 0.04 CO 0.310 Ib/MMBtu AP-42 0.20 0.20 VOC 0.464 Ib/MMscf GlyCalc 19.46 0.97 Benzene 0.039 lb/MMscf GlyCalc 1.65 0.08 Toluene 0.025 lb/MMscf GlyCalc 1.05 0.05 Ethylbenzene Xylenes 0.010 lb/MMscf GlyCalc 0.43 0.02 n-Hexane 0.020 lb/MMscf GIyCaic 0.84 0.04 2,2,4- Trimethylpentane Other: 4 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. E .COLORADO Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 6 I IIr5rI II4+r Permit Number: AIRS ID Number: / /003 [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. ,IM Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran 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: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 or(303) 692-3148 APCD-SS-B1 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 COLORADO Form APCD-202-Glycol Dehydration Unit APEN - Revision 02/2017 7 I fy� ,y hhbEumt m'n II`N 1114, II�M, u^G;, I:LCETVED \\I`[ r U.4Y -4 21'1" :. CDPHE - APCD-220 It Boiler APEN Form �, eta iora1 Air Pollutant Emission Notice (APEN) and Sources Application for Construction Permit CO` MC 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 ;Ir longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. If your emission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200)is available if the specialty APEN options will not satisfy your reporting needs.A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www.colorado.gov/cdphe/apcd. Do not complete this form for the following source categories: - Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by natural gas or liquid petroleum gas(LPG). - Heaters or boilers with a design capacity less than or equal to 10 MMBtu/hour used solely for heating buildings for personal comfort that is fueled solely by natural gas or liquid petroleum gas (LPG). More information can be found in the APEN exempt/permit exempt checklist: https://www.colorado.gov/pacific/cdphe/apen-or-air-permit-exemptions. This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 18'IN�01�� AIRS ID Number: Z? /6(.F813/ 00 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 - Administrative Information ?Er -C-- - J 7/.1 Company Name': DCP Operating Company, LP 2i �oc-r (\ Site Name: i-anvn. 4—at ra aS fi6L n l°ant Site Location Site Location: Section 2, Township 3N, Range 65W County: Weld La Salle, CO 80645 NAICS or SIC Code: 1321 Mailing Address: (Include Zip code) 370 17th Street, Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E-Mail Address2: RShankaran@DCPMidstream.com 1 Please use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by APCD via e-mail to the address provided. 380083 !COLORADO Form APCD-220- Boiler APEN - Revision 11/2017 VVV VVV iii��111 1 I ,M „ N ila}ii II qr j IIV1{• Permit Number: AIRS ID Number: / /0.ju [Leave blank unless APCD has already assigned a permit ii and AIRS ID] Section 2 - Requested Action Q NEW permit OR newly-reported emission source a=, -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other(describe below) -OR- ❑ APEN submittal for update only(Please note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: 3 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: 23.33 MMBtu/hr mol sieve regeneration heater, fueled by natural gas for Train 1 (Heater will be limited to 70% annual fuel usage) Manufacturer: Tulsa Heaters Midstream Model No.: S H O 1250 Serial No.: TBD Company equipment Identification No. (optional): H-1741 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: TBD ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec-Feb: Mar-May: June-Aug: Sept-Nov: Are you reporting multiple identical boilers on this APEN? ❑Yes 0 No If yes, please describe how the fuel usage will be measured for each boiler (i.e., one meter for all boilers or separate meters for each unit): COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 2 I Mc 1=17;V:"':,, ir,.ra I�tili 14 Permit Number: AIRS ID Number: / / � � l [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 4 - Stack Information i Geographical Coordinates (Latitude/Longitude or UTM) 40.258034, -104.625389 Discharge Height Operator Temp. Flow Rate Velocity Above Ground Level Stack ID No. ('F) (ACFM) (ft/sec) (Feet) H-1741 25 479 7,370 39.1 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter(inches): 24 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other(describe): Section 5 - Fuel Consumption Information Requested Annual Permit Limit Design Input Rate Actual Annual Fuel Use4 t5 (MMBTU/hr) (Specify Units) (Specify Units) 23.33 136.25 MMscf/yr From what year is the actual annual fuel use data? N/A Fuel consumption values entered above are for: 0 Each Boiler ❑All Boilers ❑ N/A Indicate the type(s)of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) O Coal Heating value: BTU/lb Ash content: Sulfur Content: 0 Other(describe): Residue Gas Heating value (give units): 1 ,050 Btu/scf 4 If you are reporting multiple identical boilers on one APEN,be sure to clarify if the values in this section are on an individual boiler basis,or if the values represent total fuel usage for multiple boilers. 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 6 If fuel heating value is different than the listed assumed value,please provide this information in the"Other"field. .COLORADO 3 Form APCD-220 - Boiler APEN - Revision 11/2017 liZt; ilryt: Permit Number: AIRS ID Number: / / O q [Leave blank unless APCD has already assigned a permit t and AIRS ID] Section 6- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑Yes ® No II!` If yes, please describe the control equipment AND state the overall control efficiency(% reduction): �Ir. Overall Control Efficiency Pollutant Control Equipment Description (%reduction in emissions) TSP (PM) PM-10 PM2.s Sox NO,, CO VOC Other: From what year is the following reported actual annual emissions data? N/A Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary Fuel Emission Requested Annual Permit Type Factor Uncontrolled Actual Annual Emissions (natural gas, Pollutant Emission Source Emission Limit(s)5 #2 diesel, (SpFac fy Units) (AP-42,Mfg. Uncontrolled Controlled Uncontrolled Controlled etc.) etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) Natural TSP (PM) 5.5 Ib/MMscf Manufacturer 0.37 0.37 Gas PM10 5.5 lb/MMscf Manufacturer 0.37 0.37 PM2.s 5.5 Ib/MMscf Manufacturer 0.37 0.37 SO,, 0.6 Ib/MMscf AP-42 0.04 0.04 NO„ 50Ib/MMscf AP-42 3.41 3.41 CO 84 Ib/MMscf AP-42 5.72 5.72 VOC 5.5 Ib/MMscf AP-42 0.37 0.37 Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. ACOLORADO Form APCD 220 Boiler APEN Revision 11/2017 4 11v,�m�, I Sr, Ilt1'; Permit Number: AIRS ID Number: / / Oc) Ir' [Leave blank unless APCD has already assigned a permit#and AIRS ID] 'Iku ❑✓ Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria emissions table below: , Secondary Emission Requested Annual Permit Z.,I Uncontrolled Actual Annual Emissions • s Fuel Type Factor Emission Limits) Emission (#2 diesel, Pollutant Source waste oil, Factor (AP-42 mfg. Uncontrolled Controlled Uncontrolled Controlled (Specify Units)etc.) etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP (PM) PM1 a PM2.5 SOx NOx CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: Re Actual Annual Emissions quested Annual Permit Pollutant Emission Limit(s)5 Uncontrolled Controlled Uncontrolled Controlled (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP(PM) PA() PM2.5 SOx NOx CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. COLORADO uF.n�� tv,�w� Form APCD-220 - Boiler APEN - Revision 11/2017 5 I 'Ce¢ li°F�I Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit#and AIRS ID] ,14 Section 7 - Non-Criteria Pollutant Emissions Information 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? ice.. If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Uncontrolled Uncontrolled Controlled Overall Emission Factor Emission Actual Actual CAS Number Chemical Name Control Source Factor Emissions Emissions Efficiency (specify urrits) (AP-42,Mfg.etc) (lbs/year) (lbs/year) 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. pp< COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 6 631 ' bEd �� II"V r Permit Number: AIRS ID Number: / I coC� [Leave blank unless APCD has already assigned a permit#and AIRS ID] Ir;F;; Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, rl4y;r. true and correct. :,;;r YLC13 -: 5/L /zoig Signature of Legally Authorized Person (not a vendor or consultant) Date � � Y Roshini Shankaran Environmental Engineer Name (please print) Title Check the appropriate box if you want: ❑� Draft permit prior to public notice Draft of the permit prior to issuance (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 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 or (303) 692- APCD-SS-B1 3148 4300 Cherry Creek Drive South Denver, CO 80246-1530 Or visit the APCD website at: Make check payable to: https://www.colorado.Rov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303)692-3150 COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 7 iu bEna enm•�, ir, / CLi VT -' \` I�, �1 f"p,Y -421,n ii,y,. CDPHE APEN - Form APCD-220 sources ' " Pj CO Air Pollutant Emission Notice (APEN) and _ > 5 Application for Construction Permit ll All sections of this APEN and application must be completed for both new and existing facilities, including APEN .i., updates. An application with missing information may be determined incomplete and may be returned or result in 'i4 longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. If your emission unit does not fall into one of these categories, there may be a more specific APEN for your source(e.g. paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www.colorado.gov/cdphe/apcd. Do not complete this form for the following source categories: - Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by natural gas or liquid petroleum gas (LPG). - Heaters or boilers with a design capacity less than or equal to 10 MMBtu/hour used solely for heating buildings for personal comfort that is fueled solely by natural gas or liquid petroleum gas (LPG). More information can be found in the APEN exempt/permit exempt checklist: https://www.colorado.gov/pacific/cdphe/apen-or-air-permit-exemptions. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: IS vvE 04( S AIRS ID Number: I23 /611 B/ 0 Os [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 - Administrative Information riktr _e_r a.,, 1 `/a/,g Company Name': DCP Operating Company, LP :)' K,r-r\ Q . -43C- Site Name: eitof-Nato 1Gas=P ecessing PI-dpt Site Location Site Location: Section 2, Township 3N, Range 65W County: Weld La Salle, CO 80645 NAICS or SIC Code: 1321 Mailing Address: (Include Zip code) 370 17th Street, Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E-Mail Address2: RShankaran@DCPMidstream.com 1 Please use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by APCD via e-mail to the address provided. Q COLORADO Form APCD 220 Boiler APENRevision 11/2017 38008 1 I Av ' n :,-,m n, rr IIry':'j Permit Number: AIRS ID Number: / / DOs I1:y [Leave blank unless APCD has already assigned a permit#and AIRS ID] I tl Section 2 - Requested Action 0 NEW permit OR newly-reported emission source ,Pell -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other(describe below) -OR- ❑ APEN submittal for update only(Please note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: 3 For transfer of ownership,a completed Transfer of Ownership Certification Form(Form APCD-104)must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: 23.33 MMBtu/hr mol sieve regeneration heater, fueled by natural gas for Train 2 (Heater will be limited to 70% annual fuel usage) Manufacturer: Tulsa Heaters Midstream Model No.: SHO12550 Serial No.: TBD Company equipment Identification No. (optional): H-2741 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: TBD z Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec-Feb: Mar-May: June-Aug: Sept-Nov: Are you reporting multiple identical boilers on this APEN? El Yes ✓❑ No If yes, please describe how the fuel usage will be measured for each boiler(i.e., one meter for all boilers or separate meters for each unit): �j COLORADO Form APCD-220- Boiler APEN - Revision 11/2017 2 I �''Heav,b Enerro°rtuv • q!, H1,. II,'; Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit#and AIRS ID] la= I,ali Section 4 - Stack Information Geographical Coordinates t' (Latitude/Longitude or UTM) 40.258034, -104.625389 Discharge Height Operator Temp. Flow Rate Velocity Above Ground Level Stack ID No. ('F) (ACFM) (ft/sec) (Feet) H-2741 25 479 7,370 39.1 Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑ Other(describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter(inches): 24 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other(describe): Section 5 - Fuel Consumption Information Requested Ann Design Input Rate Actual Annual Fuel Use4 sal Permit Limit (MMBTU/hr) (Specify Units) (Specify Units) 23.33 136.25 MMscf/yr From what year is the actual annual fuel use data? N/A Fuel consumption values entered above are for: Each Boiler 0 All Boilers ❑ N/A Indicate the type(s) of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) D Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash content: Sulfur Content: 0 Other(describe): Residue Gas Heating value (give units): 1 ,050 Btu/scf 4 If you are reporting multiple identical boilers on one APEN,be sure to clarify if the values in this section are on an individual boiler basis,or if the values represent total fuel usage for multiple boilers. 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 6 If fuel heating value is different than the listed assumed value, please provide this information in the"Other"field. COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 3 Permit Number: AIRS ID Number: / / CDj ' [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 6- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. .I:f' Is any emission control equipment or practice used to reduce emissions? ❑Yes ® No If yes please describe the control equipment AND state the overall control efficiency(%reduction): Y , Overall Control Efficiency Pollutant Control Equipment Description (%reduction in emissions) TSP(PM) PM10 PM2.5 Sox NOx CO VOC Other: From what year is the following reported actual annual emissions data? N/A Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary Fuel Emission Requested Annual Permit Uncontrolled Actual Annual Emissions Type Factor Emission"Limit(s)5 (natural gas, Pollutant Emission Source #2 d etc.))el, Factor (Specify Units) (AP-42,etc) fg. Uncontrolled (Tons/year)t d Controlled Uncontrolled (Tons/year) (Tons/year)a Controlled (Tons/year) Natural TSP(PM) 5.5 lb/MMscf Manufacturer 0.37 0.37 Gas PMio 5.5 Ib/MMscf Manufacturer 0.37 0.37 PM2.5 5.5 lb/MMscf Manufacturer 0.37 0.37 SOx 0.6 Ib/MMscf AP-42 0.04 0.04 NOx 50 Ib/MMscf AP-42 3.41 3.41 CO 84 lb/MMscf AP-42 5.72 5.72 VOC 5.5 Ib/MMscf AP-42 0.37 0.37 Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. VH,COLOR Form APCD-220- Boiler APEN - Revision 11/2017 4 I „sas;gym',;n, Iilh�r; Iy"I i aGv, Permit Number: AIRS ID Number: / / 005 Ifrt.,! [Leave blank unless APCD has already assigned a permit#and AIRS ID] J�a=, Il, ❑� Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. I,f'?i If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria " emissions table below: yP= Secondary Emission Requested Annual Permit -; Fuel TypeUncontrolled Actual Annual Emissions (#2 diesel, Pollutant 5 Emission Factor Emission Limit(s). waste oil, Factor Source Mfg. Uncontrolled Controlled Uncontrolled Controlled (Spcify Units) etc) Tons/ ear Tons/ ear (Tons/ ear (Tons/year) etc.) (Tons/year)) (Tons/year)) (Tons/year) ( Y ) TSP(PM) PM10 PM2.5 SOX NO. CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: Requested Annual Permit Actual Annual Emissions Pollutant Emission Limit(s) Controlled Uncontrolled Controlled (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP (PM) PMT() PM2.5 SOX NO. CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. COLORADO Form APCD-220- Boiler APEN - Revision 11/2017 5 I AV !f==`,., liK nor; Permit Number: AIRS ID Number: / I 005— [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 7 - Non-Criteria Pollutant Emissions Information 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? •„ Ill=a"" If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: ;1;1 Uncontrolled Uncontrolled Controlled Overall Emission Factor CAS Number Chemical Name Control Emission Source Actual Actual Factor Emissions Emissions? Efficiency (specify units) (AP-42,Mfg.etc) (Ibs/year) (lbs/year) Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. [y COLORADO Form APCD-220- Boiler APEN - Revision 11/2017 6 I L �i"u`6�"z;"`''', H 11:11 II,S II ry:� , Permit Number: AIRS ID Number: / I COS- Its` [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. "SZE5 -. • 51 V201 g Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (please print) Title Check the appropriate box if you want: l J Draft permit prior to public notice O Draft of the permit prior to issuance (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 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 or (303)692- APCD-SS-B1 3148 4300 Cherry Creek Drive South Denver, CO 80246-1530 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303)692-3150 COLORADO Form APCD-220- Boiler APEN - Revision 11/2017 7 I AV f=""°`°�"NSdtutb Fn.:.o�mev if .Ir Il�ri ELI VED \ 4v t��kY -4 2018 A CDPHE Boiler APEN - Form APCD-220 � It" Sources M, Air Pollutant Emission Notice (APEN) and ;; CO M� Application for Construction Permit drf All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. If your emission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www.colorado.gov/cdphe/apcd. Do not complete this form for the following source categories: - Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by natural gas or liquid petroleum gas(LPG). - Heaters or boilers with a design capacity less than or equal to 10 MMBtu/hour used solely for heating buildings for personal comfort that is fueled solely by natural gas or liquid petroleum gas (LPG). More information can be found in the APEN exempt/permit exempt checklist: https://www.colorado.gov/pacific/cdphe/apen-or-ai r-permit-exemptions. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: I U v v,G U2t.( AIRS ID Number: 2-3 /GI FU/ 00v v [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 - Administrative Information . Company Name': DCP Operating Company, LP Site Name: p �f�etteRt Lal ifal GasPweessing ant Z\,..40(11 l� Site Location Site Location: Section 2, Township 3N, Range 65W County: Weld La Salle, CO 80645 NAICS or sIc Code: 1321 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E-Mail Address2: RShankaran@DCPMidstream.com 1 Please use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by APCD via e-mail to the address provided. 380° AN COLORADO Form APCD-220- Boiler APEN - Revision 11/2017 1 I tl� 'n n;t Permit Number: AIRS ID Number: / / e r`, [Leave blank unless APCD has already assigned a permit Y+and AIRS ID] J�PI; Section 2 - Requested Action ❑ NEW permit OR newly-reported emission source -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other(describe below) -OR • APEN submittal for update only(Please note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info a Notes: 3 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: 25 MMBtu/hr stabilizer heater, fueled by natural gas for Train 1 Manufacturer: Heatec Model No.: HCI-18010-50-Q-G Serial No.: TBD Company equipment Identification No. (optional): H-19000 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: TBD ❑� Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec-Feb: Mar-May: June-Aug: Sept-Nov: Are you reporting multiple identical boilers on this APEN? ❑Yes ✓❑ No If yes, please describe how the fuel usage will be measured for each boiler(i.e., one meter for all boilers or separate meters for each unit): :COLORADO Form APCD-220- Boiler APEN - Revision 11/2017 2 I � Ilf' t • n., Permit Number: AIRS ID Number: / /' (e [Leave blank unless APCD has already assigned a permit#and AIRS ID] I,:f= Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.258034, -104.625389 Discharge Height Operator Temp. Flow Rate Velocity Above Ground Level P Stack ID No. c ) (ACFM) ) )(Feet) H-19000 320 Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑ Other(describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter(inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other(describe): Section 5 - Fuel Consumption Information Requested Ann Design Input Rate Actual Annual Fuel Use4 sal Permit Limit (MMBTU/hr) (Specify Units) (Specify Units) 25.0 208.57 MMscf/yr From what year is the actual annual fuel use data? N/A Fuel consumption values entered above are for: 0 Each Boiler ❑All Boilers D N/A Indicate the type(s)of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash content: Sulfur Content: 0 Other (describe): Residue Gas Heating value (give units): 1 ,050 Btu/saf 4 If you are reporting multiple identical boilers on one APEN,be sure to clarify if the values in this section are on an individual boiler basis,or if the values represent total fuel usage for multiple boilers. 5 Requested values wilt become permit limitations. Requested limit(s)should consider future process growth. 6 If fuel heating value is different than the listed assumed value, please provide this information in the"Other"field. COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 3 IIiS• Permit Number: AIRS ID Number: / I Ir`'' [Leave blank unless APCD has already assigned a permit#and AIRS ID] Fti2, Section 6- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Ia!; Is any emission control equipment or practice used to reduce emissions? D Yes ® No If yes, please describe the control equipment AND state the overall control efficiency(% reduction): Pollutant Control Equipment Description Overall Control Efficiency (%reduction in emissions) TSP(PM) PM'o PM2.5 SOx - NOx CO VOC Other: From what year is the following reported actual annual emissions data? N/A Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary Fuel Emission Requested Annual Permit Uncontrolled Actual Annual Emissions Type mit(s)5 (natural gas, Pollutant Emission Source #2 diesel, Factor (Specify Units) (AP-42,Mfg. Uncontrolled Controlled Uncontrolled Controlled etc.) etc) (Tons/year) (Tons/year) (Tons/year); (Tons/year) Natural TSP(PM) 7.6 Ib/MMscf AP-42 0.79 0.79 Gas PM10 7.6 Ib/MMscf AP-42 0.79 0.79 PM2.5 7.6 Ib/MMscf AP-42 0.79 0.79 SOx 0.6 Ib/MMscf AP-42 0.06 0.06 NOx 50 Ib/MMscf AP-42 5.21 5.21 CO 84 Ib/MMscf AP-42 8.76 8.76 VOC 5.5Ib/MMscf AP-42 0.57 0.57 Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. COLORADO Form APCD-220- Boiler APEN - Revision 11/2017 4 I 40341 ilr flay{ I^V' il:Ur� Permit Number: AIRS ID Number: / I 60 6, '1, [Leave blank unless APCD has already assigned a permit+r and AIRS ID] I,ti Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria emissions table below: Secondary Emission Requested Annual Permit ,I Fuel Type UncontrolledFactor Actual Annual Emissions (#2 diesel, Pollutant Emission Source Emission Limit(s)5 waste etc.) h (Specify Units) (AP etc)Fctor -42,Mf g U(Tons/year)a (Tons/yeard)7 U(Tons)year)a � l(Tons/ye ark) TSP(PM) PM-I0 PM2.5 SO), NOX CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: Requested Annual Permit Actual Annual Emissions Pollutant Emission'Limit(s)5 Uncontrolled Controlled? Uncontrolled Controlled (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP (PM) PM1 o PM2.5 SO,, NO„ CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. AV' COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 5 I f•i I„r;l ter, n =. Permit Number: AIRS ID Number: / / ( [Leave blank unless APCD has already assigned a permit#and AIRS ID] I�y` Section 7- Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteria ®Yes ❑ No NI pollutants (e.g. HAP- hazardous air pollutant)equal to or greater than 250 lbs/year? If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Uncontrolled Uncontrolled Controlled Overall Emission Factor Emission Actual Actual CAS Number Chemical Name Control Source Factor Emissions Emissions? Efficiency (AP-42,Mfg.etc) (specify units) Ps/year) (lbs/year) 110-54-3 Hexane NA 1.8E+00lb/MMscf AP-42 375.40 375.40 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. Note: Emissions shown are potential to emit emissions since this is a new source. Please include the emissions in the Notes to Permit Holder section of the permit. COLORADO 6 Form APCD-220 - Boiler APEN - Revision 11/2017 ir9r; Permit Number: AIRS ID Number: / / ce62 [Leave blank unless APCD has already assigned a permit r and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Ia^ 5/40/201 Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (please print) Title Check the appropriate box if you want: ❑✓ Draft permit prior to public notice Draft of the permit prior to issuance (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 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 or(303)692- APCD-SS-B1 3148 4300 Cherry Creek Drive South Denver, CO 80246-1530 Or visit the APCD website at: Make check payable to: https://www.colorado.Rov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303)692-3150 CO LOR ADO Form APCD-220 - Boiler APEN - Revision 11/2017 7 I Ncuy k En.lonmon+ , X1.4, ( 1LcEI\TD it MAY -4 2018 `°PHE Boiler APEN - Form APCD-220 Sources Air Pollutant Emission Notice (APEN) and CO Application for Construction Permit PP All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. If your emission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www.colorado.gov/cdphe/apcd. Do not complete this form for the following source categories: - Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by natural gas or liquid petroleum gas (LPG). - Heaters or boilers with a design capacity less than or equal to 10 MMBtu/hour used solely for heating buildings for personal comfort that is fueled solely by natural gas or liquid petroleum gas (LPG). More information can be found in the APEN exempt/permit exempt checklist: https://www.colorado.gov/pacific/cdphe/apen-or-air-permit-exemptions. This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: lS NEO+(05 AIRS ID Number: J 13 /gF(3P/ 0 V-1 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 - Administrative Information enn/ I g Company Name': DCP Operating Company, LP Ziorn ? oaliq Site Name: -S eft .Naterat-ess-Protessirig=P1ant - Site Location Site Location: Section 2, Township 3N, Range 65W County: Weld La Salle, CO 80645 NAICS or SIC Code: 1321 Mailing Address: (include zip code) 370 17th Street, Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E-Mail Address2: RShankaran@DCPMidstream.com 1 Please use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by APCD via e-mail to the address provided. WV COLORADO Form APCD-220- Boiler APEN- Revision 11/2017 1I Av 1;7""`"`°`"'�"` '� ��a�,�.,o��. I I�IMM�i. yr; Permit Number: AIRS ID Number: / / C7- IIy [Leave blank unless APCD has already assigned a permit#and AIRS ID] Isf; Section 2 - Requested Action E NEW permit OR newly-reported emission source -OR- ;I ❑ MODIFICATION to existing permit (check each box below that applies) r: ❑ Change fuel or equipment ❑ Change company name ❑ 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- ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: 3 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: 25 MMBtu/hr stabilizer heater, fueled by natural gas for Train 2 Manufacturer: Heatec Model No.: HCI-18010-50-Q-G Serial No.: TBD Company equipment Identification No. (optional): H-29000 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: TBD El Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec-Feb: Mar-May: June-Aug: Sept-Nov: Are you reporting multiple identical boilers on this APEN? ❑Yes ❑✓ No If yes, please describe how the fuel usage will be measured for each boiler(i.e., one meter for all boilers or separate meters for each unit): p COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 2 I �� ≥ nEN IIsl! !nG, !IuV, Permit Number: AIRS ID Number: / / OO3 � !`f [Leave blank unless APCD has already assigned a permit#and AIRS ID] rvs: Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) I'�! ' 40.258034, -104.625389 Operator Discharge Height Temp. Flow Rate Velocity Above Ground Level Stack ID No. ('F) (ACFM) (ft/sec) (Feet) H-29000 320 Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑ Other(describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter(inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other(describe): Section 5 - Fuel Consumption Information Requested Annual Permit Design Input Rate Actual Annual Fuel Use's Limits (MMBTUIhr) (Specify Units) (Specify Units) 25.0 208.57 MMscf/yr From what year is the actual annual fuel use data? N/A Fuel consumption values entered above are for: E Each Boiler ❑All Boilers ❑ N/A Indicate the type(s)of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash content: Sulfur Content: ❑� Other(describe): Residue Gas Heating value (give units): 1 ,050 Btu/scf 4 If you are reporting multiple identical boilers on one APEN,be sure to clarify if the values in this section are on an individual boiler basis,or if the values represent total fuel usage for multiple boilers. 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 6 If fuel heating value is different than the listed assumed value, please provide this information in the"Other"field. LORDO Form APCD-220 - Boiler APEN - Revision 11/2017 3 �]pp� °CO '°A'` Ica++n 6 En.rc p. I IuV�I y, Permit Number: AIRS ID Number: / /O0? [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 6- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. L;il; Is any emission control equipment or practice used to reduce emissions? ❑Yes ® No If yes, please describe the control equipment AND state the overall control efficiency(% reduction): y,,,;; Pollutant Control Equipment Description Overall Control Efficiency (%reduction in emissions) TSP(PM) PA() PM2.5 Sox NOx CO VOC Other: From what year is the following reported actual annual emissions data? N/A Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary Fuel Emission Requested Annual Permit Uncontrolled Type Actual Annual Emissions (natural gas, Pollutant Emission Factor Emission Limit(s) Source #2 diesel, Factor (Specify Units) (AP-42,Mfg. Uncontrolled Controlled Uncontrolled Controlled etc.) etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) Natural TSP (PM) 7.6 Ib/MMscf AP-42 0.79 0.79 Gas PMio 7.6 lb/MMscf AP-42 0.79 0.79 PM2.5 7.6 Ib/MMscf AP-42 0.79 0.79 SOx 0.6 Ib/MMscf AP-42 0.06 0.06 NOx 50 Ib/MMscf AP-42 5.21 5.21 CO 84 Ib/MMscf AP-42 8.76 8.76 VOC 5.5 IblMMscf AP-42 0.57 0.57 Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 4 I � Fn.�H..,t. :"'°°` H WN a onmeni liar ti', Permit Number: AIRS ID Number: / / ? zl [Leave blank unless APCD has already assigned a permit#and AIRS ID] J Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria . emissions table below: a'r Secondary Emission Requested Annual Permit ,I Fuel TypeUncontrolled Actual Annual Emissions q Facthr (#2 diesel, Pollutant Emission Source Emission Limit(s)Ftor 5 waste oil, (Specacfy Units) (AP-42,Mfg. Uncontrolled Controlled? Uncontrolled Controlled etc.) etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP (PM) PMT o PM2.5 SOx NOx CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: Requested Annual Permit Actual Annual Emissions Emission Limit(s)5 Pollutant Uncontrolled Controlled Uncontrolled Controlled (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP (PM) PM10 PM2.5 SOx NOx CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. COLORADO Form APCD-220- Boiler APEN - Revision 11/2017 5 I 1=7.17,V.;'"„,, III; Permit Number: AIRS ID Number: / / (3O-4 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 7 - Non-Criteria Pollutant Emissions Information Lti 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 El No ,laa If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: ;3;! Uncontrolled Uncontrolled Controlled Overall Emission Emission Factor Actual Actual CAS Number Chemical Name Control Source Efficiency Factor (AP-42,Mfg.etc) Emissions Emissions (specify units) (Ibs/year) (fbs/year) 110-54-3 Hexane NA 1.8E+001b/MMscf AP-42 375.40 375.40 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. Note: Emissions shown are potential to emit emissions since this is a new source. Please include the emissions in the Notes to Permit Holder section of the permit. :COLOADO Form APCD-220- Boiler APEN - Revision 11/2017 6 I 'k NeoRn�`'N l�F II Y' Permit Number: AIRS ID Number: / / c '7 Ili; [Leave blank unless APCD has already assigned a permit II 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. „s Imo, 5/4 /zor$ Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (please print) Title Check the appropriate box if you want: Q Draft permit prior to public notice ❑� Draft of the permit prior to issuance (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 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 or(303)692- APCD-SS-B1 3148 4300 Cherry Creek Drive South Denver, CO 80246-1530 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 coLoenoo Form APCD-220 - Boiler APEN - Revision 11/2017 7 I °`R°'= il'l I I;s' s:. Ifl R>LC\-`'I''ll' G 'I:318 CDRHE` Boiler APEN - Form APCD-220 PwAft 1! Air Pollutant Emission Notice (APEN) and tiS�urc ' Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN ,io,:, updates. An application with missing information may be determined incomplete and may be returned or result in :I):; longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. If your emission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www.colorado.gov/cdphe/apcd. Do not complete this form for the following source categories: - Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by natural gas or liquid petroleum gas (LPG). - Heaters or boilers with a design capacity less than or equal to 10 MMBtu/hour used solely for heating buildings for personal comfort that is fueled solely by natural gas or liquid petroleum gas(LPG). More information can be found in the APEN exempt/permit exempt checklist: https://www.colorado.gov/pacific/cdphe/apen-or-air-permit-exemptions. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: I(l u V E-ll`"-(-Q. AIRS ID Number: L 2; /GI FRR' 00&/ [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 - Administrative Information e; er' ,I S'1?- Company Name': DCP Operating Company, LP �Site Name: Sefton raf� Notua�P iqt Q>4(Y-1\ G`s �i , Site Location Site Location: Section 2, Township 3N, Range 65W County: Weld La Salle, CO 80645 NAICS or SIC Code: 1321 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E-Mail Address2: RShankaran@DCPMidstream.com 1 Please use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by APCD via e-mail to the address provided. 380087 COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 1 I A�1O47,1=4:1 u«r'i Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit#and AIRS ID] ;Li'•I Section 2 - Requested Action ✓❑ NEW permit OR newly-reported emission source -OR ❑ MODIFICATION to existing permit (check each box below that applies) °i'€ ❑ Change fuel or equipment ❑ Change company name ❑ 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- ❑ Limit Hazardous Air Pollutants (HAPs)with a federally-enforceable limit on Potential To Emit(PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: 3 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: 53.93 MMBtu/hr demethanizer hot oil heater, fueled by natural gas for Train 1 Manufacturer: Tulsa Heaters Midstream Model No.: SHO4000 Serial No.: TBD Company equipment Identification No. (optional): H-1781 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: TBD ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec-Feb: Mar-May: June-Aug: Sept-Nov: Are you reporting multiple identical boilers on this APEN? ❑Yes ❑✓ No If yes, please describe how the fuel usage will be measured for each boiler(i.e., one meter for all boilers or separate meters for each unit): COORADO Form APCD-220- Boiler APEN - Revision 11/2017 2 �� °"L` °`""` MWNb En�ta°nnxna II Ivry; Permit Number: AIRS ID Number: IIA,i [Leave blank unless APCD has already assigned a permit#and AIRS ID] 11sif Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.258034, -104.625389 Discharge Height Operator Temp. Flow Rate Velocity Above Ground Level Stack ID No. ('F) (ACFM) (ft/sec) (Feet) H-1781 32.6 415 18,992 32.9 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑ Other(describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter(inches): 42 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other(describe): Section 5 - Fuel Consumption Information Requested Ann Design Input Rate Actual Annual Fuel Use4 5al Permit Limit (MMBTU/hr) (Specify Units) (Specify Units) 53.93 449.93 MMscf/yr From what year is the actual annual fuel use data? N/A Fuel consumption values entered above are for: El Each Boiler ❑All Boilers ❑ N/A Indicate the type(s)of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) [' Coal Heating value: BTU/lb Ash content: Sulfur Content: ❑✓ Other(describe): Residue Gas Heating value (give units): 1 ,050 Btu/scf 4 If you are reporting multiple identical boilers on one APEN,be sure to clarify if the values in this section are on an individual boiler basis, or if the values represent total fuel usage for multiple boilers. 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 6 If fuel heating value is different than the listed assumed value,please provide this information in the"Other"field. COLOR ADO 3 Form APCD 220 Boiler APEN Revision 11/2017 it f,;l 'IN Ilry�l Permit Number: AIRS ID Number: / /00� Il;y [Leave blank unless APCD has already assigned a permit#and AIRS ID] Ia'i Section 6- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Ct! Is any emission control equipment or practice used to reduce emissions? ❑ Yes ® No Imo:; If yes, please describe the control equipment AND state the overall control efficiency(% reduction): Pollutant Control Equipment Description Overall Control Efficiency (%reduction in emissions) TSP (PM) PMt o PM2.5 SOX NO. CO VOC Other: From what year is the following reported actual annual emissions data? N/A Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary Fuel Emission _ Requested Annual Permit Uncontrolled Actual Annual Emissions Emission (natural gas, Pollutant Type Factor Emission Limit(s)5 Source Factor #2 diesel, (Specify Units) (AP Mfg. Uncontrolled etc.) etc) (Tons/year) Controlled Uncontrolled(Tons year) (Tons year) Controlled kl(Tons/year) Natural TSP(PM) 0.0052 Ib/MMBtu Manufacturer 1.23 1.23 Gas PMio 0.0052 Ib/MMBtu Manufacturer 1.23 1.23 PM2.5 0.0052 Ib/MMBtu Manufacturer 1.23 1.23 SOX 0.6 Ib/MMscf AP-42 0.13 0.13 NOX 0.034Ib/MMBtu Manufacturer 8.03 8.03 CO 84 Ib/MMscf AP-42 18.90 18.90 VOC 5.5 lb/MMscf AP-42 1.24 1.24 Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 4 I � II dc,, Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit#and AIRS ID] Id r ❑� Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. I,i: If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria emissions table below: Secondary Requested Annual Permit Fuel Type Uncontrolled Emission Actual Annual Emissions (#2 diesel, Pollutant Emission Source Emission Limit(s)5 Factor waste oil, (Specify Units) (AP-42• ,Mfg. Uncontrolled Controlled Uncontrolled Controlled etc.) etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP (PM) PM-lo PM2.5 SOX NO„ CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: Requested Annual Permit Actual Annual Emissions Pollutant Emission Limit(s) Controlled Uncontrolled Controlled (Tons/year) (Tons/year) (Tons/year) (Torts/year) TSP (PM) PM1 o PM2.5 SOX NO), CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. COLORADO Form APCD-220- Boiler APEN - Revision 11/2017 5 I � °"'""�Z p'"1""MutNb Enuy pnmen� liar Permit Number: AIRS ID Number: / /CX.) l'y. [Leave blank unless APCD has already assigned a permit#and AIRS ID] IP=' Section 7- Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants (e.g. HAP- hazardous air pollutant)equal to or greater than 250 lbs/year? ®Yes ❑ No y;r If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Uncontrolled Uncontrolled Controlled Overall Emission Factor Emission Actual Actual CAS Number Chemical Name Control Source Factor Emissions Emissions Efficiency units) (AP-42,Mfg.etc) (lbs/year)(specify ( y ) Ps/year) 110-54-3 Hexane N/A 1.8E+00Ib/MMscf AP-42 809.90 809.90 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Note: Emissions shown are potential to emit emissions since this is a new source. Please include the emissions in the Notes to Permit Holder section of the permit. COLORADO =7= Form APCD-220- Boiler APEN - Revision 11/2017 6 I •�¢� , I 1y3, ,In II+'v le-- 1u4., Permit Number: AIRS ID Number: / /0C) r(! [Leave blank unless APCD has already assigned a permit A and AIRS ID] I!fa! Section 8 - Applicant Certification n ; I hereby certify that all information contained herein and information submitted with this application is complete, true and correct.(Q.199 . 5/4 /Z0/80 Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (please print) Title Check the appropriate box if you want: ❑r Draft permit prior to public notice Draft of the permit prior to issuance (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 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 or (303) 692- APCD-SS-B1 3148 4300 Cherry Creek Drive South Denver, CO 80246-1530 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 COLORADO Form APCD-220- Boiler APEN - Revision 11/2017 7 I e ,;o�'n, leg -421 :; I&Li , �ler APEN - Form APCD-220 'sour�e,i �O1 I�•. • Air Pollutant Emission Notice (APEN) and CO. Application for Construction Permit be t returned s, or result in All sections of this APEN and application must may completed incomplete iandgmayilities, including APEN longer . An application with times. missing longer application processing You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. If your emission booths, does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint mining operations, engines, etc.). In addition, the of all available APEN forms EN (Form APCD-200) an be available if the the AirPolluti Pollution options will not satisfy your reporting needs. Control Division (APCD)website at: www Colorado Qov/cdphe/acd. Do not complete this form for the following source categories: Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by- natural gas or liquid petroleum gas(LPG). tu/hour used solely for- Heaters or boilers with a desin t capacity s fueleds than or equal to 10 solely by natural gas or lliiquid petroleum gas (LPG)heating buildings for personal comfor that More information can be found in the APEN exempt/Permit exempt checklist: htt s://www.colorado. ov/ acific/cd he/a en-or-air- ermit-exem lions.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 No�g3,ficant Part A,II�C�for revised APEN requions increase, increase Pementson, new equipment, change in fuel type, etc.). See Regulation AIRS ID Number: I�� /�ppj 0661 Permit Number: ��u V 64.4Cj [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 - Administrative Information B/a AB- Company Name': DCP Operating Company, LP ,4ho� G �tc„y -, Site Name: n lat i-6as#? mac Site Location Site Location: Section 2, Township 3N, Range 65W County: Weld La Salle, CO 80645 NAICS or SIC Code: 1321 Mailing Address: 370 17th Street, Suite 2500 (Include Zip Code) Permit Contact: Roshini Shankaran Denver, CO 80202 Phone Number: (303) 605-2039 E-Mail Address2: RShankaran@DCPMidstream.com i Please use the full,legal company name registered with the Colorado Secretary of Setatte rThis is the company name that will tional k. appear on all documents issued by the APCD.Any ychanges a g will require uired diy APCD p a e-mail to the address provided. ap2 Permits,exemption letters,and any processing g invoices .COLORADO 38008 H�OLOR DO V.V. �HFa1N6(,fVF,ONmfN Form APCD-220- Boiler APEN - Revision 11/2017 [Leave blank unless APCD has already assigned a permit#and AIRS ID] L,ra Section 2 - Requested Action E NEW permit OR newly-reported emission source -OR ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other(describe below) -OR • APEN submittal for update only(Please note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info a Notes: 3 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: 53.93 MMBtu/hr demethanizer hot oil heater, fueled by natural gas for Train 2 Manufacturer: Tulsa Heaters Midstream Model No.: SHO4000 Serial No.: TBD Company equipment Identification No. (optional): H-2781 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: TBD E Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec-Feb: Mar-May: June-Aug: Sept-Nov: Are you reporting multiple identical boilers on this APEN? ❑Yes El No If yes, please describe how the fuel usage will be measured for each boiler(i.e., one meter for all boilers or separate meters for each unit): jCOLORADO Form APCD-220- Boiler APEN - Revision 11/2017 2 l �I„ 6E;;= [Leave blank unless APCD has already assigned a permit#and AIRS ID] IS! Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) y; 40.258034, -104.625389 Discharge Height Operator Temp. Flow Rate Velocity Above Ground Level Stack ID No. ('r=) (acFM) (ft/sec) (Feet) H-2781 32.6 415 18,992 32.9 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑ Other(describe): Indicate the stack opening and size: (check one) E Circular Interior stack diameter(inches): 42 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other(describe): Section 5 - Fuel Consumption Information Requested Ann Design Input Rate Actual Annual Fuel Use4 5al Permit Limit5 (Specify Units) (Specify Units) 53.93 449.93 MMscf/yr From what year is the actual annual fuel use data? N/A Fuel consumption values entered above are for: Each Boiler ❑All Boilers ❑ N/A Indicate the type(s)of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash content: Sulfur Content: E Other(describe): Residue Gas Heating value (give units): 1 ,050 Btu/scf 4 If you are reporting multiple identical boilers on one APEN,be sure to clarify if the values in this section are on an individual boiler basis,or if the values represent total fuel usage for multiple boilers. 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 6 If fuel heating value is different than the listed assumed value, please provide this information in the"Other"field. COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 3 I �! [Leave blank unless APCD has already assigned a permit f and AIRS ID] Section 6- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ® No I'!! II�F; If yes, please describe the control equipment AND state the overall control efficiency(% reduction): Pollutant Control Equipment Description Overall Control Efficiency (%reduction in emissions) TSP (PM) PM10 PM2.5 SOx NOx CO VOC Other: - From what year is the following reported actual annual emissions data? N/A Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary Fuel Emission Requested Annual Permit Uncontrolled AType ctual Annual Emissions 5 (natural gas, Pollutant Emission Factor Emission Limits) Source Fctor #2diesel, (Specify Units) (AP-42tc Mfg. Uncontrolled d (Tons/year) Uncontrolled ontrolled (Tons/year) Control(Tons/year) Natural TSP(PM) 0.0052 Ib/MMBtu Manufacturer 1.23 1.23 Gas PM10 0.0052 lb/MMBtu Manufacturer 1.23 1.23 PM2.5 0.0052 lb/MMBtu Manufacturer 1.23 1.23 SOx 0.6 Ib/MMscf AP-42 0.13 0.13 NOx 0.0344Ib/MMBtu Manufacturer 8.13 8.13 CO 84 Ib/MMscf AP-42 18.90 18.90 VOC 5.5 lb/MMscf AP-42 1.24 1.24 Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 4 I AV '°=77,1!°1L',°,;', [Leave blank unless APCD has already assigned a permit#and AIRS ID] 2,' ❑� Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. if multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria `5 emissions table below: ' Secondary r-+ Uncontrolled Emission Requested Annual Permit 1-e 'I Fuel Type Emission Factor Actual Annual Emissions Emission Limit(s)5 (#2 diesel, Pollutant Source waste oil, Factor (AP-42,Mfg. Uncontrolled Controlled7 Uncontrolled Controlled etc.) (Specify Units) etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP(PM) PM10 PM2.5 SOX NO,, CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: Requested Annual Permit Actual Annual Emissions Pollutant Emission Limit(s)5 Uncontrolled Controlled7 Uncontrolled Controlled (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP(PM) PM10 PM2.s SOX NO,, CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. COLORADO Aire Form APCD-220 - Boiler APEN - Revision 11/2017 5 I [Leave blank unless APCD has already assigned a permit#and AIRS ID] i(L Section 7- Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants (e.g. HAP- hazardous air pollutant)equal to or greater than 250 lbs/year? ®Yes ❑ No 'llla, If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Uncontrolled Uncontrolled Controlled Overall Emission Emission Factor Actual Actual CAS Number Chemical Name Control Source Factor Emissions Emissions? Efficiency (AP-42 Mfg.etc) (specify units) (it's/year) (lbs/year) 110-54-3 Hexane N/A 1.8E+00Ib/MMscf AP-42 809.90 809.90 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. Note: Emissions shown are potential to emit emissions since this is a new source. Please include the emissions in the Notes to Permit Holder section of the permit. COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 6 I AV !lIT .; %N N irte En [Leave blank unless APCD has already assigned a permit it and AIRS ID] ,ti. Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. 1.2? pM 5/4 12ots Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (please print) Title Check the appropriate box if you want: ❑r Draft permit prior to public notice 0 Draft of the permit prior to issuance (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 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 or(303)692- APCD-SS-B1 3148 4300 Cherry Creek Drive South Denver, CO 80246-1530 Or visit the APCD website at: Make check payable to: https://www.colorado.Qov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 7 I µutt�b E"t o"moni ii Condensate Storage Tank(s) APEN .1 �'`� CDPHE� �y A2p\�'>?-., �* Form APCD-205 �� , � O.` � Air Pollutant Emission Notice (APEN) and Application for Construction Permit 5 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 all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/pacific/cdphe/air-permits. This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: lSNC 04U AIRS ID Number: 12-3 /01F'I B / G16 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 - Administrative Information per Company Name': DCP Operating Company, LP (acS Q� Site Name: . eiton , t#uraLJ3aS_P_ocessing=P{a-nt ' J Site Location: Site Location Section 2, Township 3N, Range 65W County: Weld La Salle, CO 80645 NAICS or SIC Code: 1321 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E-Mail Address2: RShankaran@DCPMidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by APCD via e-mail to the address provided. COLORADO Form APCD-205 - Condensate Storage Tank(s)APEN - Revision 07/2017 1 I Herein b Enn onaeni 380089 .._...__.. ,v [Leave blank unless APCD has already assigned a permit#and AIRS ID] ;Ila Section 2 - Requested Action ❑ NEW permit OR newly-reported emission source ✓❑ 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 ❑ 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 - Li APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info Et Notes: 3 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. Section 3 - General Information General description of equipment and purpose: Four 1,000 bbl stabilized condensate tanks for Train 1. ID:TANKS-1 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: TBD Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Storage tank(s) located at: ❑ Exploration Et Production(EEtP)site 0 Midstream or Downstream (non EEtP)site Will this equipment be operated in any NAAQS nonattainment area? 0 Yes ❑ No Are Flash Emissions anticipated from these storage tanks? ❑ Yes No Is the actual annual average hydrocarbon liquid throughput≥ 500 bbl/day? ✓❑ Yes ❑ No If"yes", identify the stock tank gas-to-oil ratio: 0.00012 m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) ❑ Yes ❑✓ No 805 series rules? If so, submit Form APCD-105. Are you requesting≥6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual ❑ Yes E No emissions≥6 ton/yr(per storage tank)? COLORADO Form APCD 205 Condensate Storage Tank(s)APEN Revision 07/2017 2 I y ----------------- v [Leave blank unless APCD has already assigned a permit a and AIRS ID] Lf!, Section 4 - Storage Tank(s) Information r Actual Annual Amount Requested Annual Permit Limit' (bbl/year) (bbl/year) A Nci /j / y� in `1 Condensate Throughput: 642509 1,9' 1 ,t� )O From what year is the actual annual amount? N/A Average API gravity of sales oil: degrees RVP of sales oil: Tank design: Fixed roof El Internal floating roof El External floating roof Storage #of Liquid Manifold Storage Total Volume of Installation Date of Most Date of First Tank ID Vessels in Storage Tank Storage Tank Recent Storage Vessel in Production (bbl) Storage Tank(month/year) (month/year) TBD 4 4,000 Wells Serviced by this Storage Tank or Tank Battery5 (EEtP Sites Only) API Number Name of Well Newly Reported Well - - ❑ - - ❑ 4 Requested values will become permit limitations. Requested limit(s)should consider future growth. 5 The EEtP Storage Tank APEN Addendum (Form APCD-212)should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.258034, -104.625389 Operator Stack Discharge Height Above Temp. Flow Rate Velocity ID No. Ground Level (feet). (°F) (ACFM) (ft/sec) TANKS-1 Indicate the direction of the stack outlet: (check one) ❑ Upward ❑Downward ❑ Upward with obstructing raincap ❑ Horizontal El Other(describe): Indicate the stack opening and size: (check one) ❑Circular Interior stack diameter(inches): ❑Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑Other(describe): pp COLORADO Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 3 1 mV';',=lar. [Leave blank unless APCD has already assigned a permit#and AIRS ID] 1aE' Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor Size: Make/Model: ❑ Recovery Unit(VRU): Requested Control Efficiency: % VRU Downtime or Bypassed (emissions vented): % Pollutants Controlled: VOC and HAPs Rating: MMBtu/hr Type: Enclosed Combustor Make/Model: 1 T B D ❑ Combustion Requested Control Efficiency: 95 % Device: Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: Waste Gas Heat Content: 3,677 Btu/scf Constant Pilot Light: ❑✓ Yes ❑ No Pilot Burner Rating: 0.06 MMBtu/hr Description of the closed loop system: ❑ Closed Loop System Jo 10— Pollutants Controlled: Voci}-bkPl owntime-onj -- r er:_`C)is Descripdo p--pianw are— a}1 lolls/ Control Efficiency Requested:'-g % Section 7 -Gas/Liquids Separation Technology Information (EEtP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Describe the separation process between the well and the storage tanks: COLORADO Form APCD-205 - Condensate Storage Tank(s)APEN - Revision 07/2017 4 Q��j� �,. dn, v [Leave blank unless APCD has already assigned a permit fi and AIRS ID] I a'I `I;A' Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form°. 'l•₹; If multiple emission control methods were identified in Section 6, the following table can be used to state the overall ;I '' (or combined)control efficiency(%reduction): 17. Overall Re uested Control Pollutant Description of Control Method(s) Efficiency iiti (%reduction in emissions) ter VOC Tank emissions controlled by ECD,er isseasscuited - 95% C � I /� NOx if,L.;I 1D/1/I CO HAPs Tank emissions controlled by ECD.€xnissieau fectloZanGFlere:A ng-EGQ.dowrt6me. 95% C Other: From what year is the following reported actual annual emissions data? N/A Criteria Pollutant Emissions Inventory Emission Factor6 Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled ' 0 Basis Units (AP-42, Emissions Emissions Emissions Emissions l0' Mfg.etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) elli,� VOC 1.01 E-01 Ib/bbl TANKS 4.09d 82.Gr)ci/, I 9-3 Li,TL— y,"'- l NOx 0.068 lb/MMBtu AP-42 -071-€ .51,(1 •' y( CO 0.310 Ib/MMBtu AP-42 0`1 U,' .G6fr I Non-Criteria Reportable Pollutant Emissions Inventory l Chemical Emission Factor° Actual Annual Emissions Chemical Name Abstract Source Uncontrolled Controlled (CAS ) Uncontrolled ( ) Units (AP-42, Emissions Emissions Number Basis Mfg. etc) (Pounds/year)g ( y ) (Pounds/year) Benzene 71432 0.0013 lb/bbl TANKS 4.09d ...II it 0?r . D. Toluene 108883 0.0037 lb/bbl TANKS 4.09d " -';l 33F Ethylbenzene 100414 0.0003 lb/bbl TANKS 4.09d G-pC_ e;s- Xylene 1330207 0.0028 lb/bbl TANKS4.09d S-IIC SCE n-Hexane 110543 0.0072 lb/bbl TANKS 4.09d '1) 7 r_a 2,2,4- 540841 10 ) Trimethylpentane ti 4 Requested values will 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. Note: Emissions shown are potential to emit emissions since this is a new source. Please include the emissions in the Notes to Permit Holder section of the permit. p COLORADO Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 5 I Q•1 fEei. nvro em [Leave blank unless APCD has already assigned a permit#r and AIRS ID] �tla"I Section 9 - Applicant Certification ! I hereby certify that all information contained herein and information submitted with this application is complete, true y ' and correct. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that this source is IIF' and will be operated in full compliance with each condition of the applicable General Permit. 5/4/ZO1S Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name(print) Title Check the appropriate box to request a copy of the: ❑� Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of$250, if applicable, to: Colorado Department of Public Health and Small Business Assistance Program Environment (303)692-3175 or(303) 692-3148 Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303)692-3150 A.A. ;COLORADO Form APCD-205 - Condensate Storage Tank(s)APEN - Revision 07/2017 6 I ma ,,t n tk7Z, -4 2611 CDPHE Condensate Storage Tank(s) APED` ., u ;orce , M T Form APCD-205 s � Ali Air Pollutant Emission Notice (APEN) and Application for Construction Permit ;Iral I�. 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 all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/pacific/cdphe/air-permits. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 15 t 134 (6 AIRS ID Number: 17-3 /6fF pg / a (I [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 - Administrative Information P-er Company Name': DCP Operating Company, LP ass C Site Name: ►heitor-NstrararGas rocessing an Site Location Site Location: Section 2, Township 3N, Range 65W county: Weld La Salle, CO 80645 NAICS or SIC Code: 1321 Mailing Address: (Include zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E-Mail Address2: RShankaran@DCPMidstream.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 will be issued by APCD via e-mail to the address provided. COLORADO Form APCD-205 - Condensate Storage Tank(s)APEN - Revision 07/2017 1 I 430. 7 HCJIN b Enr�ocvoeN 380000 v - - ily. [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly-reported emission source 1 ; ❑ Request coverage under traditional construction permit ice, ❑ 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 ❑ 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 ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info Ft Notes: 3 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Four 1,000 bbl stabilized condensate tanks for Train 2. ID:TANKS-2 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: TBD Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Storage tank(s) located at: ❑ Exploration Et Production(EEtP)site ❑ Midstream or Downstream (non EEtP)site Will this equipment be operated in any NAAQS nonattainment area? ❑✓ Yes ❑ No Are Flash Emissions anticipated from these storage tanks? ❑ Yes No Is the actual annual average hydrocarbon liquid throughput≥ 500 bbl/day? 0 Yes ❑ No If"yes", identify the stock tank gas-to-oil ratio: 0.00012 m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) ❑ Yes i No 805 series rules?If so, submit Form APCD-105. Are you requesting≥6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual ❑ Yes / No emissions≥6 ton/yr(per storage tank)? ,COLORADO Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 2 I t xe ;tl [Leave blank unless APCD has already assigned a permit k and AIRS ID] I�tl:j Section 4 - Storage Tank(s) Information Actual Annual Amount Requested Annual Permit Limit4 (bbl/year) (bbl/year) pe r e/ 1 Condensate Throughput: 1,642,500 VD-1,00 r. From what year is the actual annual amount? Average API gravity of sales oil: degrees RVP of sales oil: Tank design: ✓❑ Fixed roof ❑ Internal floating roof ❑ External floating roof Storage #of Liquid Manifold Storage Total Volume of Installation Date of Most Date of First Tank ID Vessels in Storage Tank Storage Tank Recent Storage Vessel in Production (bbl) Storage Tank(month/year) (month/year) TBD 4 4,000 • Wells Serviced by this Storage Tank or Tank Battery5(EEtP Sites Only) API Number Name of Well Newly Reported Well 4 Requested values will become permit limitations. Requested limit(s)should consider future growth. 5 The EEtP Storage Tank APEN Addendum (Form APCD-212)should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.258034, -104.625389 Operator Stack Discharge Height Above Temp. Flow Rate Velocity ID No. Ground Level (feet) (°F) (ACFM) (ft/sec) TANKS-2 Indicate the direction of the stack outlet: (check one) ❑Upward ❑Downward ❑Upward with obstructing raincap ❑Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) ❑Circular Interior stack diameter(inches): ❑Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑Other(describe): �j COLORDO Form APCD-205 - Condensate Storage Tank(s)APEN - Revision 07/2017 3 Lil h `.oA [Leave blank unless APCD has already assigned a permit k and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor Size: Make/Model: ❑ Recovery Unit(VRU): Requested Control Efficiency: % VRU Downtime or Bypassed (emissions vented): % Pollutants Controlled: VOC and HAPs Rating: MMBtu/hr p Type: Enclosed Combustor Make/Model:TB D ❑ Combustion Requested Control Efficiency: 95 % Device: Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: Waste Gas Heat Content: 3,877 Btu/scf Constant Pilot Light: ❑✓ Yes ❑ No Pilot Burner Rating: 0.06 MMBtu/hr Description of the closed loop system: ❑ Closed Loop System Ai° lfc,V- Pollutants Controlled: .Vee A ECD D\ Other: Description: -P1an# fare °( Control Efficiency Requested:�5� 1g • r b Section 7-Gas/Liquids Separation Technology Information (EEtP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Describe the separation process between the well and the storage tanks: COLORADO Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 4 I AV !n1==`,,,=`,,, „y,i [Leave blank unless APCD has already assigned a permit ft and AIRS ID] ai Ivi` Section 8 - Emissions Inventory Information IJI 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 ICS; (or combined)control efficiency(%reduction): Overall Requested Control 1-`” Pollutant Description of Control Method(s) Efficiency (%reduction in emissions) _.1 17‘24-1 a VOC Tank emissions controlled by ECD.to ua tsiat# 95% ,�� NOx --- - , Y t , Po CO er RAPS Tank emissions controlled by ECD.E-mtssionssouted4o3Jaa4Elare during ECD_Osw imt e, 95% Other: I From what year is the following reported actual annual emissions data? N/A Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor6 Actual Annual Emissions Emission Limit(s)4 �� Pollutant a Source Uncontrolled Controlled` Uncontrolled Controlled Uncontrolled ' �� Basis Units (AP-42, Emissions Emissions Emissions Emissions 7:.,;,..\t, Mfg.etc) (Tons/ ear (Tons/year) (Tons/year) 9 y ) (Tons/year) (�►� y ) (T !/ ) �' ,C VOC 1.01 E-01 lb/bbl TANKS 4.09d ,, t,$I Vii,S q ' .1',-e 0.068 lb/MMBtu AP-42 -ed ,,(i § .'7 )!(mot �' NOx �;� e .,. CO 0.310 lb/MMBtu AP-42 `0 IT,lr .13E. '1'.`;';7 e Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor6 Actual Annual Emissions Chemical Name Abstract Source Uncontrolled Controlled t (CAS ) Uncontrolled ( ) Units (AP-42, Emissions Emissions7 Number Basis Mfg. etc) (Pounds/year) (Pounds/year) Benzene 71432 0.0013 lb/bbl TANKS 4.09d ;A-No i . - Toluene 108883 0.0037 lb/bbl ,TANKS 4.09d ?w 1 333 Ethylbenzene 100414 0.0003 lb/bbl TANKS 4.09d !;4 ..2 Xylene 1330207 0.0028 lb/bbl TANKS 4.09d 5I10 �G n-Hexane 110543 0.0072 lb/bbl TANKS 4.09d 311 5 2,2,4- 540841 -1 Trimethylpentane 4 Requested values will 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. Note: Emissions shown are potential to emit emissions since this is a new source. Please include the emissions in the Notes to Permit Holder section of the permit. pQ� . !COLORADO Form APCD-205 - Condensate Storage Tank(s)APEN - Revision 07/2017 5 I A N E d ay [Leave blank unless APCD has already assigned a permit;`and AIRS ID] 'I RP; 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 1!; and will be operated in full compliance with each condition of the applicable General Permit. Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name(print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance �✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of$250, if applicable, to: Colorado Department of Public Health and Small Business Assistance Program Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303)692-3150 AV COLORADO Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 6 I m� ikkk,( _ 42 CDPHE Hydrocarbon Liquid Loading APEN - Form APCD-208 ` 5l `' Air Pollutant Emission Notice (APEN) and COt'Jr �+► If' . Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN 12.f 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 fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-2OO) 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: Ig J U F 6°- Q5 AIRS ID Number: �Z3 /qFg i j 2 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Company equipment Identification: LO [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': DCP Operating Company, LP S/a- Site Name: af-C-a',-Processing=P}ant- j orn �`r _3 Site Location Site Location: Section 2, Township 3N, Range 65W County: Weld La Salle, CO 80645 NAICS or SIC Code: 1321 Mailing Address: (Include Zip code) 370 17th Street, Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E-Mail Address2: RShankaran@DCPMidstream.com 'Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits,exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. COLORADO Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017 1 38009 1 [Leave blank unless APCD has already assigned a permit#and AIRS ID] LE• Section 2- Requested Action ❑✓ NEW permit OR newly-reported emission source ✓ Request coverage under constructionpermit Request coverage under General Permit GP07 ❑ q g ❑ q g 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) 9 Change fuel or equipment ❑ Change company name ❑ Change permit limit 9 Transfer of ownership' 9 Other(describe below) -OR- ❑ APEN submittal for update only(Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info Et Notes: 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: Stabilized condensate loadout For existing sources, operation began on: / / For new or reconstructed sources, the projected start-up date is: TBD/ / Will this equipment be operated in any NAAQS nonattainment area? El Yes 9 No Is this equipment located at a stationary source that is considered a Major Source of(HAP) ❑ Yes ❑ No emissions? Does this source load gasoline into transport vehicles? ❑ Yes ❑✓ No Is this source located at an oil and gas exploration and production site? El Yes El No If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual ❑ Yes 9 No average? Does this source splash fill less than 6750 BBL of condensate per year? ❑ Yes 9 No Does this source submerge fill less than 16308 BBL of condensate per year? 9 Yes ❑ No A A COLORADO Form APCD-208 -Hydrocarbon Liquid Loading APEN- Rev 02/2017 2 I is 6ITV,,`2t„, [Leave blank unless APCD has already assigned a permit#and AIRS ID] hf!: Section 4 - Process Equipment Information Product Loaded: ❑ Condensate ❑ Crude Oil ❑ Other: rA._ If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume 2 007 500 Bbl/yr Actual Volume N/A /^ Bbl/yr Loaded 4: e Loaded: 'V /-1 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 52.45 ,F of bulk liquid loading: J True Vapor Molecular weight of Pressure 5.0 GG Lb/lb-mot Asia C�60 °F displaced vapors 6V If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Bbl/yr Actual Volume Bbl/yr Loaded : Loaded: 4 Requested values will become permit limitations. Requested limit(s)should consider future process growth Product Density: Lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume ft3/truckload ADO Form APCD-208-Hydrocarbon Liquid Loading APEN - Rev 02/2017 3 I � „ei,CO,,LOR6�;, v - [Leave blank unless APCD has already assigned a permit#and AIRS ID] ,Its i_f Section 5 - Geographical Information Ir€ Geographical Coordinates (Latitude/Longitude or UTM) 40.258034, -104.625389 Operator Discharge Height P Temp. Flow Rate Velocity Stack ID No. Above Ground Level ( (ACFM) (ft/sec) (Feet) LO Indicate the direction of the stack outlet: (check one) ❑ Upward D Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑ Other(describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter(inches): ❑ Other(describe): Section 6 - Control Device Information ❑ Loading occurs using a vapor balance system: Requested Control Efficiency % Pollutants Controlled: VOC and HAPs Rating: MMBtu/hr Type: Enclosed Combustor Make/Model:TBD ❑ Combustion Requested Control Efficiency: 95 % Device: Manufacturer Guaranteed Control Efficiency 98 % Minimum Temperature: Waste Gas Heat Content 3,677 Btu/scf Constant Pilot Light: IDYes ❑ No Pilot burner Rating 0.06 MMBtu/hr 1 G • ti � ((,, Pollutants Controlled: -VOGfI IAPS(1= D 7Vnt11T16-On#y) ✓❑ Other: Description: 'PI•ant`Fiar 1`" tQ Control Efficiency Requested COLORADO Form APCD 208-Hydrocarbon Liquid Loading APEN Rev 02/2017 4 a [Leave blank unless APCD has already assigned a permit#and AIRS ID] I,f: Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment orpractice used to reduce emissions? ✓ Yes No I`3 ❑ ❑ ice.. :I;i; If yes, describe the control equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Control Equipment Description Efficiency (%reduction in emissions) PM Sox NO,, CO VOC Enclosed Combustor 95% HAPs Enclosed Combustor 95% Other: ❑ Using State Emission Factors (Required for GP07) VOC Benzene n-Hexane ❑ Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL ❑ Crude 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.) Emission Requested Annual Permit Uncontrolled Emission Factor Actual Annual Emissions 5 Pollutant Emission Factor Source Emission Limit(s) Factor Units (AP-42, Uncontrolled Controlled5 Uncontrolled Controlled Mfg.etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) PM SOX NO,, 0.068 Ib/MMBtu AP-42 -43T3USTL 0:3CQ3. Ems'�/"' VOC 2.02E-01 lb/bbl Liquid Analysis 203.09 10.15 CO 0.310 Ib/MMBtu AP-42 tee-, .5q — 4 Benzene 2.60E-03 lb/bbl Liquid Analysis 2.70 0.13 Toluene 7.45E-03 lb/bbl Liquid Analysis 7.48 0.37 Ethylbenzene 5.55E-04 lb/bbl Liquid Analysis 0.56 0.03 Xylenes 5.63E-03 lb/bbl Liquid Analysis 5.65 0.28 n-Hexane 1.45E-02 lb/bbl Liquid Analysis 14.52 0.73 2,2,4- Trimethylpentane Other: a Requested values will become permit limitations. Requested limit(s)should consider future process growth. AAnnual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. [� COLORADO Form APCD-208-Hydrocarbon Liquid Loading APEN - Rev 02/2017 5 I mV Ha.Lh6Enu;=s , • [Leave blank unless APCD has already assigned a permit#and AIRS ID] 'I lal; Section 8 - Applicant Certification .11 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. Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: E✓ Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General For more information or assistance call: Permit registration fee of$250 as applicable to: Colorado Department of Public Health and Small Business Assistance Program Environment (303)692-3175 or(303) 692-3148 Air Pollution Control Division , APCD-SS-B1 Or visit the APCD website at: 4300 Cherry Creek Drive South 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 COLORADO Form APCD-208-Hydrocarbon Liquid Loading APEN - Rev 02/2017 6 I A� 6eeartm icf F. c Fi.l:h b Fnusnnment Hydrocarbon Liquid Loa~dnPEN '* Form APCD-208 Air Pollutant Emission Notice (APEN)and Ap plication 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 hydrocarbon liquid loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source(e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks, 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/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. Permit Number: WLLIICOPPD AIRS ID Number: 123 / 9FBB/ 013 [Leave btanit unless APCD has aireati'j assigned a permit#and AIRS ID] Section 1 -Administrative Information Company Namei: DCP Operating Company, LP Site Name: Bighorn Natural Gas Processing Plant Site Location Site Location: Section 2, Township 3N, Range 65W County: Weld La Salle, CO 80645 NAICS or sIc Code: 1321 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 E-Mail Address2: RShankaran@DCPPAdstream corn 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 APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via a-mail to the address provided. Ay COLD 1tLDO Form APCD 208 Hydrocarbon Liquid Loading APEN - Revision 7/2018 1 1 Permit Number: AIRS ID Number: 123 /9FBB/013 [Leave blank unless APCE has already.assigned a permit#and,CRS!Di Section 2 - Requested Action O NEW permit OR newly-reported emission source 0 Request coverage under construction permit O Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of$312.50 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment O Change company name] ❑ Change permit limit ❑ Transfer of ownership ❑ Other(describe below) -OR- ❑ APEN submittal for update only(Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ❑ Limit Hazardous Air Pollutants (HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info 1s Notes: 3 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. 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: Pressurized unloading of raw condensate. Company equipment Identification No. (optional): UL For existing sources,operation began on: For new or reconstructed sources, the projected start-up date is: TBD Will this equipment be operated in any NAAQS nonattainment area? 0 Yes ❑ No Is this equipment located at a stationary source that is considered a Major Source of(HAP) ❑ Yes No emissions? Does this source load gasoline into transport vehicles? D Yes 0 No Is this source located at an oil and gas exploration and production site? O Yes ❑ No If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual O Yes ❑ No average? Does this source splash fill less than 6750 bbl of condensate per year? O Yes ❑ No Does this source submerge fill less than 16308 bbt of condensate per year? ❑ Yes O No COLORADO Form APCD-203 Hydrocarbon Liquid Loading APEN Revision 7/2018 2 1 �' `et. .-"`�` Permit Number: AIRS ID Number: 123 /9FBB/013 /013 [Leave blank u:4less APCD has already assigned a permit At and AIRS ID] Section 4- Process Equipment Information Product Loaded: 0 Condensate ❑ Crude Oil O Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: ) bbl/year Actual Volume Loaded: bbl/year i This product is loaded from tanks at this facility into: (e.g. "rail tank cars"or"tank trucks") If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: Average temperature of F bulk liquid loading: Molecular weight of True Vapor Pressure: Psia Q-60`F lb/lb-mot displaced vapors: If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: 'mod � Requested Volume Loaded5: 4 000 bb1-/year— Actual Volume Loaded: bbl/year r�0 - "- Product Density: lb/ft3 38.46 Load Line Volume: 0.0491 ft3/truckload Vapor Recovery Line Volume: 0.0491 ft3/truckload i 5 Requested values will become permit limitations.Requested limit(s)should consider future process growth. Note:Requested Volume Loaded: 8,760 Loads/yr iltld, 166,30 4- ?.tiN^ 5 P-r- }'-EJ' I -)- Om vpI )ao • „, ''----z..,-- 10/3O// Form APCD-2O8 Hydrocarbon Liquid Loading APEN Revision 7/2018 3 I Permit Number: AIRS ID Number: 123 /9FBB/013 (Leave blank unless APCD nas atready ass fined a permit'lard AIRS ID) Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.258034,-104.625389 Operator, Discharge"Height Above Temp. Flow Rate Velocity Ground Levee Stack ID Na. n (•F) _ (ACFM)` (ft/sec) (feet} UL indicate the direction of the stack outlet: (check one) ❑Upward ❑ Downward ❑Upward with obstructing raincap ❑Horizontal ❑ Other(describe): Indicate the stack opening and size: (check one) ❑Circular Interior stack diameter(inches): ❑Other(describe): 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. ❑ Loading occurs using a vapor balance system: Requested Control Efficiency: 100 Used for control of: Rating: MMBtu/hr hr Type: Make/Model: ❑ Combustion Device: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: % Minimum Temperature: F Waste Gas Heat Content: Btu/scf Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating: MMBtu/hr Pollutants Controlled: O Other: Description: Requested Control Efficiency: COLORADO Form APCD-208 Hydrocarbon Liquid Loading APEZJ Revision 7/2018 4 { L©© Permit Number: AIRS ID Number: 123 /9FBB/013 [Leave blank unless APCD has already assigned a permit#and AIRS ID) Section 7- 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(%reduction): Overall Requested Pollutant Description of Control Method(s) Control Effidency (%reduction in emissions) PM SOX NO. CO VOC HAPs Other: ❑ Using State Emission Factors(Required for GP07) VOC Benzene n-Hexane ❑Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL O Crude 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 Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor Actual Annual Emissions Emission Limit(s)- Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis _ Units (AP-42, _ Emissions Emissions' Emissions Emissions Mfg.,etc.)' (tcos/year) (tormiyear) (tons%year) (tonsiyear) PM SOx NOx CO VOC 1.93 Ibiload Eng.Estimate 8.45 8.45 Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Ernissidns ns' Chemical Name CAS rvice Abstract source Uncontrolled Controlled Se Uncontrolled { ,.. ) Basis Units (AP-42, Emissions Emissio._ Number. =Mfg=, .) (po_upds/year) ..-ftxxxids/year). .. Benzene 71432 Toluene 108883 _ Ethylbenzene 100414 Xylene 1330207 n-Hexane 110543 0.1558 lb/load Eng.Estimate 1,365 1,365 2,2,4- Trimethylpentane 540841 Other: Note:PTE Emissions shown above. Only NCRP>250 lb/yr reported. Requested values will become permit limitations.Requested limitls)should consider tuture process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. _ Q coi.ORA00 Form APCD-208 Hydrocarbon Liquid Loading APEN Revision 7/2018 5 l mx:,k Permit Number: AIRS ID Number: 123 /9F88/013 [Leave blank unless APU)has already assigned a permit it and AIRS l�j 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 General Permit GP07. Signature of Legally Authorized Person(not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name(print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance Q 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, ►I.C. for revised APEN requirements. Send this form along with$191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303) 692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.colorado.gov/cdphe/aped C0t.Q AO Form APCD-208 Hydrocarbon Liquid Loading APEi4 Revision 7/2018 6 1 L{� � Icytt c' 2S C°Y"E General APEN - Form APCD-200 ��";,�t Air Pollutant Emission Notice (APEN) and 4Q Application for Construction Permit AR sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD)website at: www.colorado.gov/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: 17511\)C 0,4(k) AIRS ID Number: 122 / L FB r� / G 14. [Leave blank unless APCD has already assigned a permit A and AIRS ID] l ll Section 1 - Administrative Information �cr szt,4;; Company Name': DCP Operating Company, LP c d Site Name: -S#4el�f -easPfe Ssin R Q Sin �E -i�� Site Location: Section 2, Township 3N, Range 65W Site Location Weld County: La Salle, CO 80645 NAICS or SIC Code: 1321 Mailin,gAdd ss: 370 17th Street, Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 Portable Source E-Mail Address2: RShankaran@DCPMidstreamcorn Home Base: 1 Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by APCD via e-mail to the address provided. 380093 COLORADO Form APCD-200 - General APEN - Revision 1/2017 1 H.al:t 6 Enuna,nra, r o y [Leave blank unless APCD has already assigned a permit#and AIRS ID] Isf' Section 2- Requested Action ❑ NEW permit OR newly-reported emission source (check one below) I] STATIONARY source ❑ PORTABLE source a ,,• -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' ❑ Other(describe below) -OR- ❑ APEN submittal for update only(Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ❑ Limit Hazardous Air Pollutants (HAPs)with a federally-enforceable limit on Potential To Emit(PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: Flare used as backup control device and during maintenance and emergency situations 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: Plant Flare - Train 1 and Bypass Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): FLARE-1 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: TBD ❑� Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec-Feb: Mar-May: Jun-Aug: Sep-Nov: Form APCD-200 -General APEN - Revision 1/2017 2 A� oOORAOO ' �epa en:cf F.�tic Ha.1+F 6 E+uHnninenf vu I [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 4 - Processing/Manufacturing Information £t Material Use 0 Check box if this information is not applicable to source or process From what year is the actual annual amount? Ise;; Design Process Actual Annual Requested Annual Description Rate Amount Permit Limit4 (Specify Units) (Specify Units) (Specify Units) Material Consumption: Finished Product(s): 4 Requested values will become permit limitations. Requested limit(s)should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Lotitude/Longitude or UTM) 40.258034, -104.625389 ❑ Check box if the following information is not applicable to the source because emissions wilt not be emitted from a stack. If this is the case, the rest of this section may remain blank. Discharge Height , Operator Temp. Flow Rate Velocity Above Ground Level Stack ID No. ('F) (ACFM) (ft/sec) (Feet)` FLARE-1 Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑ Other(describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter(inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other(describe): COLORADO Form APCD-200 - General APEN - Revision 1/2017 3 Av [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 6 - Combustion Equipment a Fuel Consumption Information El Check box if this information is not applicable to the source (e.g. there is no fuel-burning equipment associated with this emission source) Design Input Rate Actual Annual Fuel Use Requested Annual Permit Limit4 (MMBTU/hr) (Specify Units) (Specify Units) 0.2 (Pilot Only) - 13 MMscf/yr(Waste/Purge Gas) From what year is the actual annual fuel use data? 3).I3 MN1S�.�'i��,� r Indicate the type of fuel useds: El Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) C•IC.S hC,G 6/13/a ❑ Field Natural Gas Heating value: BTU/SCF O Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) 0 Coal Heating value: BTU/lb Ash Content: Sulfur Content: ❑✓ Other(describe): Residue gas/Inlet gas/Propane Heating value (give units): 1,098/1,303/2,516 Btu/scf 4 Requested values will become permit limitations. Requested limit(s)should consider future process growth. s If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. Section 7- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes 0 No If yes, describe the control equipment AND state the overall control efficiency(%reduction): Pollutant Control Equipment Overall Collection Efficiency Overall Control Efficiency Description (%reduction in emissions) TSP (PM) PM10 PM2_s SOX NO,, CO VOC Flare 100% 95% Other: HAPs - Flare 100% 95% COLORADO Form APCD-200 - General APEN - Revision 1/2017 4 I „°;:„�E„u;um�L ret MIL i'Iunwri: rain.)IV 'WillNQ1. [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 7(continued) 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.) 1, Emission Requested Annual Permit Uncontrolled Actual Annual Emissions . . 4 Emission Factor Emission Limit(s) Pollutant Source Factor (AP-42,Mfg. Uncontrolled Controlled6 Uncontrolled Controlled (Specify Units) etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP (PM) 7.6 Ib/MMscf AP-42 0.01 0.01 PM10 7.6Ib/MMscf AP-42 0.01 0.01 PM2.s 7.6 Ib/MMscf AP-42 0.01 0.01 Sox 0.6 Ib/MMscf AP-42 0.01 0.01 NOx 0.068 Ib/MMBtu AP-42 X1 31,?'" CO 0.310 Ib/MMBtu AP-42 Cap' - ?, . VOC teJ 8558-Ib/MMscf Site-specific -44a8:84 2f3742- Other q Pt( Cr611 4 Requested values will become permit limitations. Requested limit(s)should consider future process growth. (tj C4E5 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. rGCc2`44 t` 3Ia e Section 8 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP- hazardous air pollutant)emissions equal to or greater than 2 Yes ❑ No 250 lbs/year? If yes, use the following table to report the non-criteria pollutant (HAP)emissions from source: Uncontrolled Uncontrolled Controlled CAS Chemical Overall Emission Factor Emission Actual Actual Numbers Name Control Factor Source Emissions Emissions6 Efficiency- (AP-42,Mfg:etc) (specify units) (lbs/year) (lbs/year) 110-54-3 n-Hexane 95% Gvo /MMscf Site-specific -73984,011C 42 ,3y$ 71-43-2 Benzene 95% 8 lb/MMscf Site-specific 344 $ '1? IS" 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Note: Emissions shown are potential to emit emissions since this is a new source. Please include the emissions in the Notes to Permit Holder section of the permit. • COLOA;1,)DO Form APCD-200- General APEN - Revision 1/2017 5 I �� R"`Ha:lih 6EkU3 , -1 _._ .._...__.. L1 arc. [Leave blank unless APCD has already assigned a permit#and AIRS ID] l Section 9 -Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. IS? 5/4/201g ;L r' Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: ❑r 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 to: For more information or assistance call: Colorado Department of Public Health and Small Business Assistance Program Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303)692-3150 COLORADO Form APCD-200 - General APEN - Revision 1/2017 6 Av, Hrlf 6E 'nnnnl 4 General APEN - Form APCD-200 ,_\-c-\' ,\' Air Pollutant Emission Notice (APEN) and ; 17'CO V ,v Application for Construction Permit ��t ' yes All sections of this APEN and application must be completed for both new and existing facilities, including APEN 14`` 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 'I incorrectly or is missing information and requires re-submittal. There may be a more specific APEN for your source(e.g. paint booths, mining operations, engines, etc.).A list of specialty APENs is available on the Air Pollution Control Division (APCD)website at: www.colorado.gov/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: IA ,C Q4I 6 AIRS ID Number: IZ3 %Fg8/ d 15 V [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 - Administrative Information Res-- Company Name': DCP Operating Company, LP z,1S�m Site Name: eftefl-NattIfa) ag-RrOCeSeing Plat i Site Location: Section 2, Township 3N, Range 65W Site Location Weld 9 County: La Salle, CO 80645 NAICS or SIC Code: 1321 Mailing Address: 370 17th Street, Suite 2500 (Include Zip Code) Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 Portable Source E-Mail Address2: RShankaran@DCPMidstream.com Home Base: 1 Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 380094 & 094 pp COLORADO Form APCD-2O0 - General APEN - Revision 1/2017 1 i m� A „° ; P bn, v`✓ r [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 2- Requested Action H., .E: O NEW permit OR newly-reported emission source (check one below) ❑✓ STATIONARY source ❑ PORTABLE source -OR- ❑ MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other(describe below) -OR- ❑ APEN submittal for update only(Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ❑ Limit Hazardous Air Pollutants (HAPs)with a federally-enforceable limit on Potential To Emit(PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info£t Notes: Flare used as backup control device and during maintenance and emergency situations 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: Plant Flare - Train 2 Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): FLARE-2 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: TBD E Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec-Feb: Mar-May: Jun-Aug: Sep-Nov: COLORADO Form APCD-200- General APEN - Revision 1/2017 2 I [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use ,IFtI ❑ Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process Actual Annual Requested Annual Description Rate Amount Permit Limit° (Specify Units) (Specify Units) (Specify Units) Material Consumption: Finished Product(s): 4 Requested values will become permit limitations. Requested limit(s)should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.258034, -104.625389 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Discharge Height Operator Temp. Flow Rate Velocity Stack ID No. Above Ground Level' ('F) i ;(ACFM} (ft/sec). �', � � � FLARE-2 Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Downward ❑ Upward with obstructing raincap 0 Horizontal 0 Other(describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter(inches): 0 Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other(describe): COLORADO Form APCD-200 - General APEN - Revision 1/2017 3 r i II Zr; [Leave blank unless APCD has already assigned a permit#and AIRS ID] 11=, Section 6 - Combustion Equipment £t Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel-burning equipment associated with this emission source) kt; Design Input Rate Actual Annual Fuel Use Requested Annual Permit Limit4 I): (MMBTU/hr) (Specify Units) (Specify Units) 0.2 (Pilot Only) 44-3 MMscf/yr(Waste/Purge Gas) From what year is the actual annual fuel use data? 2t,‘3PC. /�s� Indicate the type of fuel used5: _pe-r 2r'./I c It viSe ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ CAA Cc �� /� /WField Natural Gas Heating value: BTU/SCF 3 El Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash Content:, Sulfur Content: E Other(describe): Residue gas/Inlet gas/Propane Heating value(give units): 1,098/1,303/2,516 Btu/scf 4 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 5 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. Section 7- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑Q Yes O No If yes, describe the control equipment AND state the overall control efficiency(% reduction): Pollutant Control Equipment Overall Collection Efficiency Overall Control Efficiency Description (%reduction in emissions) TSP (PM) PM1a PM2.5 SOX NO,, CO voc Flare 100% 95% Other: HAPs - Flare 100% 95% Av COLORADO Form APCD-200 -General APEN - Revision 1/2017 4 I 6� [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 7(continued) From what year is the following reported actual annual emissions data? N/A h'I 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.) Emission - Requested Annual Permit 4 Emission Factor Emission Limit(s)4 Source Factor (Specify Units) (AP-42,Mfg. Uncontrolled Controlled' Uncontrolled Controlled etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP (PM) 7.6 Ib/MMscf AP-42 0.01 0.01 PM10 7.6 lb/MMscf AP-42 0.01 0.01 PM2.s 7.6 lb/MMscf AP-42 0.01 0.01 SOX 0.6 lb/MMscf AP-42 0.01 0.01 NOX 0.068 1b/MMBtu AP-42 � 1773-1.3 CO 0.310 Ib/MMBtu AP-42 —7,7.13,G} -7-g-1—S: ? VOC -49 858 Ib/MMscf Site-specific -49€ 34 -20`42- Other: �i(0/VS,ts CMS,OD n C 4 Requested values will become permit limitations. Requested limit(s)should consider future process growth. C Q•°} 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. 3.to COLS TC-L7/ Section 8 - Non-Criteria Pollutant Emissions Information G Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants (e.g. HAP-hazardous air pollutant)emissions equal to or greater than E Yes ❑ No 250 lbs/year? If yes, use the following table to report the non-criteria pollutant (HAP)emissions from source: Uncontrolled Uncontrolled Controlled CAS Chemical Overall Emission Emission Factor Actual Actual e Number Name Factor Emissions Emissions' Efficiency (specify units) (AP-42,Mfg.etc) (lbs/year) (lbs/year) 110-54-3 n-Hexane 95% u(a .(rib/MMscf Site-specific 7,9934 -#22-a,?9 71-43-2 Benzene 95% 8 Ib/MMscf Site-specific —344 r"s 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Note: Emissions shown are potential to emit emissions since this is a new source. Please include the emissions in the Notes to Permit Holder section of the permit. COLORADO 5 Form APCD-2OO- General APEN - Revision 1/2017 H-ill:lFEvu.uMenl [Leave blank unless APCD has already assigned a permit#and AIRS ID] I fti':i it:add i Section 9 - Applicant Certification '`"' I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. • Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: ❑� Draft permit prior to issuance ❑r Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: For more information or assistance call: Colorado Department of Public Health and Small Business Assistance Program Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 COLORADO Form APCD-200 - General APEN - Revision 1/2017 6 Av Hrall 6 Ei u.ulnent v iIN;, Fugitive Component Leak _�� „ CoPHEt Emissions APEN - Form APCD-203 CO . s 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 fugitive component leak emissions. If your emission source does not fall into this category, there may be a different specialty APEN available for your operation (e.g. natural gas venting, condensate tanks, paint booths, etc.). In addition, the General APEN (Form APCD-200)is available if the specialty APEN options do not meet your reporting needs. A list of specialty APENs is available on the Air Pollution Control Division (APCD)website at www.colorado.gov/cdphe/apcd. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: I vv - AIRS ID Number: { Z3 16 fj3j / Q l (P [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 - Administrative Information Q � e Company Name': DCP Operating Company, LP /�� `g Site Name: t°�«�^!c.+�.'r;I�w �r,cessittg P+�a t- cJ f� Site Location Site Location: Section 2, Township 3N, Range 65W County: Weld La Salle, CO 80645 NAICS or SIC Code: 1321 Mailing Address: 370 17th Street, (Include Zip Code) Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E-Mail Address2: RShankaran@DCPMidstream.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 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. 38009 Form APCD-2O3 - Fugitive Component Leak Emissions APEN - Revision 7 pp [COLORADO /2017 1 Zko mew u M n, [Leave blank unless APCD has already assigned a permit A and AIRS ID] Section 2- Requested ActionIxt ❑ NEW permit OR newly-reported emission source(check one below) Iy -OR- If: ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change process or equipment O Change company name O Add point to existing permit O Change permit limit ❑ Transfer of ownership3 El 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 ❑ 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 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: TBD l]Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source hours/day days/week weeks/year Operation: Facility Type: ❑Well Production Facility' ❑ Natural Gas Compressor Station' 0 Natural Gas Processing Plant" ❑ Other (describe): 4 When selecting the facility type,refer to definitions in Colorado Regulation No. 7,Section XVII. Form APCD-2O3 - Fugitive Component Leak Emissions APEN - Revision COLORADO 7/2017 2I L31r!N2=g'n, [Leave blank unless APCD has already assigned a permit#and AIRS ID] I:FI Section 4 - Regulatory Information What is the date that the equipment commenced construction? TBD Will this equipment be operated in any NAAQS nonattainment area?5 0 Yes ❑No Will this equipment be located at a stationary source that is considered a ❑Yes ❑✓ No Major Source of Hazardous Air Pollutant(HAP)emissions? Are there wet seal centrifugal compressors or reciprocating compressors ✓ Yes No located at this facility? ❑ ❑ Is this equipment subject to 40 CFR Part 60, Subpart KKK? ❑Yes ❑� No Is this equipment subject to 40 CFR Part 60, Subpart OOOO? ❑Yes ❑✓ No Is this equipment subject to 40 CFR Part 60, Subpart OOOOa? El Yes ❑ No Is this equipment subject to 40 CFR Part 63, Subpart HH? ❑Yes El No Is this equipment subject to Colorado Regulation No. 7, Section XII.G? p Yes ❑ No Is this equipment subject to Colorado Regulation No. 7, Section XVII.F? ❑Yes ❑� No Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? ❑Yes No 5 See http://www.colorado.gov/cdphe/state-implementation-plans-sips for which areas are designated as attainment/non- attainment. Section 5 - Stream Constituents E The required representative gas and liquid extended analysis (including BTEX)to support the data below has been attached to this APEN form. Use the following table to report the VOC and HAP weight%content of each applicable stream. VOC Benzene Toluene Ethylbenzene Xylene n-Hexane 2,2,4 Stream (wt%) (wt%) (wt%) (wt%) (wt%) (wt%) Trimethylpentane (wt%) Gas 28.95 0.0278 0.0135 0.0000 0.0034 0.6443 0.0011 Heavy Oil (or Heavy Liquid) Light Oil (or Light Liquid) 100 0.0961 0.0466 0.0000 0.0116 2.2254 0.0036 Water/Oil Form APCD-2O3 - Fugitive Component Leak Emissions APEN - Revision p COLORADO 3 7/2017 [Leave blank unless APCD has already assigned a permit 4 and MRS ID] iF Section 6 - Geographical Information Geographical Coordinates -tr (Latitude/Longitude or UTM) al 40.258034, -104.625389 Attach a topographic site map showing location Section 7- Leak Detection and Repair (LDAR) and Control Information Check the appropriate boxes to identify the LDAR program conducted at this site: ❑ LDAR per 40 CFR Part 60, Subpart KKK ❑Monthly Monitoring-Control: 88%gas valve, 76% light liquid valve, 68%light liquid pump ❑ Quarterly Monitoring- Control: 70%gas valve, 61% light liquid valve, 45%light liquid pump ❑� LDAR per 40 CFR Part 60, Subpart OOOO/OOOOa ❑✓ Monthly Monitoring-Control: 96%gas valve, 95% light liquid valve, 88%light liquid pump, 81% connectors ❑ LDAR per Colorado Regulation No. 7, Section XVII.F ❑ Other6: El No LDAR Program 6 Attach other supplemental plan to APEN form if needed. Form APCD-2O3- Fugitive Component Leak Emissions APEN - Revision 7/2017 4 ]COLORADO :N b Fnruti•urtl [Leave blank unless APCD has already assigned a permit#and AIRS ID] ;I Fa II:; Section 8 - Emission Factor Information Select which emission factors were used to estimate emissions below. If none apply, use the table below to is identify the emission factors used to estimate emissions. Include the units related to the emission factor. ❑✓ Table 2-4 was used to estimate emissions7. :Lk ❑Table 2-8 (< 10,000ppmv)was used to estimate emissions7. Use the following table to report the component count used to calculate emissions.The component counts listed in the following table are representative of: ❑✓ Estimated Component Count ❑Actual Component Count conducted on the following date: Equipment Type Service Connectors Flanges Open-Ended Pump Seals Valves Other9 Lines Gas Counts 30,516 2,062 7,304 122 Emission Factor 0.000441 0.000860 0.009921 0.019401 Units lb/hr/component lb/hr/component lb/hr/component lb/hr/component Heavy Oil(or Heavy Liquid) Counts Emission Factor Units Light Oil (or Light Liquid) Counts 5,048 988 72 2,448 28 Emission Factor 0.000463 0.000243 0.028660 0.005512 0.016535 Units lb/hr/component lb/hr/component lb/hr/component lb/hr/component lb/hr/component Water/Oil Counts Emission Factor Units 7 Table 2-4 and Table 2-8 are found in U.S. EPA's 1995 Protocol for Equipment Leak Emission Estimates(Document EPA-453/R- 95-017). 8 The count shall be the actual or estimated number of components in each type of service that is used to calculate the"Actual Calendar Year Emissions"below. 9 The Other equipment type should be applied for any equipment other than connectors,flanges,open-ended lines,pump seals, or valves. Form APCD-203- Fugitive Component Leak Emissions APEN - Revision AvCOLORADO 7/2017 5 ,COr! [Leave blank unless APCD has already assigned a permit'and AIRS ID] Fv6, Section 9 - Criteria and Non-Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. From what year is the following reported actual annual emissions data? N/A ;tPl Use the following table to report the criteria pollutant emissions and non-criteria pollutant (HAP)emissions from source: (Use the data reported in Section 8 to calculate these emissions.) CAS Actual Annual Emissions Requested Annual Permit Emission Limit(s) Chemical Name Number Uncontrolled Controlledt° Uncontrolled Controlled11 (tons/year) (tons/year) (tons/year) (tons/year) VOC 273.92 43.83 Does the emissions source have any actual emissions of individual non-criteria pollutants(e.g. HAP- hazardous air pollutant)emissions equal to or greater than 250 ®Yes ❑ No lbs/year? If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: CAS Actual Annual Emissions Requested Annual Permit Emission Limit(s) Chemical Name Number Uncontrolled Controlled9 Uncontrolled Controlled10 (lbs/year) abs/year) (lbs/year) (lbs/year) Benzene 71432 526 84 Toluene 108883 255 41 Ethylbenzene 100414 Xylene 1330207 n-Hexane 110543 12,191 1,951 2,2,4 540841 Trimethylpentane Other: 10 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. 11 Requested values will become permit limitations. Requested limit(s)should consider future process growth,component count variability,and gas composition variability. Form APCD-2O3- Fugitive Component Leak Emissions APEN - Revision COLORADO 7/2017 6I r°`"s`"' HeftN b Enrimtinenl [Leave blank unless APCD has already assigned a permit#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. Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: ❑� Draft permit prior to issuance ❑� Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with$152.90 to: For more information or assistance call: Colorado Department of Public Health and Small Business Assistance Program Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 ©@� COLORADO Form APCD 200 General APEN Revision 1/2017 6 I A Y Ih6Emgnp N la A CDP"E General APEN - Form APCD-200 \ 'cCO '` -VAir Pollutant Emission Notice (APEN) and °mac° t Application for Construction Permit N, All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. There may be a more specific APEN for your source(e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD)website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: l IcIU`,t l f c) 69 t AIRS ID Number: I Z-5 /gFC,19/Q(7 [Leave unless APCD has already assigned a permit#and AIRS ID] Section 1 - Administrative Information P-e-r" Janet- Company Name': DCP Operating Company, LP Wa Site Name: -Sb; { at I c--. -$e sing-Plarrt—A Site Location Site Location: Section 2, Township 3N, Range 65W County: Weld La Salle, CO 80645 NAICS or SIC Code: 1321 Mailing Address' (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 Portable Source E-Mail Address: RShankaran@DCPMidstreamcom Home Base: 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. 380096 COLORADO Form APCD 200 General APEN Revision 1/2017 1 , A� H I:N6Enuvrn„°n, �................... r.usa l✓ 1\1.111 LLJQ1• III [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 2- Requested Action I.r. O NEW permit OR newly-reported emission source (check one below) ❑✓ STATIONARY source ❑ PORTABLE source -OR- ❑ MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit El Change permit limit O Transfer of ownership3 ❑ Other(describe below) -OR- ❑ APEN submittal for update only(Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info£t Notes: APEN being submitted since emissions of NCRP (methanol) are >250 lb/yr. 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: Two (2) 400 bbl methanol storage tanks PTE throughput = 4,800 bbl/yr/tank for a total of 9,600 bbl/yr. Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): METHANOL For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: TBD ❑� Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec-Feb: Mar-May: Jun-Aug: Sep-Nov: COLORADO Form APCD-2O0 - General APEN - Revision 1/2017 2 I �� MT6EwNnunnnl HII[J iu riumuer: i i O� [Leave blank unless APCD has already assigned a permit N and AIRS ID] Lfi Section 4 - Processing/Manufacturing Information a Material Use ❑� Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process Actual Annual Requested Annual ry, Description Rate Amount Permit Limit4 (Specify Units) (Specify Units) ((Specify Units) _�r- lr�E (1)0 r C-OI Material Consumption: Finished Product(s): 4 Requested values will become permit limitations. Requested limit(s)should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.258034, -104.625389 I Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Discharge Height Operator Temp.Flow Rate Velocity Above Ground Level Stack ID No. (Feet): ( F)- (ACFM) (ft/sec) METHANOL Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter(inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other(describe): pp COLORADO Form APCD-200- General APEN - Revision 1/2017 3 1 M. „;,t 6E„„.;u„� • •••••••�•"""`""• HIf�J IV 1\UIIIUCI. [Leave blank unless APCD has already assigned a permit n and AIRS ID] .I. L.1=, Section 6 - Combustion Equipment &t Fuel Consumption Information 0 Check box if this information is not applicable to the source (e.g. there is no fuel-burning equipment associated with this emission source) Design Input Rate Actual Annual Fuel Use Requested Annual Permit Limit4 (MMBTU/hr) (Specify Units) (Specify Units) From what year is the actual annual fuel use data? Indicate the type of fuel used': ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF 9 Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content: 9 Other(describe): Heating value(give units): a Requested values will become permit limitations. Requested limit(s)should consider future process growth. 5 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. Section 7- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑✓ No If yes, describe the control equipment AND state the overall control efficiency(% reduction): Pollutant Control Equipment Overall Collection Efficiency Overall Control Efficiency Description (%reduction in emissions) TSP (PM) PM10 PM25 SOx NOx CO VOC Other: COLORADO Form APCD 200 General APEN Revision 1/2017 4 I Av H..alh 6 Erincement I d" Section 7(continued) From what year is the following reported actual annual emissions data? N/A :l,f.I • 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.) 1T'. Uncontrolled Emission Actual Annual Emissions Requested Annual Permit 4 Emission Factor Emission Limit(s) Pollutant Source Factor (Specify Units) (AP-42,Mfg. Uncontrolled Controlled6 Uncontrolled Controlled etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP (PM) PM10 PM2.s SOX NO), CO VOC 0.13 Ib/bbl TANKS 4.09d 0.62 0.62 Other: a Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants (e.g. HAP- hazardous air pollutant) emissions equal to or greater than ❑✓ Yes ❑ No 250 lbs/year? If yes, use the following table to report the non-criteria pollutant (HAP) emissions from source: Uncontrolled Uncontrolled Controlled CAS Chemical Overall Emission Emission Factor Actual Actual Number Name Control Factor Source Emissions Emissions6 Efficiency (AP-42,Mfg.etc) (specify units) (lbs/year) (lbs/year) —. 67-56-1 Methanol - 0.13 lb/bbl TANKS 4.09d 1,235 1,235 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Note: Emissions shown are potential to emit emissions since this is a new source. Please include the emissions in the Notes to Permit Holder section of the permit. COLORADO Form APCD-200 - General APEN - Revision 1/2017 5 I Ay- �.....�.w......... rul\J IV I UIILLJQI. / V t [Leave blank unless APCD has already assigned a permit#and AIRS ID] , Section 10 - Applicant Certification pi I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. M1 5Icj12 o/g Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name(print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) 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 to: For more information or assistance call: Colorado Department of Public Health and Small Business Assistance Program Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B 1 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 Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision COLORADO 7/2017 7 I AVkbF.vim Hello