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Home My WebLink About20180777.tiff:COLORADO: :Department of,Publie Health ErEnvironrnent Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150O St PO Box 758 Greeley, CO 80632 March 7, 2018 Dear Sir or Madam: RECEIVE MAR 12 2018 WELD COMMISSI On March 8, 2018, the Air Pollution Control Division will begin a 30 -day public notice period for DCP Operating Company, LP - O'Connor Gas Plant. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required ,by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days ;from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Y, 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 Pu.1j_ (!.e hn W. Hickenlooper, Governor I Larry Wolk, MD, MSP1, Executive Di ector nd Chief Medical Officer view• CC : ?L emmtrp) NLCJrJ, 03-13:-1$ 2018-0777 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: DCP Operating Company, LP - O'Connor Gas Plant - Weld County Notice Period Begins: March 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: O'Connor Gas Plant Natural gas processing plant Section 31, T5N, R64W Weld County The proposed project or activity is as follows: The applicant proposes construction of_a new natural gas processing train at an existing processing plant. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) • the source is subject to control requirements under a Federal Maximum Available Control Technology requirement for major sources • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 11WE1481 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 fromany 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.W.us GOCORA`DO 1 I ,,;. �.n,. iii xm^s 6 ex:vonmr66 Colorado Air Permitting Project Project Details Review Engineer: Package #: Received Date: Review Start Date: Section 01- Facility Information New application received 7/19/17 Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Location: Type of Facility: What industry segment? Is this facility located in a NAAQ$ non -attainment area? If yes, for what pollutant? carbon Monoxide (CO) DCP OPera'fing,Company,C 123 ,O'Connor Gas Planf'.'>111"s: Weld Quadrant Section Township Range Section 31, Township 5N, Range 64W, in Weld County, Colorado > 1, s ,t.cess Natural Gas ProcessingyPla' Oil'&:Nat€ ral as:P,roduCtion3& Processi Section 02 - Emissions Units In Permit Application Particulate Matter (PM) azone (NOx & VOC) AIRs Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks » , ,., '001, ..' . 3 , .. ,+..:Amme•Sweetenln 'Unitr %a ng, nit �,,.. g, ,�.�� AM001.. 3 . "a- " � � '>Y .3 �,€'€..es'��'� , T11NE1481'" 7 %.��::'.:-_:.3..Nos,�� 5' � ':':sf:«krY;a,w�� E;�F,, ', <. • - { Permit.;;z''.' �1u.Nlodificatioi � ate;:;, conditions to . , % .. . � . •. "> .3..., ,3,3,.3Y i; •'x "^ " - 9 ,. , ., " .. , ;, . ". ", »E_ 002 "; ...,, _ > s»-, � " . ';� Y ...,. -`E< 't -£E .. »..>, ". F, , I c. 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S »,,... _.. %%'h•n�°a�ti`;•3?..%".Y, D'wsi:a,>,. , � No . xaeF n NoEAction E-'°: .Requesfe Existing poin�t:�.. ,..,Permit ,,, 3,3, ,,,,,,, ,,,, , ,,,,,,,, " "x0053'%'.»3... _ .. .-:-'% ._t,.reFr,a3 Ear..•, E>!oz ;ar,f,T .z, cr;>na'•--,,�^,,� � e,ank.-�->� -r .:.,. Condensate:T ;�3 TANKS ,, " + ,t S<$`,'i, +1Nc-l-c-<s� ' ''"iGv"`V z��v,.'n> :_,,;;� i ,3 53: 11WET481= :� ':�_. _ _. M �m3.: ,� -< ,.,.No„�� ,F � -,,,iviodlfication � ,. Existing/point,,:. -... _. .006 . ,,,,�a,T3'%,�, - ��kugrtn+e;Component,Lea�=s FUG s3aFE.z:"� • ��:,;: .3"t�;, 11V1IE1481�; , a ,. _�„_" 3 v�; ":5`� ,�a, ,,,� - ��.�� _��y��No?�� Pe m t�' F Modlficatlon'w' dd'""r`ocess unit»',:a.>' : - r. ,,,, ..,E :;, . ,» ,,, , 3 .. 3 � .,,'„ 3. 3 07 , , � r '. ',>.:3' 3,. ,. >,,,,, s ,,• .,, „< , , t',R�'r<, + , ,.., <. � . , "� <. 2 c "s� Boderor.Brocess Heater,., � » E � .. � �. , ......., :"!3 .,....' 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Pe�rtid�lnitlala3% }mot � . �,.,:�",i>ril r,: .: = .:Issuaricehvs:> NeHr3lourCe- ili>;. 0'CorinortlL»',. :'313€;;,":,.;.,%• 33 011 ,.. 3,,--.:.,:'3:.-- .. � � Condensate Tank»._ - � �,, � t �»».�� ..-.. TANKS -2. ,.�tiw:.'* . ��„ a':��t: i 13)3)'1 „ 11WE1481 ... 13-, ,.... :;z.,`-r,"4z + 3a's h '��° es' e t" t a t s "sr„ .`tdr+ � `'�' .,€ a Sou ce: ;>;-'; O'Connor II'� ._ ,,.........:..,. 012a .. ...,,>,.». > , .. <a»,,,,as.,..,.,, .. :�'t y- �)t:,Fugitiv"etComponenttLeaksf 1'j: • „ ,:EUG-2 • ::d ��»� i�'�.'%; �'r1''SYWE�1481»' '1i.3>E„1:,,5-; ; ; .�...?^v`^y;:€.a ,., :� iw<'r�"% E':l :', ,�':'tY;es:�::�'_ '.fi e�irutanitlal '`<+`,„ ,.,:,Issuances„ New Source O',ConnorilG f.:..::. ' " " , , ., 013» .. "" _, .n.,. L ,..,., .nl.;,.� �+m".F'��%urbme_�..u„� ,T,URB"1>'-'; �i�*� %y1S1NE1481' , �. .,>+ ,�„�„�Is �Yes�'� °�"Permit�-lnitial3"' � suance.� New So r u ce" O'Connor II::,` 3..:+,. - ,:':: 3»' �, .',. , ,' .» ,014. » - ,.,,,.» .._» ,,,,,.,E .,,, a _- ,,> :. 4, -E�`a' t,S., ' ,,,�.__-, Tub e , ,,.., U < Sir ,,,`�';�-�, :--fiV1%E1481r 'i»^': ;'�: �' �: �; m s.,Y. :»3" zPer`mit'Initial ssGarice'a�T�' N -w o_,.rC_, e S u e;-" .3•',33»,', 0'Conno'r11 337,3 3' � ,., + 0153'.. .. ,».,- „+»^P:E :.:}�;; .r: ,�a-q�."�; tE,; r,v, E. ., s, '"� ,,, �Boller or Proce H r � � . ss.€ , eate �, `, 33` ,'3 ." _ ', ;., HT 01. , .-. ,`i; , )„• 533%^ � h: r� . >- ..„„% ,�,+��',.. w�' ,�� ,,.. 3>' '' ;: xE E .:; � S1WE1`¢81,"� ..» .. " 5"', „„, � � ;.,k. t'-�.,�j�»' x ig" rF. Yes,-��-� Pe _ : mil rnt al ',;€^,K',eE:�E;,pE .B,E�-E,' z`1�'aE ��Issuance-�� New Source' - 0'Connor-11�3�„»,: , ,, ,,, 7 .» ,.... 016.- ...... . ,'�. ,,: , ,Boller or>�P.roc Mea e� ess, t HT -02 r•, �°>-=:'� a» �">��, 3 � � SSWE1481�,;, " S„s�,;;,,, , . ;',-„r'>;"•..'i err %��", � � Xes� �4,_ " ��- � ;Permit Initial�� - .. Issuance �l Neinr>Source=, ""°:':: ≥3;;3::- ;€ O„'Connor;ll��'� 3 017:-,:� ,� ' i>,l �,AmineSweetenng.Und, s3 . 3E 002?;:1� 13 k::Ex��'�"~� ,, 3'3',''1P"ermitlniiialr '11WE148111f�,�� ' :a .., ,,33;` �� Yes_�;� �,:�alssuancehE��;,; NeG++%Source": O'Connor II "'''' "" »3 i;3' 3,.33, ,'..>33,333ai, 3, E- .., ,3 , „,3, ,,, 3 ,..., ....,_ .. 1 .. 3» 0 8 s <+,.n;,,+%%;'�a°;j«;>.,q.�ve rE%' ,'t^!'J"` rtfY ss:, „>+-Y��., t, ,,.+,: � v,.,., r R,'3 .. T.EG-Deh drator.- t» »�,r.»rz.E � y ��, n" -133:: .3-:aD01.:-:-»:.: »,,... Via" `�•�'!",�, �` e - ,jr..;,:i , ,. 't .. ._-<-.- �...� _._��;� " 11WE141,,,3, �� " 8 . - 5'c'r':"'>. .�,• ""3E'{'€.a�,F;s%�3•; a� ,�,,,. ;.gL>'_<,.�., +�3`;�r;' �=�i�es»k,,( - Permiti'In"itiahEi A 3' 3RR E, ;,� 'Klssuance'� NewSource, O'Connor II_ ,..:-.».......-......,3:.3.3-:.. -:.'...._ " ,, „3,1.: 019" ....3.,,.,3,,, .:.........:.t,; .„ »`3 < .t, ,,,..--... ', r..a 3 + �,",,sressu,zed.0 oad g�: , ,,3,3, ,,, U�'�,�� ;;, nu, <" t'y%rya,«£ , e o ,.. .- ,.,t r.,y,�. >, ,;3-' ,33 >=Y1WE14813 )3, ':13�,.,v' 15'3,':,,;,._; _ o 'r�nit,, . ;��_:-=-, ;,,t�,�S ?p;, ;t' ft Perrri tan „H�, aI,�;E r� :-�. ,%R:�;:,� ttX Ye`s��_�,."»Issuance��€�EO'Connor111�� New SourC ;::.:..wr'-> , 3 . 331,': ; ,,,,,,;,,,,,,»„ 3,,,,,, , EE„ 3 020: - ..+. , ....,.,, ,.,.»,,» ,33.1»43-�,'»", ,�- r � " , , d <ocarbo Loadm E E H r n�Ll uld. ,-Y _-,-'--- „� G _..',g � , 3%'; a ..: ,'- ,,,, 3:; ." :-.:LO.2....:::.:... .__..._ v r'a-"„','iTF°» � .",,,» ,.. ' �.,,.� ��' 3,1, `>1'iW�E1481:;»;.: , _.., itnit�lnitial,i�3 i',�t,'eri'" - aE• .s'�, �;,W=;:'% .:t,; �+� � ,-Issuance a � ��Yes�z" New Source - Connor 11 Colorado Air Permitting Project Section 03 - Description of Project DCP is proposing to expand the existing O Connor Plant to add'a new 230 MMscfd natural gas processing tram 'O Connor 2 Gas:Plant " (O'Connor 2)' In addition,., ;: DCP" isproposing to modify someof the existing O Connor Plant•sources .The proposed 'permit actions are summarized below Existing points:' Point 001: Update permit toreflett compliance strategies that align. with 017. Update emissions to reflect 95%control at flare. Point 004. No; change. DCP originally requested to increase the permitted throughput.from 638,229 bbl/yr to 2,280,885 bbl/yr However DCP determined that there are two separate:loadout points at:this facility and Point: 020 was added to account for the add(tional' throughput instead. Point:005 Update emission factors to correct"for four (4) storage vessels ratherthan eight.(8) as originallypermitted. Point 006.Update rule applicability"to includeNSPS 0000a due to new process unit at existing process train:: Point 008: Update PW tanks and report . source as•,APEN required/Permit Exempt (<1% 'crude oft by volume): and add an'additional 400 bbl tank : • Point. 009:. Remove existing plant flare.to:be replaced with new.flare,(point0): 01. DCP proposes to:remove the existing flare, as soon as thenew flare commences New 2omts (O''Connor II) i , Point:013 & 014 (TURB-11.&(TURB-2) Install two new:.turbines to serve as residue gas 015 coeater)mpressors, Point & 016 (HT -01'& HT-02).'Add two heaters (1 regeneration heater & 1 hot oil h Point 017 (AM002): Install a new 230 MMscfd amineunit controlled by a regenerative thermal oxidizer (RTO) Point 018 (D-01) Install a new 230:MMscfd TEG dehydrator Point 011 (TANKS 2) Install four(4) new 1000 bbl fixed roof stabilized condensate storage tanks with combined throughput of.T,642 500'bbl/yr Point 010 (FLARE 2) Install a new plant flare to serve,,as a backup control and control"during start-up, shutdown and maintenance for the; existing O'ConnorPlant as'well as the new O Connor II Pant DCP is also, requesting this: flare; be approved` as an alternative. emission control device for . backup: control of point 005 Point:012 (FUG-2)::New:fugitive componentleaks: associated. with O'Connor 2 expansion Point 019 (UL -1): Pressurized loadout of"raw: condensate' Pointstabilized condensate from O'Connor II train O Connor is an existing synthetic mmor'source:with respect to;Title V . Nonattainment New Source Review (NA,NSR) and an Area Source•with respect to 40 CFR°Part 63 National emission Standards for Hazardous Air Polfutnats:(NESHAP) for Source: Categories With; the proposed plant expansion,;this source will. become Major for Title N./and a Major Source with res ect to 40 CFRI Part 63':for.hazardous air olutants HAP ," p R. ( ) Section 04 - Public Comment Requirements Is Public Comment Required? If yes, why? tRequesting SynthetirMinor,Permit :' "> >,`- " "-`'. ;' `''"",. for NANSR Section 05 - Ambient Air Impact Analysis Requirements Was a quantitative modeling analysis required? •No If yes, for what pollutants? . If yes, attach a copy of 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? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) Is this stationary source a major source? If yes, explain what programs and which pollutants here: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) National Emission Standards for HAPs (NESHAP) SO2 N0x ❑ ❑. ❑ ❑ V0C El O PM2.5 PM10 ❑ ❑ ❑ ❑ H Ps CO 0C M2.5 M10 P HA O. O O ❑ O ❑ O O O O 'S O O Amine Unit Emissions Inventory la al -Iollawairliaa Pea Magmas* a fa • aa ..00.1 leant Quellreir rtnl..o w r *MY. ....p. .a. e..yr lord, + weMK., all. (Ora, r. Oa* ..eer aIwo In.uar.nrw erwn,w..a 0IawF.r.r..ar.ar,ewan..e ,... a...,...we u+�........ r.. a.r Iowa Isago•Caolotama lama.. froaldaa Wisdom aol CroOllflOall NA Van ado Coa YOU W.I. .-casts ts•VamIlinunrCsa ad‘... Sella Lama. 44.181.1 r..w Samamt oeIrYaw 'ha a anal. su Yaw toa.malenlempet 4,14 *Galan gW..x• 3 .. '::HAW ' Yoga. FOII•91 I*^ ten. ono ov 0411, Coma, Mftel 4,11 11.51 14,1 OAT Ian lenesa Oferol Mora fall Amin. Unit EnnuiOM Inventory Cote* MONO llesawOul Anton rNnr Irwnnl osio M'MM N.A./ Onl 11.7 13.41. LIT narm 1.1 atoff II A nevi ..61 r..* 2,41 149, Rog 14.1 inninnt 4.11 IMP 14110, OOP WNW.. CoOneed 1.111001. God.. MI MI 1.16 400 41,0 Inn Poislifftre *rem.. MM. orn rr. n.r=..�r 19•00.6.raa.r Porn -ain• Mw..wr.wu.Iminrrlr F:r�....rl.n .r nrnw. nr�u r.✓rr �.tl].Y.�t r r r nr..... ....lu.ws r.n• wnf.m.... numYrMa�usY.�� orrr. rr.r'ers.wr.r ri�wt Y..�rrw.wnnrarr�r..nr.rwnway . rr.rrarMea..w..n•••••• rrrrenr.vra.rrr rr ▪ Tannin nonnollon innarenso—nnionnom.anor'annons......:onnoi.nrinni.i.....? [In C.PAn� 0 bLM'IMd p.>WAfnwugrinraNsrutg. WrMLI w •v.r...I nom... w4Yr • sw rW wwYat atlr. to yY. � • rYbw� a.rM.. ,.iW wrrrti ✓ w ..wMn w rr I.r..n !rtes (..1 .wA Hydrocarbon loadout Emissions Inventory Section 01- Adminbtrativ. Information Fadllty AIRs ID: County Plant Point s&action 02 - Equipment Desolation Details Detailed Emissions Unit Description: Emisab from this inuriaarercontroliad tiimn,anOpsed flan/combustor (John 21nk VC 9127791)-', Emission Control Ourlag cwnbwta downtime embslons a • routed to LM pptn flee.., Device Descrlptlo Requested Overall VOC & HAP Control Section 03 - Processing Rate Information for Emissions Estimates 27&176 Barrels (hbl) per year 638,729 Barrels (bbl) per year 26805616 gal/yr Annual Actual Throughput = Annual requested Throughput . Section 04 - Emissions Factors A MethodoIoaIe6 L = 12.46.5'P'M/T (AP -42: Chapter 5.2, Equation 1) L = loading losses in lb per 1000 gallons loaded Factor Meaning Value Units Source S Saturation Factor !:. r 0.8 AP -42 Osapte5, Tab. 52 1 Submerged bad dadlsated . loch -, noem.I service - P True Vapor Pressure : ="5.0032 pale .. :- Arerap Por,pressun front aEPA TAN16409d w es /Goiba 0.W' 10 00..4In Denver, CO M Molecular Weight of Vapors ' 66 lb/lb-mole AP -42 Gupta, uptar 7 Table 7.1-2: RVp10. T Uquld Temperature 'x.512.43 liquid Bulb Tee mprature from EPA :Ti.,: 4,0,9d w/ Diso1N. RVP:: NCRPs Component Benzene Toluene Ethylbenzene Xylen s n -Hexane 2,2,4-TMP Source: 4,82 lb/10=3 gal 2.02E-01' lb/bbl Mass Fraction =' 0.0278' StabOhad'e0 sample from:cond.hs.t storage:nee u_. Emissions horn Control Device Mating vsloa Pilot flow rat. Assist gas flow rate Total fuel usage Apportionment' Apportioned Fuel us. =Apportionment is the amount of combustor fuel use attributed to the loedout Please see technical analysis notes 07, 1050 btu/scf 80 scf/hr 1200 scf/hr 11.0376 MMscf/yr 88.1% 0.874891485 7.295514873 MMscf/yr Section 05 - cmissbm Inventory Rwu.sted Emissions Emission Factor Uncontrolled Emissions Controlled Emissions Source 'Pollutant VOC 0.2023 lb/bbl 64.566 tpy 3.223 tpy AP -42 7.06E-04 lb/bbl TNRCC NOx 100 Ib/MMsd fuel- 0.59 tpy 0.59 tpy AP -42 dupter 1 (set 281E-03 lb/bbl TNRCC CO 84 Ib/MMsd fuel 1.20 tpy 1.20 tpy AP -42 chapter 1 Benzene 2689E-03 16/bbl 1716 lb/yr 06 lb/yr Mass Balance Toluene 7.452E-03 lb/bbl 4756 lb/yr 238 lb/yr Mass Balance Ethylbentene 5.552E-04 lb/bbl 354 lb/yr 18 lb/yr Mass Balance Xylenes 5.633E-03 lb/bbl 3595 lb/yr 180 lb/yr Mass Balance n -Hexane 1.447E-02 lb/bbl 9234 lb/yr 462 lb/yr Mau Balance 2,2,4 -IMP 1.072E-05 lb/bbl 7 lb/yr 0 lb/yr Mass Balance Actual Emissions Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.2023 lb/bbl 27.97 ccv 1.40 WV AP -42 NOx - 7.06E-04 lb/bbl 0.10 ccv 0.10 toy AP -A2 CO 2.81E-03 lb/bbl 0.39 tpy 0.39 toy AP -42 Benzene 2.689E-03 Ih/bbl 743.43 lb/yr 37.17 lb/yr Mass Balance Toluene 7.452E-03 Ib/hbl 2060.24 lb/yr 103.01 lb/yr, Mass Balance Ethylbenzene 5.552E-04 lb/bbl 153.50 Ih/yr 7.67 lb/yr Mass Balance Xylenes 5.633E-03 Ih/bhi 1557.35 Ib/yr 77.07 lb/yr Mass Balance n -Hexane 1.447E-02 lb/bbl x000.21 Ib/yr 200.01 lb/yr Mass Balance 2,2 4-TMP - 1.072E-05 lb/bbl 2.96 Ih/yr 0.15 lb/yr Mass Balance analysts notes) Uncontrolled Controlled (LPY) (tpYI 0.37 0.02 1.03 0.05 0.06 0.00 0.78 0.04 2.00 0.10 0.00 0.00 Hydrocarbon Loadout Emissions Inventory ;action 06 - Regulatory Analysts Carbon Monoxide .. kle........,. Refutation l-'• Particulate( Smoke: UIIIoi1Mon' idda end Sulfur doaM( ;'.. instal (Pe..................eguNo 3 Sectio II Al ) ,..,,......c-.::: ....x.... :» q� • : Section LA - 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 ith seven (7) or o e volumes of odor free al . Jie0ulatlon 3'-APEN arid Permittitw Requiremcrda _ � � is this site considered an aeploraeon and production location (e.g. well pad)? If yes, review the following two exemptions for applicability: - Does the operator unload lass than 10,000 peons (238 gals) per day of crude oil on an annual average basis? If yes, this a Assbu point is categorically exempt from pima nook -womb par Regulation 3, Part 5, Section II.D.1.1 Does this operator unload less than 6,750 blob per mar of condensate via splash f01 or 16,306 bbb per year of coMensate via submerged all procedure? If yes, this omissions point b otegMolN exempt from perk requirements per Ragulatlon 3, Part a, Section IIA.LI Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Alr Pollutant Emission Notices are required for: each Individual emission point in a nod -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 Applcant is required to file an APEN since emissions exceed 1 ton per year VOC. Part 8 —Construction Pemnft Exemptions Applicant Is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TM' threshold (Reg. 3, Part g, Section II.D.2.a) Pert 0,11LD.2 - RAC requirements for new or modeled mbar source This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenence areas. This source is located in the 8 -hour ozone nonattainment area, but not the 1 -hour ozone area. The date of interest for determining whether the source Is new or modified Is therefore November 20, 2007 (the date of the 8 -hour ozone NA area designation). Since the tank battery from which loadout is occurring came into service after the date above, this source is considered 'new or modified." New storage vessels will be constructed upon issuance of this permit. Operator is using submargad fig and controlling amhslons.ola enclosed combustor, Therefwa RACT teq tr nb re satbtad No appYoble subpart This facility Is not classified as a bulk gaso0ne terminal. Re.nfaebD 7.- Volatile ()rank Compound'.: - No sections apply. Per Regulation 7, Section VI.C, a terminal and a bulk plant are defined as a petroleum liquid storage and distribution facility that has a daily avenge throughput of more than 76,000 liters of gasoline (20,000 gallons), which Is loaded directly into transport vehicles This facgity b halter a tmnsihai, bulk pie t per dennitlona In Rag?. Section VI G JteNlatlnar 8 NTwrdous Air. Ponpralia,i ,� .. . • MAR EEEE This subpart applies to organic liquid distribution operations (OLD operations). Per 63.2334, you are subject to this subpart If you own or operate an OLD operation that is located at, or Is part of, a major soure of HAP emissions. Furthermore,. this section Identifies that OLD operations do not include the activities and equipment bduding product loading racks, used to process, store, or transfer organic liquids at 'oil and natural gas production field facilities, as the term 'facility Is defined in 63.761 of subpart NN. EPA has confirmed that natural gas processing plants am Included In the definition of 'natural gas production field fadlities' for the purposes of this subpart. Therefore, this source Is not subject to this subpart. ri Hydrocarbon Loadout Emissions Inventory ,5ectlon 07 - Technical Analysis Notes L. The sample used o esttrnate the HAP emissbm from this source was, obtained from the Mewboum to Plan een March 11; 2009: THs samplenrsults b massfrxtwhs tint are more , ; : tNe(L geaterth.e( those.pprovedi Issw«e4.51ncetlteaperat isonlyrequeztlng tobcreenothe:thbu�prt inthisiswance, ltwasdehnninedthon newsamplewauklnotbe' rcgW11:'1! sta knew emiflontittdrs: .. 2 Baud on information provided by theoperator :Ihe emhsbro renelSe; frmn Me 0.40 t operotlon are routed directly from tle,taeker trucks to an erdosed flat¢. 11th enclosed March afro "used o cu ,": •] issl from the condmsao sto.:!I* sseh. ': > .. 3 In oNer;to cakulete coritbustbn emissions, opentor.alcWated the volume vented dirc6hg loadout otentbro using the ideal�jps taw (PV•, nRT) 7}ie values used In this nkulatlon arc as follows .,.,. . ; : ..,.•......._. (Iln (64.556 ton/year)', 121%7016/tonl•:I11Dmd/6616) 1956241b, d/yeu :-. :: I ]•,10,P,'!....#42 psis (IB)T 51215 R (52F( :> (lv)R 10731 Ps4 fr 3/R.;Ib•mol V (195624 Ib-moUyearl'110731 ps4 R 3)/R lb:md).(512450)1(2212ps4) 68756866N 3/yeat ;; le order to calculate the obme cored the . ti operator utillied actual conditbro of tempmo a . ... aM ix'essero 1,vii psi) r.s/v . the wlume viuA then need to be convene sea dnrd canditlohs of temteraturc and Pressure. This an be done utillling the combined ps law.whkh sta.„, (P1 ,„. ..,3 QTV2)/RI Using this equatb Mo.! Boll.. eempe , t re (60'F) and presw (14:7 pda) the vohhme vented b••,. bee deteirni ed t be the following Vl 51212pda)'(667,5$0.66scf/year)'(51967RIUI1512.45R):(14.7pda)) :742'11836 f/veer.;,••.'„,"„i i; Since Uie�atarhd E vented eslog the' cdmdneE pa law is 1<sa conurvatlire thin ttie operoror estimated actwl vdu'rne; rate natal wbme is en xcepteble estimate.. .:: .. . ...b The operet6 determhied th . hot value used in the combustionnku on nice Ined:o on be 661b/ib•md hued AP -42 Chapter. 7.Table 7.1-2. Barad this molendu weight k Boa assumedthe neatcoete I of the gal woWd fall between thon of Butane (M•W a m Neat Coeteet 3 262.4 Btu/u� and Pentane (M W 72 1491h/Ib-mot; Ne t Cornent "4 0009 Btu/scf):Us6q [tie olewlar weight and heat content of Butane and Pentane the opnxatei interpoleted.the hear content f the ''rte jar to be3,677Btu/ad TMi heat content Is the gross heatvalve (Le. wgher heatlng value) which I' taro tense tlo the the et h at value (Le:leaver heating value). The TNRCC document spMlkdry Identllles the t o the net heat lire for NOn and CO emeslons olci atlonn As result, the the of the gross heatvalue here iii 5 The NOx and CO emissions were nelculated utng Oro emissl s talon from o TN0.CC Technkal5upq m 4 pares. The emndons 4dori toed'0000 130lb/MMBtu nd 05496 m/MMBW ..for. NOx and CO, fespectlyely. Barad on tie document, the emission looter'utillzed for CO• is for air/unaisisted flares wftH a vste gu'stream that hn a taw Btu coment.The documeen deMes :( taw ten lender '3982;000 Btonld. Technla0y, the waste gas viou. be.. .. ..ddooumem sin. a tie was. . hot Cement was estlritated to be 3;677 Stu/of; -e �.however: the emission factorPmvkled for{ -. - "._ _.___. .. .._. _ _ _ .,conservative and therefore iraeppde:.:� 6 The TNRCC emindoni factors• Per NOx and CO were converted from Ib/MMBtu to Ib/bid using the followinacaiculetlons:' BI Cslc"ulate gasto;oB (GOB) rail :18S7,58E 66 zdty rl'11 y a /63S,229 bbl) � 1:3909 sd/bbl (11),Convert front lb/MMBtu to lb/bd:; ..:::' :. :'. .. ... ((NOVa(033g16/MMBtu)•(3677 MMBtu/MMscf)!(1MMsd/1000,000af/ idj'17:3909 bbl) '0.0007116/bbl ....::,.t..._.,...k,.n:......e.nrn:...o...n.:..:uu.....r..pOp00Dicfj.IL3909. scf/bhl)�0.002D116/hbl.' 7 The operpnorcekWated emiss•l nifrom [n pibtandDiugeguaswci-tedwith ehecuntmidevke( :dosed ...Meter), Theseemissio ebesedo Dibiflow�roo of 60 scfh;:azsistg flow of 1200 scf t and emiislon fatten from AP42 Chapter 1 Sectl 14 based o 0760 hr/yr peratlo f the combodoe Shoe the'cowbtzdo Is used m control the, storq o ks (Point 005) 'and thisemisslon unh, the fuel woof the combustor is apportloned baud on the relative emhsbro produced from the rcspecNe process streami For ex..mple :this loadout pdrit Is atMbuted 1'66.2%of the fuel gn combusted based on followingthe het flow to the fla ._, . .. .. .. .. .... ... ..._ He tflow fin Point 00516 combustor. 1.666'MMBTU/yr ,,, Heat Tow from Point004ocombusor:3,263.66 11(3,263:66 MMBTU/yr)/(3263.66 MMBTU/yr+; 1;666 MMBTU/yr) 662%attrihuted to ppl 1001 3 (3 6663MMBTU/yr) / (3263 66 MMBTU/yr+,1666 MMBTU/y ) • 338% ttrlbuted to pohtt 005 3 II III '. i The operator Indkated thae assist gar I rep i ed he the btu of the waste ins is trot hfBh enough of rtfico burette combtst the waste gas complepery Also in order o avdd ozyQen brake • a small aeiourrt of slit '6 sometlmes needed to keep th lines e bas. . pur{ed: The 30 scfm'purge uss roe Is:based'uhi tkld Novdedge irid experknce!. D The opener did not olwleo PM emissions assorlated wkh the comburtbn iwdoutaM condensate tank emisslom thrt are routed to'and oontro6ed by the enclosed flareTheaperator asserted that stoic the enclosed Boreli designed to he airnokeless combustlon deWoe; partic den co tter h trot expected tube generated from the odmbudlon of condensate tank and loadohrt ' wonte go outed o and contrdkd by tee 8 e . 'a t - '_•:. 1 and to dd this state t o emission factor source for bustl emhsi (NOx ndCO) AM2Chapt :335 rMewed Thhd«tmient pr the isoloenfroe,flnoIe ry tad d carbon W rtkies (soot) nhumed hyd arbans CO and pertlally burned end eltered hydroorboro. Also emitted ae nitrogen oxides (NOs) and If sulfur tonoinbg matefal such s' Eitydiegini... Sulfide r wetnepons h Bored;'wlfur dioxide (102) Based on thin of m ;the d« t does not Provide infornation volth regards to partk let matter except w th regards to ; noon. The'document further provWq that a smoking flare dl etUy reeuhs i soot fo atlon when it states 'The tendency of a fuel to smoke or snake soot is influenced by fuel characterlstln irid; ....- .. No _ by the amount and distributors of oxygen In the wmla¢tlon xotte:'Tlih h (urtherwpported by footnote < bekhwtable 135 1 hkh provide the foposvbhg:'Saot N concentrationvalttes ; ;`. nomnhoklrq wren; 0nkiograme per Mat (pr/14; II{htly smoking Bares; 40 µ6/L; aveoge smokirg flies,:177'pg/L;and heavily smoking hares, 274 pg/1• .. At this time • there is not another isotirce-of anti. that quantiflei PM10 r PM23 from industr4l tyres nd therefore it w10 be ed that the kali Mance Ofperilcidete mm .from a flare h soot froth smoke as expressed lo • •,,;. . It shoWd be noted that the O&M plan requkes that d M Checks be conducted o determine If the enclosed Bore hsmokitq. f smoke is observed dining the daM ohedt the source h reguked to ' either conduct i method 22 w MmedleMy shut I the egulpment o imestipta the aura of the smoke, nd cordud repdrs u etesssry Based on thin rentdrerneritTer the enclosed flare e.nd the manufacturer design for the enclosed Borg o be okel if operated Proper..:,* an sahN be asw edthat the eodowd Bore wl3 operate without snhoke on a Mauler basis. Also if amok i 'observed the open or vv@ be reeulrcd;to asshtis.the Drobkmand panto necemry maintenanc' o pevent the endesed Bare feSin amok..ig: Iu such. Tarn camfoilahkammbg If the tool PM emission facer of 7.6 iti/piniiit fninAP-42 Chapter.1.4 were osed'tlie reel PM isslonn (far both PAX ,10 aih4 2.5) would be below OPEN thresholds. As cis; the entisslorts uM t result In pennk ain't; for PM er result In addltlonal reguletery requkementi BatedOothelnfoiynetle.ndiienised abovei h was determined that the operator'sserton that a smokeleisflare would not beexpeded to have PM ewinolo s wks valid:However- if better date h developed in the futuretor estlmatbg PM endssbm from Industrtal flares It should be irduried b tutu analyses..; .,: •.'• ..: ._.. ..... ..... . _ ... ,... .. 9 Since tltK loadout operation hu u«unrolled VOC > 20 spy, tiperetlon using subrne'r�ed PoI 1 I t sufflderrt t eat RACirep Wremmo. Hdwevu uu of suhmet,ied fill In conlutictlon with control using en endosed combustor has been determined to satlsfy,RACT 10. Upo nevi f o draft permk DCP,req red tNt the emMY Omits be ed fro td c since k has 32 modhsof ..dual productl dita it was determined thatthh was an ptabk.iequest•nddukhg that M addltbnalthroughp t assoc4ted with th " pr cesslnt t in:vsli be nHored one monthly bash beadnew stoiiii6 tania point. (031) and a's ;ectlon 03 - Inventors SCC Coding and Emissions Factors AIRS Point I 004 Process I SCC Code 01 4 -0M1001 - Pollutant P1.446 Pk42.6 NOx VOC CO Benzene Toluene Ethylbenzene xylene mnesane 224 IMP Uncontrolled Emissions Factor *REM #R6Fi 1.68E-02 4.017 6.69E-02 6.40E-02 1.77E-01 1.32E-02 1.34E-01 3.41E-01 2.55E -0a Control % 046% 1660% 0.00% 9500% O00% 95.00% 95.00% 95.00% 95.00% 95.00% 95.00% Units lb/1,000 gallons condensate throughput lb/1,000 gallons condensate throughput lb/1,000 gallons condensate throughput lb/1,000 gallons condensate throughput lb/1,000 gallons condensate throughput lb/1,C00 gallons condensate throughput lb/1,CO3 gallons condensate throughput lb/1,000 gallons condensate throughput lb/1,000 gallons condensate throughput Condensate Storage Tank(s) Emissions Inventory 5.000. Ol - Adnimbtradw le .o iln (Fealty Ants ID: County Paint je00n 02- Eauhnn.nt Dec.1.1on Deb01 [Mailed Entialons Unit /Fors 14) 4O0!cruel Rsd reel steb6laed emel gn oadanvte ttarq.030 Des0Spbm ::.. Emlon Cantrol o.vb.to )Ed Description: dbesd ,4:. :O(labniM VCd1277911. Uru?m{mrnbmemrdwnt4n .ndeebro.w Mai*Mai* pbMtlWe. ; Requested Overall VOC & HAP Control (Rider's., 94: Primary Emb 100 - Storage Tent's) Actual Condensate Throughput. Requested Permit Unlit Throughput . Pot.mlal to Emit (PIE) Condensate Throughput • 470 Barrels (IMO per par' to Smelt (bbl) per War Bmeb (bbl) Per year Secondary Emissions - Combustion Owings) Hut crn.nt of wan gas. ' ii � 9-' >i'i 3077 Btu/sd Volume of wan gas emitted per SSE of liquids produced . 6709743211 .d/bbl Actual hest content of waste gas routed to combustion d040 • Request het =Mont of waste gas muted to oxnbus0On device. Potential to Emit (PIE) Mat content of waste gas routed to combustion device • Atoiba.d fuel combustion . Section 00- Eml0bm [Mon 6 MaMdebMs Will this storage tank .nth flash emb lm:0 EPA Tanks Result VOC Emission Rate. Total * of Vessels Total VOC emission Rate. Pollutant Bent* Toluene Ethdbent.ne avian. itHeam 2.2.1-TMP 65132 Actual Condensate Throughput While Emissions Controls Operating . ; 276)6 garrets (bbl) per year 722 MMSTU per year 1,644 MMBTU par year 1.666 MIAMI per year ,.(L.9797( Nitcbd per war • Emission Factors -. Condensate Tank *salon Factor Source Pollutant Uncontrolled Controlled (6Ab1) (64/801) (Co drmte Thrpoiph) (Cod..* Tbmrghpot) VOC LORE -01 5.162E-03 oft SPITd&e`EPATANc6ES.Wa,Mb6 IBMtrutAln Ts EPATAN16 E�J WMIh6.M &oatk 9trSpedReLP TAN0 S3 Wak644adOr able '' "ftWEk(PAINi1ESE.T We4Ybjaod Or a1BY. 7)005pod4 mums LPr Working and IMMOd* tea AI4J o-'�lT®.vwft✓r.aa', SId SprNk mATANN9 E.P. WerONg.ai BtoeOde gent* 1372E-03 6.660E.o) j Toluene ToOne 3.901E-03 0901E-0 Edylkenane 1033E-01 094 1870E-03 10437E-0 n-Hmea 7.311E-03 3.691E-00 _ 224 IMP 5.072E-06 2736E-07 Sh0390030PAP* *.LWe.Wgmad **whim P* rum Control Devise Endabro. Source bn E Uncontrolled Uncontrolled () (6/864) —6/50.00 (9alM heat cos bMed) (Condensate TBr..gbierd PM10 0.000F400 PM23 0.000E-00 tiFr b TNPCCFbw Embelaas Gddmn(tFO+4 TNRCC Ran ntr`alamGWmniC� Nita 6]360 3.601E-04 CO .,> 390 1134E-03 P10utent Control Device Fuel Emission Factor Source Uncontrolled Uncontrolled I6/FAOSCF) ; 1JL ;u ., (fuel gas *busted) l'ooaldlida PM10 ': 7.6000 / . .AF42Table1.8.22(PMI0/Pptav91' Ta8le 3,t.I(PM1.004e. S) / T M.42 Ta81.3.41( AM162T 6' !W) P142 -57.f000 s0 '�`' ' ..Nita "'. 300.0c03,!: ' Co 64.0000...,_ / yam'' Section 0S- EmMbm Mrrhory Criteda Pollutants POa0(1(to Emit Uncontrolled (tarts/p...) Actual Embda0 Uncontrolled Controlled (tom/wul (tons/year) Requested Permit Undo Uncontrolled Controlled (tomMar) (.0.0/p..,) VOC P9110 PO4.3 Nita CO 3255 10.27 071 3235 165 0.00E+0 0.0[400 0.00E-00 0.00 0.00 0.0UE+00 0.0E-00 0.00E-00 0.00 0.00 115E-01 4.%E-02 4.98E-02 0.13 O13 1.58E-01 098E-01 198E-01 0.53 0.53 Hazardous 41rPollutarts Potential to OM Uncontrolled (0000/9...) Actual Emissions uncontrolled Controlled (tmW..rl (tons/...) Requested Permit Limits Uncontrolled ConOW.d (tom/war) (r000M•r) Requested Permit limits Uncontrolled Controlled 16W erl (6s/we) Benue* Toluene Eth96r ror Eylane .Hesaue 221 Tom 00379 0.1897 0.0095 0.4379 00219 876 M 1.2130 0.3235 0.0263 1.2130 0.0607 2426 121 0.0901 00392 0.0020 0.0304 0.0045 121 9 0.9172 0.3973 0.0199 0.9172 0.0459 1834 - 92 2.3555 1.0204 0.0510 13593 0.1170 4711 236 0.0017 0.0008 0.0000 0.017 0.001 3 0 Condensate Storage Tank(s) Emissions Inventory Eaggsa OS limdatoor_.%rnm IY naMt Regulation 3, Parts A. IS Regulation 7, Section 0II.C, D, E, F Regulation 7, Sedlon 111.0, C Regulation 7, Section XVII.b, C1, C3 Regulation 7, Section XVII.C2 Regulation 6, Part A, NIPS Subpart Kb Regulation 6, Part A, NSPS Subpart 0000 NIPS Subpart 0000a emulation 8, Part E. MAR Subpart HH (Sae regulatory eppkabllty worksheet for detailed analyale) Source requires a permit Storage Tank b not subject to emulation 7, Section XII Storage Tank Is not wbjact o Regulation 7, Section XII.G Storage lank Is subject to Regulation 7, Section XVII, 6. C.18. C.3, as Stooge Tank Is not subject to Regulation 7, Section RVII.C.2 Stream Tank Is not subject to NSPS Kb Storage Tank is not subject to NIPS 0000 Storage Tank is not subject to NSPS 0000a Storage Tank is root subject to MAR HH $colon 07 - Meal and Per** SamoMe and Te¢Ina AeeoMmeng Does the company use the state dehuh'embsions factors to estimate emissions? If ye, are the uncontrolled actual or requested emission ctlmated to be greater than or equal to 93 tons VOC per year? I/ ye, the panntt will contain an 'Initial Compliance" tasting requirement to develop a **speak *missions factor based on guidelines In PS Memo 0501 Does this company use a site spedfe emissions factor to estimate .melons? • If yes and If there am flash emissions, are the emissions factors based on a prevudtad liquid sample drawn et the facility being pomtided? This sampla should be mnsldar d representative which generally means site-spedflc and oatle¢ed within one year of the application reeved date. However, If the facility has not been nodiflad (ai., no **welts brought on-Iltw), then It may be appropriate to use an older sttespeddc sample. If no, the permit will contain en 'Initial Compliance' testing requirentent to develop a site specific embakKo factor bead on guideline in PS Manor 05-01. N/A - Operator Weulabd weaken aeleg ske spedtk EF Des the company request **Vol device of ldency grertethm 95%for a Ilan or combtocbn deice rMl ss£•�'-�3 -', ≥`='''.5;'�% If yes, the permit will contain and Initial campliane tau condRlon to demonstrate the destruction effde y of the combustion dMe ba.ad on (net and nude coroantradon sampling ;edam Oa - Tadrnkal Anaysb Notel .: ;� : is �:;:ii:; 3: 'L"Oa6nMori if'motilRotion 40 CFP rt60.2:'AId9 i3"'»> ::.:::. ...... ; >...>; . .> per pa ......ryntanmeuuanY.P,h1'ya,,.l.thaegeln;:v chaP{i In th'i mrthoE o/eywitksn of,inNbdn�hteRy�ihleh Increases thiimduritdinYalrpd0utire333i .."" ".... . (owMdt a.mhrd appllcj"imhied Irde M� rtmmpM.ri,hy that facilkyer,whfdt rculb M M:milslan ofartyibpolbrom which a siandsrd appllc) (ntu�tln'Gtmmphiri''d'o[ Dmbusly irill{tad.', Sourabnot rsquctleg arty dw gst[d throughpw bu ....h f m-phyA Ith np(soum only ',vaulted asoppcoed tog origt IIY Perimtl!d). As KMe'atoraP vcaele weuld�, not 6e,conskiridsnodMid tMellohb definition Ai iuch; soii� bpotiibiilFj:sutijia ter NSVS 0000 based anthi origMi coretrsi¢kinErta: on, regulatory analysis; li Wes:determined th pic'u .»...::3>: >.... store{e'J6sels ire'not wMect o NSPS 0000 because the potential VOC ambalons Perstdrage vessel are less than 6 toy 2' With Mb. ._,.,. permit modllbtlgn [M agrattiils �agyadng to.updrta amksiom fi¢on biiad'uri.0'stcrgi tanks rrtMcthm g is dlscusaid' In hvn gl abdJi'Aii'vtiid EPA.TAN16"wa iubrilkeN td». .0 ,,..:,,3...._.33.: :x.; ,: »:;:.,3;;3:;.>:;;::;;:. ... davab .bad ambsbn h¢Pm,,,,,,,,,,,,,,,,,, ... .... ,.,,,»:-»........::.::: __ .. ,... rat _.nH ,",....j ..31-:I �>..;,I.,]�S???:»:i??a=?;:::,'10,3.6 1 Based on tl» eoeess desrnilRbn provldid?y theoparrtor, Ma cende ta Mrt rcubi• 'rt Na Inlet racNvinj'rta'{i ind... hkh h'raabiA ham p'"tesbiiitiu� hcm'botxi(v stations h pnxmed IA priorto dbMbsrtbnto the Aar :'wuab::''' itabildc b ass."4'awParatbni',!r' dirt nrnova tM: c:i••'lOgMiii Mdretarbons lionsglee lyuk to milt RVPapadflotbn;; .I,... 3.1,333 , ;,; :>:i; , -" ;..... ,. >; ,..,..., ;:::.:>>i:....>.;:?.: is ., . .,, 3,,;;.> 3.,3 ;.3.:3,.:.......y.>, ,.. 3.:..,,... ;33::: ..... .... ......I ::::??;:;;:;;::;;;; l The source ttwd EPA Taub 9.09.4 to akvltte werkLw and bre.i7 imbsfons and amlmed dehuR pregrtle afCwsdlne RW.�fO"ind meM• nsla{Ital data for Darn"ir CO. This approadi Is'acapn kah e a tM storage vaceb it this h,i7= rtora st b1ih I { d• at Sine tM modem 1 p rized M B h irniuioro will not scour. EPATartis aA9 d IY kulae t orhAig it bnatNn{ambslons aid btherribnmiccuiata inrthod torestlma[Isw embilem from [hti wu¢a.' "" S.'" '1".gto Fundarmmahof NawmlGaProcawtnL'Serond Edgbn, hY.Xld'uy;Patrbhard Mc4rtnry ,:7, Vapor P. sure)vahx: rengefrom lD tt 3apel;but lhimmm...r,,i. bereq ied. , 'wMntMl uldtitmcked ofhki..". Dui to tit W .... , ..... 1;•_iiiwnlrit Gaao6M RVP?Mil!•us•"".,u Tank;0.09.d:aPWan to M'araasaub4 astlmrti ta'r chi caMaean composbbn... L.Thes:::. usedto'aulmatatM HAP ambsbnsfromthisscum wasobtalnsdfromchi MaiiEoui.".7!: neon March 112009.Thb simde was m.d to eat'trnatachi HAPam�bil3orii�ln'piivlotb: f hswnes Par: apdkatldn iiditiiJ luh.2012 Ikios chi tip....:. b rict'iyirstlry' �iry'proccs cMii[i ttii[ woukt elect 6qutl'mmpokkldn,'k wa AelirtbMid that i Mw i'urtp...... lanai bi nrpidrid •e.bibhnewambibn h¢ors-.,,".".-> :3: ., ,.• l7 iaiiiit *alculrt. mbustbndmtvbns"op.n oro tad lof i n ;(n n': (11G;473Ib/yr/tank),'.�(l Ibmot/66 ih) • )4 tsnlsj'.99S.36314mo1/yaa (e)x.12.13Psli 1,.'''''».:: :1131e;;;Ii:l>3' I(9,Ta512:45R(S2p)".1'x,',,,3 ,13,3313 :(v)Rti 30.791 Pala R 3/R•Ibmd ,„ :'V:(69b963bett n00 ) (10.733pa1 R 3dMllitnole•(512-d5R(/(12 ll psis( a5D7LT si'i'dyer v...'tilysb imasfw Wafoidbwubnmuandad kmtiiiiiii ualwlura La.sd w. h^3 skaendtbns j t -;3.3;;;':aC??':?i?i?',; ,,,,,,,,,,,,,,,,,,,,,,,,,,,,:,:-;a;3..,.; , ....»::--:;:a.::k;., L In ordarto cormd amlaslon factwsi an SCF/bbl hctorwu usad:Thb was alallatad � ��tdlowa as ,. ._ ,.,, id/6b1d (a5297b.7.sd/yr�/ afE,7 9 bZi,i ,.07097 acf/bbl'.,.;3i i»*,»., .,. 'Pleiii iii ge'In the ethnical ,.. amlysla jwtc tocMepohrt OD4fadbaalenniirdits th�i Aotvalw used in Mi mburtla �uldulitb� ... -3».. ;; .... 33. .. .,: ,.. 3,.3 ,?�: ,, �....;: , r, ':I?33> ,..3?I, I j ) .. ,,,..o.. : ;9 -The oemdewilln 7.ln 7,.,.n (orNOx and CO Meuse Me millions ri bebi APEN�repartMg M.raslidldai Pliii ealtoldinlolinahysb netas e7 iorP at usi::-::>»:3.',s�?:'�.::.>a>3:� ? ' '.:.... 3 ,,3.3>;. ,: ..-.. Il -:;3, ; t combmtnnhrel 3 ;,a>�; �. 3i,>. .�: .....»v».v,,,".............."...._....: � � ,...,A�f:.3.,,n,,.., ,..,,.,..,".,,.v'''.f::x.:,.•• ::.,::»>3::r... ,•., 10.EthylEmtacls &'2,1,a;TMP imtiiloiti'!no below'APENiepoNeg dir'isltblds,(<]9p Ibi/yu act eThivalves'uied Intltnulalrtionaraii follow: =1L Plus. see Kfn Metedsnlalim isnotisfw.tM Gtt004 hird9diclon Ialob wlt PNimbsiad win mnsblarW ire Raub forcombtNtlen of warts a frtim radii's! . ",..M iri.,,-.1133.po.. ._,..e:•_,,,et?... t...._Y:............. ..... kN....»,...... !s tlsi tartdanuta lanbtewi b?, coated en —and ,,,,, »„ 3,,..,>..,;> , .,_,,.,,_,.?, 3.4.e:,.,:: . .......... .. .. . . corrtcobad thsendstsed Ogre:�„„,,,-,». :.: ., ...,., ,,,, ,_„�.... ,... .,. �.: .. M , __._.._.._.-'- .. .. . , . ,Rill. . .. ,.,:.. >3.,,,.3.,,. .l{ittaotrCif .> ;:12:Sinai Rerspta'ni j'(.' itidii Ma'!' ". .4.of,NAP,amlasbns,RbpotcdldM,subla¢to MACT3HH.However,Rsussd.Nmfmd that thib:„---:mkideh...... tit. keels PotanN9l lot,bash'. 3m.ritel r.:_. .... ................, -...ants with the.p,tentil. f.. ,..:"... ,.......... .., .: ..... ,.... ..... ._,.. .. .. ....... • ice, icon (63:760( si-ei a SBone ,daeies:r.• 'Poterrciilfd'kdi iiinbslorieSeddifiee:,si6'Sieee nineyLotie 0.n07dQweii'i ztcolonel[sMepull toai. Thertjun Q3Scubkinek'CIPir lkar1.4, 3." , . ,.": ,rt .,, .... .,,._,,.. .. ,N.IanvRv'equel to o�iriaur Min iO,dyr::.-.•TM o4tenk GGlt,'n ular4tid �ibovi.wu"GKi�mrlriiG�to tie 01Ap7 siibM.� "' ��'p�tink'Eoie �enava ,: .,N x n.; � .. eerMi Meuse. M ( .,,.:, �; tM etttlal rx hash emlabrs. ;>".. �".. •'.≥»::'3'' »'>� Allis Point 035 Proems 9 tSCC Cade 01 1{-04-00SI Pollutant PM10 PM2.5 NON VOC CO Banter* Toluene Ethylbemene Xylane n-HmM 224 TAR Uncontrolled Emissions Factor 0.COEn00 0.OOF00 1.37E-02 146 3.93002 3.27002 9.05E-02 6.75E-03 6.84E L76E-01 130E -0a Control % 0 0 0 95 0 95 95 95 95 95 9S twat b/1,000 gallons condensate throw 6/1,000 gallons condensate they b/1,000 gallons condensate throw b/1,000 gallons ° Neens. throw b/1,000 gallons modem. throw b/1,000 gallons conclave. throw 6/1,000 {elite condensate throw b/1,000 gallons sndermate threw 6/1,000 gallons condenses throw h/1,000ullorta condensate throw b/1,030 gallons condensate throw 9053 K:\PA\2011\11 W E 1ab1cP Salim Condensate Tank Regulatory Analysis Worksheet Colorado Reeuletlon 3 Parts A and B-APEN end Permit Reonlremenq ATTAINMENT - Since this facility h looted In the ozone non -attainment era. end CO emissions ere c 2 ten. all goestlone In thltaeddon an listed ea N/A 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part &Section 11.0.1..)? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and t.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NON greater than 10 TPY or CO emissions greater than 10 WV (Regulation 3, Part B, Section II.D.3)? 'Source is booted Ina non -attainment urea NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A Section II.D.I.a)7 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Mena 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions hom the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section 0.0.2)7 'Source requires a permit Colorado Regulation 7. Section XII. 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank looted at an oil and gas exploration and production operation', natural gas compressor station or natural gas drip station? 3. N this storage tank located upstream of a natural gas processing plant? 'Storage Tank is not subject to Regulation 7, Section XII Section NII.C.1 - General Requirements for Air Pollution Control Equipment - Prevention of Leakage Section KI I.C.2 - Emission Estimation Procedures Section 011.D - Emissions Control Requirements Salton nILE - Monitoring Salton KII.F - Recordkeeping and Reporting - Colorado Regulation 7. Section Ktl.q ' 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at a natural gas processing plant? 3. Does this storage tank exhibit "Flash" (e.g. storing non -stabilized liquids) emissions and have uncontrolled actual emissions greater than or equal to 2 tons per year VOC7 'Storage Tank is not subject to Regulalion 7, Section 011.6 Section 011.8.2 - Emissions Control Requirements Section KII.C.1 —General Requirements for Air Pollution Control Equipment — Prevention of Leakage Salton KII.C.1— Emission Estimation Procedures Colorado Regulation 7. Section KVI( 1. Is this tank located at a transmission/storage facility? 2. Is ON condensate storage tank' located at an oil and gas exploration and production operation , well production facility', natural gas compressor station' or natural gas processing plant? 3. Is this condensate storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions' of this storage tank equal to or greater than 6 tons per veer VOC? 'Storage tank is subject to Regulation 7. Section XVII, B. C.1 & C.3, as provided below Section KVII.B -General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XV11.C-1- Emissions Control and Monitoring Provisions Section gV11.C.3 - Recordkeeping Requirements S. Does the condensate storage tank contain only 'stabilized' liquids? 'Storage Tank is not tub)ect to Regulation 7, Section ItVII.C.2 Section 7MI.C-2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR. Part 60. Subpart Kb. Standards of Perfonnence for Volatile Organic Ladd Storage Vessels 1. Is the individual storage vessel opacity greater than or equal to 75 cubic meters (m) l`472 BBIs)7 2. Does the storage vessel meet the following exemption in 60.111b(d)(4)? a. Does the vessel has a design capacity less than or equal to 1,589.874 m' I-10.000 all used for petroleum' or condensate stored, processed, or treated prior to custody transfer' as defined in 60.11197 3. Was this condensate storage tank constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23,1984? 4. Does the tank meet the definition of 'storage vessel"' In 60.11167 . 5. Does the storage vessel store a 'volatile organic iquld (VOL)' as defined in 60.11197 6. Does the storage vessel meet any one of the following additional exemptions:• a. Is the storage vessel a pressure vessel designed to operate in excess of 204.9 kPa ('29.7 psi] and without emissions to the atmosphere (60.110b(d)(2))7; or b. The design capacity is greater than or equal to 151 ma (`950 all and stores a 8quid with a maximum true vapor pressure less than 3.5 kPa (60.110b(b()7; or c. The design capacity is greater than or equal to 75 M' (`472 all but less then 151 m' (-950 BBL) and stores a liquid with a maximum true vapor pressure' less than 15.0 kPa(60.110b(b))7 'Storage Tank Is not subject to NSPS Kb Subpart A, General Provisions g60.111k - Emissions Control Standards for VOC 660.113b - Testing and Procedures 850.115k - Reporting and Recordkeeping Requirements 860.1160 - Monitoring of Operations NA '7.,`,'.rA NA 2/il7/ Yee::WO Yes°:"s....... Note; _.3`-. Yes=s_AW Yes=: --`.j¢, Ya FX+j'°S Iowa Requires an APEN. Go to the neat question Go to next question Source Requires a permit Go to the next question Storage Tank is not subject to Regulation 7, Section XII Storage Tank is not subject to Regulation 7, Section XII Go to the next question Go to the next question • Storage Tank Is not subject to Regulation 7, Section 011.6 Go to next question Go to the next question Go to the next question Source is subject to parts of Regulation 7, Sections KVII.R&C. Go to the next question Yea: '.•T'Storage Tank I. not subject to Regulation 7, Section KVII.C.2 6 -fl Storage Tank is not subject NSPS Kb -The storage vessel opacity is below the applicable threshold. 40 CFR. Pert 60. Subpart 0000. Standards of Performance for Crude DII and Natural Gas production, Transmission and Distribution 1. Was this condensate storage vessel constructed,reconstructed, or modified (see definitions 40 CFR, 60.2) after August 23, 2011 and on or before September 18, 2015? Go to the next question 2.. Does this condensate storage vessel meet the definition of "'storage vessel"' per 60.5430? - 'TIMM Go to the next question 3. Is this condensate stooge vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 4. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? 5. Is the storage vessel subject to and controlled in accordance with requirements for store a vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Sub an HH? 'Storage Tank is not subject to NSPS OO00 Subpart A, General Provisions per 660.5425 Table 3 960.5395 - Emissions Control Standards for VOC 960.5413- Testing and Procedures 660.5395(g) - Notification, Reporting end Recordkeeping Requirements 660.5456(c) - Cover and Closed Vent System Monitoring Requirements 660.5417 - Control Device Monitoring Requirements (Note: If a storage vessel Is previously determined to be subject to NSPS 0000 due to emissions above 6 tons, per year VOC on the applicability determination date, it should remain subject to NSPS 0000 per 60.5365(e)(2) even If potential VOC emissions drop below 6 tons per year) 40 CFR, Part 60. Subvert OOOO0. Standards of Performance for Crude Oil end Natural Gas Facilities for which Construction. Modlfication. or Reconstruction Commenced After September 18.2015 1. Was this condensate storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after September 18, 2015? 2. Does this condensate storage vessel meet the definition of 'storage vessel"' per 60.5930a? 3. Is this condensate storage vessel located at a facility in the crude oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the Industry? 4. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? 5. Is the stone vessel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart HH? Storage Tank Is not subject to N5P5 DOOOa 4068. Pert 63. Subpart MAR OH. Oil end Gas Production Fecllitley 1. Is the tank located at a facility that is major' for HAPs? 2. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(21(; OR b. A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or Is delivered to a final end user' (63.760(a)(3)1? 3. Does the tank meet the definition of "storage vessel'' in 63.761? 4. Does the lank meet the definition of "storage vessel with the potential for flash emission?' per 63.7617 5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or Subpart 0000? 'Storage Tank is not subject to MACE' NH Subpart A, General provisions per 663.764 (a) Table 2 963.766 - Emissions Control Standards 663.773 - Monitoring 663.774-Recordkeeping 663.775 - Reporting RACK Review RACE review is required if Regulation 7 does net apply AND If the tank Is in the nonrttalnmem area. 11 the tank meets both criteria, then review RACK requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Ad, its implementing regulations, and Air Quality Control Commission regulations. This document is note rude or regulation, end the analysis A contains may not apply to a particular situation based upon the individual facts end 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 Ad„ ifs 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 end Air Quality Control Commission regulations. but this document does not establish legally binding requirements in and of Itself. Yes NoMN Wal iaglZ Yes ab Yes Go to the next question Storage Tank is not subject NIPS 0000. Storage Tank b not subject NIPS 0000 - This tank was constructed prior to the applicability date. Go to the nest question Go to the next question Go to the nest question Storage Tank is not subject MACT HH - MAR HH does not apply to storage vesseb without 'flash' emissions _w _. M.. 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P moms m 2222.2.,•2221,22.• 2.0.20....222...• 6q' 21 112.22,222 ..YSY.am.K.m.rll • m =PR .22,22.212112.2,22.22220 22,2222 2it• 2'1 ors ow 2.2221. :. E :'_wa.ttlam� wq_p2NtP�aI reNra i wl rnwi wrap .am 222,2222221.2222.22 • m nn.. 2.222222•24 *2221• 10222.222 A+wuawul suwryslw3 aunIBni Produced Water Storage Tank(s) Emissions Inventory Section 01 -Administrative Information Facility AIRs ID: County Plant :008 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: :Three (3) Rxed roof produced water sponge vessels The':st rpge vessels inciude one (1) 400 barrel vessel one' !barrel ons=et and one (1) 300 buret vessels connected via IIgWd manifold I I ¢ i I,„ Emission Control Device #Emissions from this source are not contmlte Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions -Storage Tank(s) Actual Produced Water Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Produced Water Throughput= 9,270001 Barrels (bbl) per year 27,810) Barrels (bbl) per year 10p Barrels (bbl) per year Secondary Emissions - Combustion Device(s) Heat content of waste gas=_ Btu/scf Volume of waste gas emitted per BBL of liquids produced = (y scf/bbl Actual heat content of waste gas routed to combustion device = Request heat content of waste gas routed to combustion device = Potential to Emit (PTE) heat content of waste gas routed to combustion device = Section 04 - Emissions Factors & Methodologies Will this storage tank emit flash emissions? Actual Produced Water Throughput While Emissions Controls Operating = 0 MMBTU per year 0 MMBTU per year 0 MMBTU per year Emission Factors Produced Water Tank Emission Factor Source Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) (Produced Water Throughput) (Produced Water Throughput) VOC 0262 :. 0.26 ISOSOScedWalenttate EllindudesRash) Froilii Benzene 0007 0.007 produced Water StateEF(indudes Rash) Frwwd: ° Toluene I I 't 3 0.000 Ethylbemene ! 3 0.000 X ere II 0.000 ., Pio`croced Waterto E.F. (includes 9ashj Front n -Hexane - 0 022' i 0 022 224 IMP S .,.,.;,;...:.... 0.000 i Control Device Uncontrolled Uncontrolled Pollutant (Ih/MMBtu) (lb/bbl) Emission Factor Source (Produced (waste heat combusted) Water Throughput) PM10 - 00000 PM25 ... 0.0000 NOx '. 0.0000 CO I : „ 0.0000 Section 05 - Emission Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC PM10 PM2.5 NOs CO 3.64 1.21 1.21 3.64 3.64 0.00 • 0.00 0.00. 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Omits Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Omits Uncontrolled Controlled (Ibs/year) (lbs/year) Benzene Toluene EU ylbenzene Xylene n -Hexane 224 TMP 0.0973 0.0324 0.0324 0.0973 0.0973 195 195 0.0000 0.0000 0.0000 0.0000 0.0000 0 0 0.0000 0.0000 0.0000 0.0000 0.0000 0 0 0.0000 0.0000 0.0000 0.0000 .0.0000 0 0 0.3059 0.1020 0.1020 0.3059 0.3059 612 612 0.0000 0.0000 0.0000 0.0000 0.0000 0 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Section XVII.B, C.1, C.3 Regulation 7, Section XVII.C.2 Regulation 6, Part A, NSPS Subpart 0000 (See regulator/ applicability worksheet for detailed analysis) Source requires APEN, is permit exempt Storage Tank is not subject to Regulation 7, Section XVII Storage Tank is not subject to Regulation 7, Section XVII.C.2 Storage Tank is not subject to NSPS 0000 13 of 52 K\PA\2011\11 W E 1481.CP5.xlsm Produced Water Storage Tank(s) Emissions Inventory Section 09 - Inventory SCC Coding and Emissions Factors Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn at the facility being permitted and analyzed using flash liberation analysis? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line(, then it may be appropriate to use an older site -specific sample. 3Po... a %�NlGa N/A - Operator used the state default emissions factors to estimate emissions 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? N/A - This source is uncontrolled. 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 08.7echniol AnalysisNotes • 3 Thissource Is APEN requ red because uncontrolled:actual VOC emmissions are>Ytpy Additionalty this source;Is permit exemjt because R meet, the categorical permit exemption In Colorado,; RegulatonH Part BILD:Lin. As sock, anrAPEN ,egp'q�/=VermRExempt ktter_will'be is ell for thissource 3d - : - ?, 2 Regulation 3 Part 8 Section III D.I a. intei'Minor sources n designated nonattamment or atteinment/maintenance areas tliat are othenvlse not exempt pursuant to Section ll D of this Part, shall: "apply Reasonably Avarlatile Control Technology for thepotluartts fonwhrch the area.& nonettamment a att 'nmerrt/mai hnaoce As stated.; bove this source u exempt:from permit reyuiremenis per I_ Regulation 3 Part B Section 110 1 m As aresuh this source Is not raqulred to aDDly reasonably a ailable control technakgy wnkh would be an enclosed flare to control emissions from the produced ! waterstorage vessels 3, _ ,,,, .3„ ,... ,;.. AIRS Point g 008 Protest a SCC Code 01 4-04-003-15 Fond Roof Tank. Produced Water. workopcbreatnigtflashisg losses Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.0000 0 16/1,000 gallons liquid throughput PM2.5 0.0000 0 16/1,000 gallons liquid throughput NOx 0.0000 0 lb/1,000 gallons liquid throughput VOC 6.2381 0 lb/1,000 gallons liquid throughput CO 0.0000 0 lb/1,000 gallons liquid throughput Benzene 0.1667 0 Ib/1,000 gallons Squid throughput Toluene 0.0000 0 Ib/1,000 gallons Squid throughput Ethylbenzene 0.0000 0 lb/1,000 gallons Squid throughput Xylene 0.0000 0 lb/1,000 gallons Squid throughput n -Hexane 0.5238 0 lb/1,000 gallons liquid throughput 224 IMP . 0.0000 0 lb/1,000 gallons liquid throughput 14 of 52 K:\PA\2011\11 W E 1481.CP5 adsm Produced Water Storage Tank Regulatory Analysis Worksheet Please note that NSPS Kb might be might be applicable for certain tan W at water management and Injection belittles. If the tanks you are revlewMg are at one of these facilities, please review NSPS Kb. SH�1�edon 3 Parts A and B - APEX end Parton Requirements You have Indicated that source is in the Non.Ansinnoeot Ares ATTAINMENT 1. Are aswntrolled actual emissions from enycriterb pollutants from this IndMdual source greater than 2 TPY (Regulation 3, Part A. Section II.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank located at a non-cornrerclal fadO, for processing oil and gas wastewater? (Regulation 3, Pan B, Section U.D.1.M) 3. Ara total facility uncontrolled VOC emissions greater than S TPY, NOs greater than 10TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.3)? 'You lave indicated that wane Is in the N tnAtLlnment Area NON -ATTAINMENT 1. Ma uncontrolled emissions from any criteria pollutants from this IrdMdul source greater than 1 PT (Regulation 3, Pan A. Section II.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank looted at a norwommerdal facility for processing dl and gas wastewater? (Regulation 3, Pan B, Section R.D.I.M) .3. On total facility uncontrolled VOC emissions greater than 2 TPY, Nos greater than 5 TPY or CO emissions greater than S TOY (Regulation 3, Part B, Section 11.0.2)? 'Source pubes APES, is permit exempt Nevado Regulation 7. Seaton XVII 1. Is this tank located eta trammlcsion/storege faculty? 2. Is this produced water storage tank' looted at an oil and gas exploration and production operation, wen production facility', natural gas compressor stations or natural gas processing plant? 3. Is this produced water storage tank a Axed roof storage tank? . 4. Are uncontrolled actual embsionsr of this storage tank equal to or greater than 6 tons per year VOC? (Storage Tank Is not subject to Re4ulatlon 7, Sen'wn 11Yi1 Session ]MI.B- General Provisions for Air Pollution Coned Equipment and Prevention of Emissions Section lVII.C1- Emissions Control and Monitoring Provisions Session ]MI.CS- Reordkeeping Requirements 5. Does the produced water storage tank contain only 'stabilized' liquids? If no, de hgiaWe additional provisions spay. 'Storage Tank is not widen to Regv'aticn 7. Section 'N.C., Section ■VII.Ce. Capture and Monitoring for Storage Tanks fined with Air Pollution Control Equipment 40CFR. Part 60.Subeerl 0400. Standards of Performance for Crude ON and NaNnl Gas Production. Transmisslon and Wsxlxrdo8 1. Is this produced water storage vessel located ate facility M the onshore on and natural gas production segment, netwal gas processing segment or natural gas Oansmisslon and storage segment of the Industry? 2. Was this produced water storage vessel constructed, reconstructed, or modified (see definitions 40 CFR. 60.2) between August 23, 2011 and September 18, 2015? 3. One potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? 4. Does this produced water storage vessel meet the definition of 'storage vessel.' per 60.5430? 'Storage Tank Is nut subject to NSPS 0000 Sobpn A. General Provisions Per 660.5425 Table 3 460.5395 . Emissions Control Standards for VOC 460.5413 -Testing and Procedures 460.539516?- Notification. Reporting and Recerdkeeping Requirements 460.5416(x1- Cover and Closed Vent System Monitoring Requirements 460.5417 -Control Device Mongering Requirements [Note: Ifs storage vessel Is previously determined to be subject to NSPS 0000 due to emissions shove 6 sans pr Year VOC on the applicability determination data. it should remain subject to NSPS 0000 per 60.5365(eNl) oven If potential VOC ambgnes drop below 6 tone per year] RACT Review RACT mime b required If Regubdon 7 does not apply AND If eta tank is In the ronatolmrd area. Role tank neat both criteria, then review RACT requirements. Disclaimer This docunenl assists operators 00th determining applicability of certain requirements of the Clean ...ea Rs irpienenting ovulations, and Air Ouagly Control Commission Pepuleliom This document is not a rub orregulation, and the Meya'is d contains may not apply to a pdiwler situation based upon the individual facts end circumstances. This document does not change or substitute for any lam ovulation, or any other legally binding npdnment and is not legally enforceable. In the event of any conflict behr.an the language of this document and the language of the Clean Air Act„ Ale implementing reuisdona, sod Air Quality Control Cmnicdon reulations, the language of the astute or mutation big control. The use of nomnrndafory language such its 'nconrend, "nay,' 'shroud,'and'can,'is blended to demibe APCD eiterpnlatbns and nownnerdetions. Mandatory terminology such es 'sad' and 'required- en Mended to describe oonboltbpngdrementsunder the temp of the Clean Air Ad and Au Quality Conhol Commission ovulations, but this document rtes not establish Melly binding nyWanenb ht end of Oat Yii Yea CF NFrvi45+b:'+ No Yes Yis-WSPF Source Requires an APEN. Go to the neat question Source Is APEN-requlred/perMtesempt. Source is APENaequbed and permit exempt Continue -You have indicated the source category on the Project Summary sheet Continue -You have indicted the facility type on the Project Summary sheet. Go to the next question Storage Tank b not subject to Regulation 7, Section MI 111.4,..`"I",_IStorage Tank b not subject to Regulation 7, Section%VII.C2 Yes N0 3: R2 NAi'.,I,$_ Continue - You have Indicated the source category on the Project Summary sheet. Storage Tank Is not subject NSPS 0000 -This tank was constructed prior to or niter the applicability date. 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P� . ay M wf 433rP M.em w v e V N...wero+a.w a� 4 Nma. era..Y.+wPa.rNm.n Pm'omn.W wr.weNmPw4.a...P•.w ar4T1N.....1..Pe Pn.4 Ws..P....la.r...V Pme 1.a. •'33wpV.NP Cw P.N.r. ww•gwrnPUP.t M'twroaT.w..Mwslm. V ••pm wow., Or. T.P�arowam s•V.w.wa4...a.u�. WwwM.4Tv.•v.Ys 1ls[n33n r.t.wMw JM .3•44.4 •4.+4.3.44 ••P.3aI.4+..T..r.�-3333.. b.>..rw[..re4a.N..aPrWVw.ma..wr�. w ww• q Mw.w ••4.04....4..•••334P.eua>atea •s3..44.3. .i wy.v eP4www ...44.•••344.4 rPro WwP.[ 333.4. n'wvT.n3...w..vm Tw•N1...e.w .33+•0+4 Pen .v..Wrr r.Pw.w.W.••+arowVe...ev mnvn..w•. 3.r0•.I PPrwm phV...N.m ..wn rowPwv>tnPwm w P.....••YTPwNaarro4•••3 a4 Y. ra •••••• •••••••••••••••••••...4••••••••44................. 334+.4P.syeVTPPV...•Wp wmm a 33a4v.Pa.t.q.t.q ...pw•roe1.onwwo.q P.r..uPr.ewrM P. N..Y WP+[ Paarml R.yilvn'WI V.3303. 00.4 wM vP.mn Va.....n.ww..w...▪ .wTq NVw wr.eP. P.em..1t'ar•4 T w..•.1 No•n • .wm you awe...r.ro.[r NT•PaP.ew'tn.e.m P.mawVT.3aip0TMP3333.Pro.Mw •ePe..M 4Tv.n.mro. PP.33e..rw.Ye.VP..P [.pP..lm NwaP a rum . rv...v [•433..4 Mr. bTPw 11.000 43.11 034.0 OZOO 033.31) 03.1.30 4.390 300,3 did 0 004.0 4.0 stir 4.0 .3300 ccente 43313 4.0 0,30 WOO via 0341 33.41 wanT..Nwe.Y ... NP.mm 3..4.1 M•4.1 4•0 34.3.33444 PW4q pad 30-32 weal 41.04 434 4334..0 I. 40.0 4W.W 4W N wan e433.Nr.nl YW.gI A.miUaaul CUOITTIW3 aieli Condensate Storage Tank(s) Emissions Inventory Semen 01. Aa,lese1b.dm Infarnadon 'F.d%9 AIRS ID: County 9012 PCm ' 011 porn r5.me 102-000. 110 D.eb+pekn Deets Detailed Emissions Una Derrwkr Lf.s. (4)1000-.b,.IMod roof stabilized n.a bps racwe.Fwmn.rw.I.S Emission Control Davke Daalpt 00: Emission. are collected .10 VRU and mewled Otte plant e10l Durintvw downtime (magma of2%an.Mgr lembeor- Requested Rare VOC & HAP Control Efficiency u Receded YRU VOC R HAP Collection Meitner Tk Pranrr Emissions -Stooge Molds) 7crl Condensate TnrouNm0 • Requested TOW ThromhPot. Potential to Emit (PTE) Total Condosce Tl.o.aaA - Proems 01 Combed Proem 01 Throughput URII: VRU operation: , Rope 02 Cmm0 Rum 02 Throughput Enclsed combustor. 0 Barrels @b0 per year Acrid Coremsee Th0.e0+07 0 wmle Emissions Comma opereing • (� :� o R.rree (top Par Year "2x000 Barra (3b0 per year ,:::I;-,111,sa2,SBo! Barrels (roll per year . . X1..09.3301 Barres(bd) per year , 100% ControlCm0031y% ;;320501 Barrels (rob per Year Someday Emissions - Combustion Da.le(f) for Air Pollution Control Separator Got Healing Vale Volumed waste got endued per 001 d liquids throughput Hem content dwaste gm - W% this storage tank emit flash emissions? EPA Ta.b Remdt VOC Emt0In Rate. Totaled Vends TOW VOC mission Rae. Pollutant Benzene Toluene EUrylbmxene Mlesan -Ha. ate 2.2,4TMP 91% Control Efficiency % 1300. 0900012,939 m.3/I. 003107 Embalm Eamon (Peeve 01) Cowdawta Tank Emission Fame Scree Pollutant UlmOb0Rsd Controlled Ills/a0') (O%/btl) (Coedensse ThrmuEleM( (Cootie* Tbveeghen) VOC 0007E-01 0.000E+0D stc. 5p.dne EPA;Tues EF:W0Kby wet SooWryOnly Senates 1338E-03 0.000E+00 WM SpidficEPATANR0E.. Wasting andSnothig Only Toluene 3.701E-03 0.000E+00 91i1'jocine EPA TAMSLE:Weldon and 1000300$0003 Ehylbevur 2162E -0a 0.000E+00 Sae SpedRO EPA TAMkS E:P. Waling and 3000701ON3 RTlon. 2802E-03 0.000E+00 5ttlpsdh EPA T..103 E.F. Wakkg and bs0N0O OMI -Ikon. 1.192E-03 0.000E+00 Ste SpsdfkEPA TAtA6 e3. W.Abq.nd Rr.nrhlgddy 22. T00 5.335E-06 0.000E+00 9bS.dnc EPA TAMS EF:WMluand®iaTdER Only ...Ion P.m. Morons 02) 000d.n ea Tank Factor Source P0010220Emissive Una-Uolod Cenbeged (PASO (10/roQ (Condense. Thr.ughP-1 (Caednme 11 a4RPn) VCIC 1007E -0l 5.033003 51C SelikiPATAMS ES.WoWg and treading Only Ranene 1.335E.03 3.333E-05 SIC Sp.tlhEPATANICE.F..WaMndand *.0070 Oily Toluene 3.707E-03 1.35,E-06 1m Sp.dREPATAHRSEP: Wakbw and Biee0100O*d'f Mylbente a 1762E-06 1.3310-05 Site 3enmk EPATAH3EF. Wield/ eking Onto 0910.. 2302E-03 Lb10-06 9YSpecific EPA TMBSE.7 WdUng and SmeltigONF Mover 7.190E-03 3.599E -0a 9e'Elamite EPATA91H Ei.� Wvtl{ and gem0OMgO,dp 226100 5.335E-06 1447E-07 S,1 speak EPATMMS ES: Working and B.mdnng00l Emission f.0as (Proofs 021 Control Delos Uncontrolled Uawebb.d_ Polley. P ""-"0I (m/bOl) Eedtlln 00000 Saes (erase hen (Condenses 0.dr.sed) Throughout) PM2.5 Mb ' 0.0330 .. 0.0002 Ms20..,, 13.5 tdaebts Raw (Nos) CO : 0.3100 ,-. 0.0003 AP442 aapt. 131.9 biluithalRib(m). .,. Oatmeal Proona Paraeren: Gas Recycled 113 MMW/yr GIs Rated to Cobol. 0.02 Mescf/yr 20 of 52 RAPP.\2011\11WE16ULCPS.Mm Condensate Storage Tank(s) Emissions Inventory Section 05 •Emissions Inwntan Criteria Po1laants Potential to Ent Uncontrolled (tons/yearl ' Actual Embsbm Uncontrolled Controlled (tons/year) (tons/year( Requested Penni Lines Uncomro5ed Controlled (mns/year) (tons/year) V0C Pe010 ArQ-5 NOO CO 0266 0.00 0.00 82.66 0.0!27 0.000400 0.00EW0 0.000000 0.000400 0.00E r00 0.000440 0.000400 0.00E-00 0.0004430 0.00E-00 0.003 0.003 0.003 0.003 0003 0.013 0.013 0.013 0.013 0.013 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled ' Controlled (ron„'vnor) born/lenI Requested Perml Limbs Uncontrolled Controlled (tom/Year) liens/year) Requested PermO Links Uncontrolled - Controlled (mr/reari la/rearl 5.00.0. Toluene Etlrylberbene ketone naleat.' 224 TMP . 110 0.0000 . 0.0000 110 0.00 • 2197 2 3.04 0.0000 0.0000 3.04 0.00 6069 6 0.23 0.0000 0.0000 0.23 0.00 054 0 2.30 0.0000 0.0000 2.30 0.00 4603 3 5.91 0,0000 0.0000 5.91 0.01 11622 12 0.00 0.0000 0.0000 0.00 0.00 9 0 06 • Re .ulrtory Summary McMIs Regulation 3, Part A, B Source requires a permit Regulation 7, Section AI.C, 0, 0,7 Storage Tank b not subject to Regulation 7, Sachem ell Reguatbn 7, Section KII.G, C Storage Tank Is not subject to Regulation 7, SeNar 011.6 Regulation 7, Section 000.0, C1, C3 Storage tank Is subject to Regulation 7, Section 0VVI, B, C.1 LC3,.. proyc Regulation 7, Section IN0.C.2 Storage Tank b not subject to Regulation 7, Section %VII.C.2.b. Regulation 6, Part A, NSPS Subpart Kb Storage tank Is subject to NSPS Kb Reguatbn 6, Part A, NSPS Subpart 0000 Storage Tank Is not subject to POPS 0000 P15P5 Subpart 0000a Storage Tank b not subject to NSP5 0000a Regriatbn 6, Part E, MAR Subpart HO Storage Tank b not subject to MACT MN (See regulatory awfabUty worksheet bur detailed analyab) 210152 K:\PA\2011\11WEI40LCP5.abm Condensate Storage Tank(s) Emissions Inventory Doe Me company use the state disk emissions factors to arinse anbbts? Oyes, are the uncontrolled aural or requested emissions estimated to be greater than or equal to 80 tom VOC per year? If yes, the permit wB contain an Initial Compliance. testing requirement to deveop a site specific anbsbm factor based on redeem NPs Memo 05-0L Doe the company use a ske speak emissions factor to estimate emissions? If yes and kthere are flash aNssions, are the emissions factors based on a pressurised igid sample.. at the feciby being permtted? That seraph should be conddaed represmOlbe which generally means tkespecek and coeected within one year of the appikedon recdved data However. 0 the farms has not been modified (ey., no newwdb brought online), then It may be approp late to use an older Peepeak sample d no, the penut w0 contain an Initial Compitance testing requirement to develop a ate spedtk ernbabm factor based on pi0dlnes in PS Memo 05-0L .`H, N/A- Operator mbdasd emissions udng doe epedh EP Does the company request a control device efficiency greater tin 95% for a flare or combustion date? ' kyet, the permit wit cocain and ink. compliance tat condition to demonstrate thedat naxbn efficiency of the combu[bn decka bated on Het and oudet concenaatbn sampling Section W-Tedrnkel ANNA. Note, I. Baiedap the maces dauGlen aroeidebe the operoiNthtcpdbmi[a that resulea the In. neNiving step is routs toaaabOta lidor:o diebiAnbn to Urstorayevmeb:Thbidbaherreegre the remaidng lighter hydro[ rbom,hom the liquid to meat the dated RVP spec ON. POP 10), As ireuk. tMmndeouaea is stabilised ores b b routed tothe cwMsmate tads. ;:_> `LTM HAP emattbm'aaoclatedrith that source were nkudaiel Ming a mon. coat ahmiedfrom the AIMModn ps platoon Mirth 1.1'; 200% Orb tern.. used to at6nate tae NAPmassons from themdersa ahio emverii Under point 005 in the CP1"ad N that csuiace- Skis tley wan mead end tppraved too tee with the istrinkurate tanla covered coder. point 005 they were accepted end used in the malydsdNis pabe.' 3 Thesanrap banpeopeed tcrasa lab fe dlcy.me operalx her 61d6ated[lame rtora8nveiNswdIbe controlled bribe pl ntflan(Pointdi01muoe vall'e mthe. 0n]/3tjl01e.chb waerevised byOCP su h that NNW.. Mated to an eidosed dornbuaor duu6g VRU dowmi .... ... /.The vapour k R used or ., . h c .... dcoverym (yaw lmKLc.to0CP n21121u r8re mntrded.eeraet chit mmhabhp ankle opposed gdpmna4TM agreed imitated 98%dtM ko from this tank will to retried totheplans hilat WYRU. Piaui see email nspqueto DCPm 2(11/1018'"' btgthbd ermNatlori. .�::• , dime You at beinggranted100%oansrol ell. iheinq ptbne.This IS comctent ;Oh theassunedefranncy of the VALI for AM001.Ahe 02,ennd C -CL flat attire teore eel of VOUu coed ton 0 -CL S. TM used EPA Tads 0,0.99 to CMcolaswwrkhg and broarhi/ emeaioro and attuned defaul Properties of Gator,. IMP 10 and Ueterobguldatel Dever. CO. That ...illera toed when 1.100000 'enmbsiwv for; she other condensate storage meets at thatfadkyowaed under . point110: That sm.'.is' acceptable amain* the smrat veaek a this taaly store sttOeed;Meier gee otMemate. Sine the toedennaea not messiahed,the Oahemissions will not orar, EPATmb.09 0.d only y.ca%e kulworking ad breathing an accurate methodic, estimating emissions from this won 6, border to od ula combietbn emission.,s Operator the volume viinedl ...si te tanks using g the a la ideal IP/.tOT). Thevrireawed hithb Calculation ere aafol.: ' (p (1)653tr..; ioNn' 2000 @/toed• (1 ORmsi/E6 M1 50.10 m-,noW .. ..: .,_: rte the ie.. foe ltoo/V )la bated Ur the miramro0ed emlebiii M n.---. O.:,un sntrolled praoas 02) fill (lIP.02,02pe1 3 .: n J (a) 7.509.878 (60'?( .. ,., (b) A: 10.731'priaYM3M lbmd V•ISO.101bmoWea1910:]31'nsb tr'!3VR'I?moll'{51967AV13212pW1.l'2305L]ad/Tea . Tide voce {?!sernendeto0J0ad/ihi 7 Mordhg io'fudanmtab d Natural Gas Pnvrmhhg, Serord Edtbn' by.. y IOdnay,, P4''''''''''''.7 arthh 'bbd'...`, nd Mdarrey'(Reld Vaper.Pruvrrel cars range from curt 34 psi bd the 0ermon rmpe:69 [012 pd ehmtthe 8gdd at trucked alteC.'Ooetetlm.at,umhigGaolre RVf in; [NOW' NEPATeetb all9.deppaastobe a icuonteewlmaetatM condndanoampvttbn ( , L ,TM operator ddenohed the Mat value ceedb the combetbn dndabm Nrougp hterpolstbn_eared m the aawnsd RVP "'"-:4"i;;;,,,..'""'"'"7-' cpandngthoMadec weyht (MW) was determined to M 66 O/95md bated on: ARa2 CMple .] TaWe 7.1.2.Bvad on this mdaivW w > dghi kwasanumed ;Nab. drM N'a'oredtall httwamtha deuane IMW.5B.t220/Ibmol. Neer COMan:3,262a BtWfdlaed PemipelMw IbAbnel Heat Cmtmt.e,0W98tuhcl). Urnlrhe molecularwNgh and Mat content d Butane and:Pmt ,theoparetor Nterpolatedthr Me concerns dlhewarepato be3A77, et0/at. That het comeab Mgrs, M ahc (La.hbhaM here -heal which it more ebettiin the net MN vatic IL been Matdaedw)• Bated' norhe ahanoe d' a data. rho approach.b rrepuble, .:. 9 The pmmk�rd nor hrocde momhlr enpbabn 1006f tills source Abhough that bas start. Oh. oormalled nmissbn rate b based on backup emerol elonarb- 00 he lndkated chat theanue d "U. RU dawakre;h mnldperentWyamp aged oninnanhend-ocriot Mfaxably b!obnddwneoirMdMyhab,'ttisutlt OCP eed onymmply Mth eoannual Omk. IwO nuhealna nenthlyprorae WnI/ataal cordertarethmmghptt ,; :. duce that It.dependem d cite nga. anme of YOU d...!!!!",!..:'.7.71' horn cog M rapo0Elry nmontldy emMbn Inc since iM<omrttndemhuem ere M1ieW eminsly on VRU dewnsbhme Pa:iW%control6 :> anutned durYq VRU upUmel... . ;:" � ,. ..:. '.:.. - 1O,Thbltorapveael atWledto 0595 kb- in erderto0.umplywkhthb rgoberna.t.t eopaaor ha , .. '-: hmdbledtM coral a...elk tie controled wM'ekhm adored vent srit7:"- n and an encleed1Cmbsibrinot titre( 00 ;: _ .. e clwM Vast ayeam adsnRU:- :Based on5W116btdreach wash equipped with adored vwrr eytabo andcorRrd deelca beemplfroyn the rrpubemamsdpaagrapA((cl aof‘1,,,,,....... did(800U6b1 N resek "kin' btduh bdorma[bn penaNingt ih de'1'vrlon of 7:"- ins wevap'presura(oordN 56o.116ge1 sNu paragraph(landMt'WSch a4.!"."othat regube runntakydtM parapet '.>. ,, , .� , 0yytem ad control dank. a rguked :i3 J U. NSM MD 60333q<I.eachfiusgtdpped rtth admdvem � �� • �N 60.112h(N310 (b1131 (arks Heap tlx Ike emptfr 60A Wrhird Pnwlsbm adWldaebp and blow dot�r. 5P5vraper60 afooi r Iflarada2(.000uh. 'iiin he nsroIMAR Or� br.-�moringplan fat: xis dsraned 1N an enil0sad eanleolosb nmcomdered kBanfwpuryoras d BOP 3fa-Epuhastateddw- n ._ wnii nit'. p J �ffara epll/toopenllaaadyand not to nncbendilires ndmndmm-- (AOtr1f100019) rurrhnrtmcs. t6PS Sb requuenwmsi 6D.113btd11)II) bmipaidd dabs oaetrhar [or gdmnd cornbuntko drvke�thazhwW beaddrasad NtlwmoNtodn don Tliirrgukammlwar ramnwrivlMio OOP:•andtM tliatbn dr'1.7'""--; rvklaniueg. penoNb,g to the requlrerpentwar kehded Nihe pemtlt ; .:'� „ . ,11.Umm�w0edembsbmwaereed brp0YOGA.such, thin eorega reek b tublect Bepdabn7 Sectbn%NLL IM YOU pale ssrveatM prkpmytwmd dews sedl'adi overage hydvarban ward eflklvhe i.of 95%" per XVII.CLb.whh rte enclosed combustor being pad a. a hetkrp storapcank hod subpa to 5TEM rgobemenbNlMt.C2brkrUoewlBmrdafn and rcebOad Bquedt.• AIRS Peho e 11 hoses SCC Coda 01 1404.00342 Five) Roof Tonic Works%El emethNt 1000 AIRS Paint e hose 6 SCC Code 011 - 02 [♦.(14.%.02Posed Rdd.Tafk:.VbrMrn48nathru Lasses *Proms 016 though. wine eeibn es marked eh VW. Proms 02 b eerm8hgrt doing Val doeerume (endade a routed en Rare). Uncontrolled Eeleloe Mint hoar Control% Mot PM10 OAOOE.00 0 lb/1,000 gallons tandee% throughput PAILS OAOOf0 0 95/1-000 gallons condessa Swarm. too 0A00F00 0 95/ 1.000 gallons torrent. throughput VOC 2-396 100 lb/1,000 gallons condmst throughput CO 0.000E.00 0 95/ 1,000 prom con.. throughput Bemee 3.185E-02 100 95/1,000 pilots cond.. throughput Toluene 8826E-02 100 It /Ipoo gallons condemn throughput Ethy0etrsene 6.576E.03 100 95/ 1,000 pions condenser throughput Xylene 6.672E-02 100 Ib/1p00 p0om N.M. throughput n -Heater L714E-01 100 01/1,000 pilot condensat throcgpco 220 TMP. L270E-04 100 lb/1,000 pions condense throughput Iboshobd Emissions Pollutant Factor Control % Udb PM10 0.000E-00 0 tr/1,CCO pions condensate through. PM25 0.000E -0D 0 Os/1PC0 pions condensate Uuocgret Nth 4.177E-03 0 Oy1p00plonscondemue throughput Vas 2396 95 95/1,000 pitons condensate throughput CO 1904E-02 0 lb/1,000 gallons condensate throughput Berme 2396E-00 . 95 [M.P.p.m Toluene 3.185E-02 95 Ib/1,000 pions condensate throughput Ohylbetoene 83261-02 95 95/1,000 gallons condensate throughput Xy6pme 6976E-03 95 M/1,O0O prism condensate throughput nHeane 6.672E-02 95 C/1p00 p0as condensate throughput 224 Teo' L7141-01 95 lb/1-003 pions condensate throughput 22 of 52 CAPA(2011\11WE148LCP5adsm Condensate Tank Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and a • APIs sed Pant Requlrsmmtl ATTAINMENT • Since this facility is located In the otons non-atalnm5nt ma. oed CO ,minions ant 2 ton a1 ountlons ht this sad. are Wed as N/A 1. Am uncontrolled actual emissions from any r111ada pollutants front this individual source grata than 2 TPY (Regulation 3, Pin A, Sestlon11.D.1..)? 2. Is the construction date borvla date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Mauro 0601 Definitions 1.12 and1.14 and Section 2 for additional SWdana on Enrvllather applicability)? 3. Are total facility uncontrolled VOC omissions greater than 5 TPY, NO. Bnatar than 10 TPY or CO emissions graater than 10 TPY (Regulation 3, Pan B, Section II.0.3)? INutenough lnformatlon QQ11.-.A.11A11181LEII 1. Ars uncontrolled emissions from any criteria pollutants front this Individual source greater than 1 TPY (Regulaton 3, Pan A, Section II.D.1.a)? 2. Is the construction date (serves dne) prior to 12/30/2022 and not modified after 12/31/2002 (see PS Mme 05.01 Definitions 1.12 and1.14 and Section 2 for additional guidon on grandfather applicability)? 3. An total facility uncontrolled VOL emissions front the greater than 2 TPY, NOt greater than S TOT or CO emissions amain than 5 TRY (Regulation 9, Pan B, Section 11.0.2)? ISourca tequilas a permit Colorado Peaulatlon 7 Section %I) 1. Is this storage tank located In the 8 -hr ozone control area or any ozone non-atalnonsnt area or attainmant/malnanana area? 2. Is this storage tank bated at an oil and gas exploration and production operation', natural gas compressor station or natural gas drip nation? 3. Is this storage tank bated upstream of a natural gas processing plant? ISlantage Tank is not subjsot w Rqulatbn T, Salton 0 Section OILC.1 - General Requirements for Ab Pollution Control Equipment - Prevention of Leskaga Sadao OILC.2- Emission Estimation Prondura Satlan OILD- Emissions Control Requirements Satan RILE - Monitoring Section Sll.F- Recordke•ping and Reporting Colorado Resofstlon 7.5action uILi 1. Is this storage tank located in tut 8 -hr ozone control area or arty ozone noo. ttalnnlom aria or analrrmam/nuManana area? 2. Is this storage tank bated at a natural ;as processing plant? 3. Does this storage tank adrlbn 'Flash' (e.g. storing non-utabl lied liquids) emissions and have uncontrolled actual emissions greater than or equal to 2 tau per year VOC? 'Swap Tank is not subjera to Regulation 7, Section 011.6 Section XILG.2 - Emissions Control Requirements Secila aILC.1 - General Requkemams for A4 Pollution Control Eguiprert- Prevention of Lakaga Section OILC.2- Emission Estimation Procedures Colorado Regulation 7. Ssttlon XVI) 1. Is this tank bated at a transmission/storage 1.idhy? 2. Is this condensate storage tank' located at an 03 and gas atploritlon and production optntlon , well production facility', natural gas cornpressor station` or natural gas processing plant? 3. Is this condensate storage tank a Dad roof storage tank? 4. Ara ummntroRad actual emissions' of this storage tank equal to a greater than 6 tons par year VOC? IStaaso tank Is subjact to %oyutation 7, Callon EVIL, A C.1 8 C3, as ptovkYd baton Sectlm %VILE-Canarel Provisions for Al Pollution Control Equipment and Prnantlon of Emissions Mellon EVILC.1- Emissions Control and Monitoring Provisions Section EVILC.5 - Rernrdknplog Requirement, S. Don the condemn, storage tank contain only 'stabilizer Moulds? 'Stara. Tank is not subject to Regulation 7, 5action XVIl.C.2.b. Section MVII.C.2 - Capture and Monitoring for Storage Tanks fitted with At Pollution Control Equlpmant s0 Cr9. Port 60. Suboart Kb. Sandsrds of Performance for Wine Orank Ilouid Saran Vase's 1. Is the individual storage vessel apadty greater than or equal to 75 cubic mates (m) ('472 BBLt)? 2. Don the storage vessel meet the following exemption In 60.111b(d)(4)? a. Don the vessel has a design opacity less than or equal to 1,589974 m' 1-10,003 BBL) used fa p,raleum or condensate stored, proraaed, or treated prior to custody transitr' as defined in 60.111b? 3. Was this condensate storage tank constructed, raconstruned, or modified (see definitions 4060. 60.2) after My 23,1984? 4. Don the tank matt the definition of 'storage vessel'' in 60.111b7 5. Does the stooge vessel store , oolatlt organic liquid (VOLT' as defined in 00.111k? 6. Does the storage vessel men any one of tha following additional esamptiom: a. Is the storage vessel a pressuce vessel designed to op,rata in pass of 204.9 kPa ('29.7 psi( and without emissions to the atmosphere (60.110b(d)(2""?; or b. The design capacity is greater than or equal to 151 m' ("950001." and stores a liquid with a maximum true vapor pressure' lace than 33 kPa (60.110blb))?. or n. The design opacity is greater than or equal to 75 M' (-472 BBL" but ion than 151 m ('950 XBl) and stores a liquid with a maximum true vapor pressure Ion than 15.0 kPa(60.110b(b))? I5taaa tank Is subject rn PJSPS Mb Subpart A. Gmenl Provisions 460.1126 - Emissions Control Standards for VOC 460.11lb - Testing and Procedures 460.115b - Reporting and Mrordkeedng Requirements 560.116b - Monitoring of Operations NA'; x.... Yes N Ne":a^3..._. Yek _4< No's3iw.',.',.i.: Source Requires an APEN. Go to the next question Go to nett quastion Source Requires a permit Go to tut next question Storage Tank is not subject to Regulation 7, Sertbn 3II Storage Tank Is nor subject to Regulation 7, Satan RII Go to the nee question Go to the net question Storage Tank is not subject to Regulnbn 7, Section 0II.6 Go to nen question Go to tut cwt question Go to the nest mention Source is subjon to parts of Rogulnbn 7, Sections 0VII.BLC. Go to the naxt question Yie(W.a`IStorage Tank 4 no subject to Regulation 7, Section EVII.C.2 Yei? N ✓'=: Go to the nen question Go to the en question Go to the en question Go to the flat question Go to the neat question Souse is subject to NIPS Kb Nit';°`ati) 0.507632 40 CFR. Part 60 Subvert 0000. Standards of hrfirmann for Crude Oil and Natural Gas Production. Transmission and ohtrktitlgi 1. Was this condensate stooge vessel constructed, reconstructed, or modifhd (sae definitions 40 CFR, 60.2) after August 23, 2011 and on or bear. September 1!, 20157 2. Dos this condemns storage vassal neat tha daMition of "storage vessel"' per 6054307 3, Is this mndenate atom{. van..) looted ate fac3by A. doom. og and natural ges produrlbn u6mant, natural gas prounlo angora or natural gas transmission and storage aalmam a1 the Irdtatry7 4. Ara potential VOC .Msatanst horn the Indiodual storage venal greats than or equal to 6 tons par year? 5. Is the tong. vessel sub ea to and controlled in accordance with requirement for won a vessab In 40 CH1 Part 60 Subpart Kb or.0 GR Part 63 Subpart HH7 'Storage Tank is not subject to NSPS 0000 Subpart A, Gametal Provisions per 460.5425 Table 3 460.5395 - Emissions Control Standards for VOC 460.5413 -Testing and Procedures 660.5395(3) - Notification, Reporting and Recordkeepin9 Requirements 650.5416(c) • Cater and Cloud vent System Monitoring Requirements 660.5417 - Control Davis. Monboring Requirements (Na.: No atocaga vessel is previously detamdned to be subjrt to POPS 0000 do to rnb.loes .0ow 9 tors pr Scar VOC on tin epbbiky detwminsbn dab, N shoed rehab subirs m POPS 0000 per 40.33434.l(2( even if potan.al VOL embalms drag Misr I tons per year) 40 CFR. Part 60. Subpart 0000a Standards of Performance its Guth Oland Natural Got 1.0013., for widish Construct.. MPdlflrten.w ReronatrsOinn Commenced AfM Soto*. 10 2013 1. Was this co dosata storage vestal rnniruad. reconstructed, or modllhd (so definitions 40 GR, 60.2) ahr Saptwnbsr 11 21157 2. Does this condensate storage vestal mod the dMnitlon of 'storage vents' per 605430.7 3. Is this condemn. storage vessel looted at a faorky In the, crud. oil and natural gas production tagnwnt, natural.. Processing earn. or natural i ..mission and stooge sot non ol tim Industry? 4. An potential VOC missions' from the Individual storage venal greater than or aqua? to 6 tau per vas? 5. Is the Worag. asset sub(.o to and controlled in accordance with requirements for storm. vestals In 40 CalPart 60 Subpar Kb or 40OR Part 63 Sub art NH? IStorag4 Tank iv not subjrt to LISPS 000Oa 40 CFR. Part 63. subvert MAR His. 01 and Gas Production hg I. Is the tank located at a facility thst b major' for NAPs7 2. Is the storage tank located n an 01 and natural gas production facility that mots eahsr of the folboing nharia: a. A ladtty that mousses, upgrades or tors lnydroorbon Ikluldat 163.7Wa1(211: OR b. A facility that amasses, upgrades or stow natural gas prior to the point at what moral gas rsen tin natural gas nansntdon and storage souroe =gory orb delivered to a Ilnal and user. (S3.760(a)(3117 3. Dos the tank mat the definition of'storage vessel'' In 63.7617 4. Does the tank met the definition of 'Otago vassal with the potential for flash emission'. par 63.7617 5. Is the tank subj.R to control raquinments undo 40 GR Part 60, Subpart Kb or Subpart 00007 'Moron Tank h not subjrt to MACT NH Subpart A. General problons par 663.764 (a) Tobin 2 663.766 - Emissions Control Standards 663.773. Monitoring 141774 - Rewdkaaping 161775 • Reporting RACT Ravhw RACT review is required N bpdatbn 7 does put apply AND N the tank Is In du notrasWutrnt arc. N the tank no. bin nlbrb, don review RACT naqubwma 3.. 0lsclalma This dominant assists opinion wlh datermnip app0cabity of certain redeemed* of the Clean Ai' Ad, 4. incarnating r.pi4RIMF. and Ai Qualify Control Commission notations. This downed is not a rJ* Of reptilian, and the wysis 1 certain may not apply to a perlcisar abortion Mad won the Maldu f fads and ricunstance.. This dammed does not change or ululate for any law, repletion, or any other isgay binding requirement and is not isgay enforceable. n (he evert of any 004ed between the language of this ducunald and the language of the Chen Air Ad.. 1s inpbnardip reptilians. and Al Qualy Control Commission regulation, the language d dr statute or regulation tv>/coned Tha use of non -mandatory language us)] as 'rammed." 'may. 'shodd,' end 'can,' is interred! to deacr6* APCO Narpaa(ioru and recommendations. Mandatory terminology SW, as 'must' and 'rogiied-aro Mended to describe cortrn6p ragiierrlrts seder the lams of the Chan Air Ad and Al Qiwkfy Control Commission repulstbn, bl this downed does rid *Wabash ,Agar birSij ragiirnr0s in and of IOM. Tar;::'. NA On', Storage Tank b not subject NSPS 0000 -This tank was constructed prior to or ghat tin spp0obllity dates. Go to the neat auction Go to it.. not question Go to the neat motion Storage Tank b not subject HOPS 0000a. Go to the nest question Tha facility Is not an affected tours. under MAR OH Go to the resat question Storage Tank Is not subject MAR NH - MAR Hit due not apply to storage ...stab without 'fish' omissions Storms Tank Is not subject MAR NH Fugitive Emissions Inventory Sao: m rwY.�awYm.o.se rases.: Iw:+.Tw[.:ir :[i.emsw WoorwowoM e.�Msw w.err[.r:LsM mr.rresw.ee. O....1 erow Ilmoto Rao So: MOW �....+[.. ee`• srlo...nu WNW: WI wow Mort000l r+ r he. MM MM MM MM IJOM n. MM - 12.00 MEOll 0.014 • WS. OM 0.00,40 002. 4wBW l.�Woo C000los M. ow.irlYe Moo MiolYwro Comorro riewo Mwur LIOM CA: 1-10I. LOOM 1_▪ 10.0 SALM irOM L.04 LOOM 6014 - 1.0.0 614 ▪ UCM Own roome Molromo Moon MIMI ...170111 11,11.171.11 .231>140,1 4.17102 0.40.11.0 114 It iv+ Joao ae War: ni 11.1 raM M Orr 17 711O1 :Owl Leo .12:45114.411 WA 1,1 w.1..m411 Sorini fr. F:45.-115011 rola 2-1, 0:2,1•16 00011773 0.14.47-0 Untirel. 6.411.11N 1.0.371 Fugitive Emissions Inventory Malta s, rrrirar.r.a rr... ..wc... r...4r �u4...a= w.. r....r wrads%/rlt...aw...rr.Y.. wrw...a�m4...•....•• • ....... . isrnr..rw..LM..rr..uu .`ra.�r.4.rr...». ten* .w.. .a....r.r,...r.l rwww r 'yaw . e...`r ... m RIM rrr+i..er. PM.. ramsr�wr.. owaltdmmal me. The dee r...+...r.r.....4a.r......Y....mil.M. ....+r rrw.w r.w am. MY alma. Ye mow humlame• Nowa midi, OMNI DM* Me .w.names r wr..= L Ty ...min ..a ...P..rr. Ms rm. a wr w.wa.....«maw ..r.=mewl wY.lap. ......_...ro., ......33.3 st .: r.w..owe. Y..... mawa mown. omega. 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'w. }..r ......Y m.4ra1....^1r..+/�Yww.i.saYa.rm¢aomurs....Y WA'a.r.....a4 4.w.rm.wa]" ' !" .wws.'''F.ro..4wi.Yrw Ww..iSlswt.4'W. �aT, 77YwM.A ::' r. r.rNYy . a.4......1r,;;;;:::.;6.—...—.......Pa.. aa atr .ii� W a o to .w a.nw Y .atl rw PaY '� H...i w aaww�a. 77 'rma Y.rp. w.maYw P aYwv ri,. ...a. .+..u...+ .W !!.se.rsr a.I, ''" ,,.j..............7........' r.rwwr....waw.r.oa.o.w.. wsr�rarrr a..4..a4. a.: wa oom...Yra.. .d. r.4aage.r VS CNN. rraW..a. awr..... =Mime. w Ww0.•0.•mlM..rawM r w awn.* fn. 312•6•411.,•174.443/1.45.07rolle ew.a. .a.a... ...a.m. Lobed at •...waom.rawu mom. araa.a ...rot 4. f....0...mmMaia>ra4l+ Turbine Emissions Inventory S.ctlan 01- Mo* 4trt•1M Information 'AWOty AIR. ID: County Plant Point Secnon 02- Eaubment Dncrlotbn Detail Derailed Emissions Unit 0tw'(5 S0Iaf, T•vw 70 s303378.3.ffitateandadethart twist! 1570 K T3OL rated 66.16 Mm MS ( WV)/hr,Mat irput and. °mclptb¢ Fnddon Control Devitt No uaono TrAM.an golpp.d rM Sel4NDa tad*eery wAJtA re IN.r m the gwadon of m..PdRnro Description: m eotwmWrddi oaaxd dnM. ::[::: Requested Overall VOC 6 HAP Control ENldency 75: 3ec0on 03- ProcessIne Rah hdnrm.tbn ter Emh.Im Eadmstyl Heat Input Rae DPW). Heat oantem o/ fuel gas (HHV) • Actual Hours d Operation • Requested Hours of Operation • Actual hest 0.0,4 rate • Requested hest input rate • Potential to Emit (P7E) Mat Input fate • Actual Fuel Consumption • Requested Fuel Consumption • Potential to Emit (P7E) Fuel Carernpdon • New Sours - not yes petalled 0.00 MM0TU par year 639,637.66 MMOTU per year 639,637.66 MAIM MU per year 0.00 MMsd/y.ar 609.16 MAhd/year 609.16 MMtdMar Emission Fritters Tublue Farm. Source PPollutantEEmission., Uncontrolled WsentrNYd' (m/MMotu) )6/MMscf) (Fuel Input) (Rd Cra.untp n) VOC :.2.1M-03 . 2.205 AP42CMptar:3T1hie32-26 - tt P3110 -'. 315E-0! " 1143 MbaE Smei " '®"; '• Ataeo6aesea.r�- "1'E+ �" PM25 :=.315E -0k...;': 6.103 500 .. 3.10E-03 3570 Ai2Osspml3Tale 31 ISM .337E-02 41.702 MMNAritmnree;, Q CO 531E-02 57.906 INamdadoitr"j ,ees '( m o..pnar,3 7aw.>s3f� AYRthipte 37abb313^ rormdh a.p. oE �a3�a z46E.a m Acetaldehyde ..7100E-05 4.20E-02 Aaeldn ' ;'.1405-06 372E-03 AP.42Oaytar,31.0le iUS inns.. .120E -0S ' ' 1.26E-02 AM142 Chapter 315114e 31-6 1,3Arbdirne -130E-0J ' 152E-04 APi2 Chapter 3T.be 319 Ett.90.sena .' 320E -0S 336E-02 AP42ClapPtii 3 Table 323 Telmer.. =i1.30Ep 131E-01 AP -+F, Owiti r Stable PAX ,7,.?',2.201.06: - 231E-03 AP•4O*ptar !Table l2. %yens ?.6.04-05 :.. 172E-01 AP•42 fLaplai3Tahlel23 tiectbn 05 • Emissions Im+ntry Criteria Pollutants Potential to Emit Uncontrolled Itom/n.o) Actual Emissions Uncontrolled Controlled (.../Y•wl I...M.1 Requested Permit limits Uncontrolled Controlled Rattles,) (toro/year) 114* 317.10 317.10 114.71 2157.60 2330.66 VOC PM10 PM25 SOt . Nits 03 0.67 0.00 0.00 0.67 0.67 167 0.00 0.00 167 167 157 0.00 0.00 137 1.67 109 0.00 0.00 109 105 12.70 0.m 0.00 _ 12.70 12.70 17.61 0.00 0.00 17.61 17.61 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (Im,Mar) (tons/year) Requested Permit Limits Uncontrolled Controlled ItaroMar) (tom/year) Requested Permit Limb Uncontrolled Controlled Iba/ye4r) 11./y..1 EsmuNMyM 27715.01 0.0008000 0.0005400 2771,01 2171531 0561 454.1 Acetaldehyde L279E-02 0.0001403 0.000E+00 1279E-02 1.279E-02 25.6 25.6 Awed. 2047E-03 0.0001400. 0.000E+00 2047E-03 2047E-03 4.1 4.1 Omen* 3336E-03 0.003(103 0.003(100 3631E-03 3636E-03 7.7 7.7 1,3100040 ne 1375E-04 6000E+00 0.0000.00 137SE-04 L3751-00 0.3 0.3 Emy1enlem 1023E-02 0.000E+03 0.0035400 1023E-02 "10231-02 20.5 20.5 Tolerate 1156E-02 0.000E+00 0.0005400 6133E-02 6153E-02 33.2 61.2 PAH 7.036E-04 0.0001400 0.0004400 7.036E-04 7.036E-04 14 14 Xylem 2047E-02 0.000E+00 0.000E+00 2.0475-02 1.047E-02 40.9 409 27 0152 K:\PA\2011\11WE1431.1P5.ahm Turbine Emissions Inventory 1g80tb01 Section ILA1 - Esapt as Madded In para0nphs 2 thrash 6 Meow. no owner or operator of a sour. she allow or cause the emission into the atmosphere of arty au pollutant which Is in excess of 2O% opMty. This standard b based on 24 consecutive opacity amen. taken at 15 - second Imrvab for se minutes. TM approved Mew.. the method for Mies stn.l.e measunmra A EPA Mend 5 (4068. Part 60, keener A (MN, 19920 in all subsections a# Section IL A and B of this mutation. Section ILA. No wner or operator tie sue or permit to b• em02ed into the atmosphere from any fuel -blaring equipment, penkdat. nutter M the Mu Oases which seals the following 01A11 For And burdp equipment with designedMat inpus greater than L10' BTU per hour, but less than or equal to S*0l0s 010 per hour, the following equation wA be used. d.trM, the allowable particulate .mbbn Menton. PE.0.5(5)v When: PE . Particulate Emission in Pounds per MOM. BTU Mat Inert. Fl . Fuel Inmate Million BTU per hour. TM erbium come under tbb emission pains has M design boat input raft of 73.0 MMOo/Ir. M a rwl[, the eubMw an sub». to fish preen .1180 r.pdsden. [sing the Myra queues. the .I 1. parta ls» er»Ysbn OMatb. 6 O.114lb/MIAOs. The AP -42 rnbaim factor of 0.8,10' 8/81810.. mid be the talod.dens above b helm this p.nkusm .mien threshold Salim VLO.4. New sources of sulfur diced& shell not crewmen to in errsttd sulfur dim.. In cues of the following pretmtpedlk IMiatlos (Heat Input ma she be the manufacture. guaranteed madman host input raa) VLR.4sg). Cmhbadg Turbines with a M. input of lass Man 250 m00en BTU pr hour. OA pad. of sew Amide pr nee » BTU of bin input The turbines owed under this .Hobo poles h.. deign Mat bout re» of 73 MMOtu/bt he. relit 0.mrbbla 4.084,06 m Me portion of the matador,. 'Me AP -42 ender» faceted 34.0' Ib/MMO8 used b tier wkubdo s .80.08860,46.800686. emission tiwddd ge.dedon 2 Section LA - No prsr, wherever bat 4, shag cause or sew the ern*olon of odorous air contaminants from any single source such as to mush In detectable odors which are measured in saws of the following Ikni0: For apes used predominantly for resew.. r ocmwdal purposes it is a violation if odors an deemed after the odorous aft Ms been 610med with amen (7) r move volumes of odor h.. air. Regulation 3 Part A-APEN Bqubernerss Criteria Pdhter.s: For uteri. plluterrs, Alt Pollutant EmMeon Notices an mere for. ..du Individual emission polnt in a hnn-attal.rmd area with uncontrolled actual meteor. of enb form per year or mom dam individual eetnd. pdbrt+nt (Pollute. ere not su.n.d) for which the area b nun -attainment 0pp0ont 8 required m Ole an APEN Mao emissions es.ed 1 tan pr year N0a. Pen 0 -Construction Porn* Exemption. Poet.. b required to obtain M pone since uncontrolled NO. rdssbns from this faceby an peer thee the 20 TPf dor.a»M (Ben. 3. Part B, Section 11.O.1.) Ra,6.04. 6 Peet ■ ration 16 Standards of ►erf..ftan» for New Reel Our.. Equipment MG Standard far Prdpbb lamer. On and after the dab 00 winch the required perforrnaram the is oonplead na mm. a 0Mratw .0bpa to the prwWws of this radatlan may Madeline. or ouzo the decha m. Into the atmosphere of any particulate matter which is: ILG2 For het batrg gdpment geneatlng gamer than one million but las than 250 melon Btu per hour mid input the fallowing equation will be used to determine the albwa1e particulate emission 0mitation: PE.05(FI)A26 Where: PE Is the allowable particulate emission be pounds per .00len Btu heat Input 0 b the fuel input In million 6tu par hour. If two or man units comma to arty opening, the marl.mm eleowable mission rue shall be the sum of the individual emission rata O.G3. Greater than 20 pent. wader. 1 OD Standard M hew Moab.: On and afro the dab on which the requite prbmanee test b come... m ...or operator MP. m to powers of deb »deep may Archers; or cause Me discharge Into the atmosphere sulfur dlmdd. M excess of: OO.3... SCUMS with a Mat Inpma of less than 750 region Stu per hour: OJ Oa SO2/um.. Btu TM turbines d under the he a deatgr Mat input rated 73 MMO0/hr and was wamhoted dm 01/30/70. As M markthe oo.en pole anew is wheel to this portion of 1M repletion NSPS Oct TM p.a840. of this subpart an applicable to the following affected fded.: M statlgary gas turbines with a Mar Inpt at peak bad equal to or greater Men 00.7 Maim.. (10 million 00) per has, based 00 the loner Meting valued.. fuel fired 'Me M. Yen at me be for .mt. of dMem minas Y 60.4 MMidhr (1Nel wbkh bar..., then 001000089.. Y. rmde... »Mims would he a8A4.n to Mb 06R; Assam., the nuke. a she tub4att to NSR IOOM (roe pp4k0820y dbsssala. Wood. Aesdbr 1609 gat. 104039) S900.ry .ambmdm rrye »gab». meet the weave w ante from the ng8rmerhb of to subpart GO althis part Heat money sigma generators and duct bunion regulated under this subpart aw ere pted tress 6m p. 0ernwhb at mavens D&,O8, and Dc of this pen. As. met 06PS GG ds not ppy MPS MCIO1 If you an the owner or operator of...wary cornbEbn turbine wt. a Met input at Pak load equal to or greeter than 10.7 Olplaubs (10 MM0O) per hour, based on the higher heating valued the fuel, which commenced motroctbn, modl0atlat or ncomsbuarn air February 13. 2005, your turbine b sub.. to this subpart • Each of these turbines ism. Me Input at pd bed of 73 MMdm/Ir (010660 0/MI.06 we wtrhmmw wmp.nre ever Femme 1; 2005. 4. . omit, MPS I00U( apples to ads of those turbine...11w app obis rqukw.ris haw been bduded in M p...*. A...d.07 Section MILD. Combustion Frees Adjustment 09LD1 Red ]wiry 1, 2017, Mb S.cdan MILD. applies to the following gmbs0bn equipment ed. uncontrolled .01.84 0.0ol.. of NO. equal mrerseer than gem (S)tons per ymt pd that are Weed at.4Nrg major mums of NO; as Ord in Section MLA M6Lo1d satbnry combustion ❑shine Tlh facility is not a oft), ear. of Nita ere theddws the turbine .armed under MY peeht b out sub4s. to eh MA Regulation ■ • MILL h TM: Tau w sub40n to tine subpart M you emu or operate • stationary comauebse 0060000800000000 maj , source of NAP onybn; Once Mb b a major sauced HAP rd Is thereon select to ti. mWprt. This turbine Y'mw' pr 636MG(0K2) sham It w6 artrnab 0nseunbn aft 1/14/03 Per the... of standards for Reeked gb.t.sw50 43.f03544)'Isar start up s 1000 wtwmwsmtdstationary methadon eating that is a Yon premb gamfaed s0dahory coneethlon cubic& r Medan jk.n• pm-itad stationary ombetien turbine as left: by deb o0p.t Menthe, 0on*M with mi. bttiM No0jk.6en ng8rmu»b *forth M (01145 but need not rwmdl ddh any other requirement of the subpart Ina EPA tees feel octp to »quire crathelsoce and p itch a data,.in the Faked Rap6br.' yam prank ear —fired stationary ombadan tartar' 8 djesd in 636175 or 'Each sartium7 mmbedoh Onbkr at* if b gdppd only mitre pas mkv bmmoms. d0**8gy—'- Aathw0A Man arms bobmr0P Is defilade. 're '00.4190090040010480.87 the for/ are aware* inked thyme a ban rather jar 000804.. incsaa.bster. Mfchq stay orninudan 008Yla wham me ad ova began w In M. maaabaat40. d.wr.' Sins them Writhes or• dangledm Wes Pases aamjaedstatomy combustion habins(w nab 00), Heyearl only sowlp worth 04 reporting madmen,. Inn.. until such tram that the cry b Q10d As pblchbs in dr Fskrd Register. 23 of 02 Turbine Emissions Inventory Medan O7 - Technkal Anoints Nobs L Th manta Wa momio aneet pmuldtl for MR source Indicated Mafwl lb 3:13m 6636 MM6tu/30 Imwouer, tM opx.atorsoad tM NM. flow by a /atSorol3l 0r. wlculrtbm and p4mlRtfn� porposu. Tubb du to tint fi0turt emMlonrat p Id.d n diet urblp0�ma ufaatuzer pW0otbn .160'.• bud nalaw Aeitbl'raiuO o/notuzel.0u (LNV). TMzelen-isacme4rvat1. m0ux0 forpemnldxMl' purlsoau, OCP mmw[s tM LAS h inpu rota of 6646 660:160100,0460r:',600'04 "01u INI04T Anna 6 to tM 616, hoUry value, IM 111V ratln0I rnuhipliad by 11 3np0fltl mrn4blcn how 1MV t MINI. Thb In. hodolop rerM3l a mnsat60tM estimrte of fool tomwnpdon and mtubre vaulting from.. ioonm. Asa nowt, thb b ampgba far qrm 5065 s.'rr.AOsuchs1na rotel . .0 tomaadto73.OMMem/.. ....;tM� lubnfactpii(x NCa a.. . (procldtl byth0_ ntu. ... 3ola o/ Ib/Iv)ww0 tlto unka o/ps/MMBtuWnl' [M mmatlh otl pot rate (1.0.73.0 MMBlu/h) .. : .� �.. 2. T34101 lor66 spcilkadan sh0x nappta issl Marmatbn for bumtl hydmorbon0. M 4wr,tM spec den KA d1(a Kate bur« VOC ar :. ,_. , . ... .. _. am4abnfacb hom0P-42w40ba.mepttlfw to Mbhata emiub • 9.Upon ip'wx,OCP16 d.dth Watsurxbmtll d Ofbitlit lSo&oNOaadmobey.tM 00btM d.HKd ofa'aan.P hl'u-flzedmtbnarymmbnm( turbb0 comalntlin §69.6173'; Th bronitun atatu'Sd o1lOi nrtll N rvp�:mhtl battles zech 11 (51O w. estrmiaN If rm slr/fwl MIMUm a060Wryxnl9 mmrol06 00166.6or " ,Prow A0-wch n dxxmlMd,? 16.1thbtur3lna mae[itMMDNtlon ola.•ain,P am3iWlind atWonary cpm3uta tutbina'loytls4.purpofes'�df MAR, rem', l Mmai communicated to DSO 9/12/17:thOt th r4a etted'emisdaK 6scraaaa ofPM25 audd ttl wIt3 thh madlflotbn eacwd mob6n thresholds.' N rxdtDCpmmnwnkattl thot man/adwn0r" tut data I dbatx' lower PM 2S Mi0Kth.nthO default APd7 amiubn1Mun Ahhoul'htA PM23 61101,Ozebrnt (01 11tNd bytM manho06unr, DCP trvm Mx Rnn"adiaw wmdax�wlN'"5 iM bwx VM250mlbbnfao Asa r.0ok em611001dor bdud.d !litho a lysis abawitbued rio4Mirtinted ma0u(aa dm. It 010'actuadeft* 9.606.10116 INadei n9WremaM to. mnduaaata0M taac to 6.00,stnt per. wlth tM GM23 vnlxio. rote: ." .-:' .. S. On 1/26/16 DCP bmfted:a Mutual mpilu0 IndudN6in.MEN Ex thI'pdn WIth thI timntal, DCP 3 rommettne In tM PM23.0mallon amtor aid'ensbsbn Once th6 w10 ba totec and Mucad PM leas b the hot (ba54d xl tw1amir0r gAarant44 p oldtl wrth 1/2016?pp) haw 3040 proposed, DCP . - _., ....., SOatan 10- Memnon SCC Codba and Emission, Rectum AIRS Puha 013 Precool' SCC Cab 01 Uncontrolled EnnWiem Pollutant Each Control% Unto PM10 5.85E-03 b/MMBta Input PM2.5 5.65E-03 b/MMetu Input NO 3.97E 6/MM6tu Input VOC 210E-03 b/MMBtu Input CO 5.51E-02 b/MMBtu Input 101 3.60E-03 b/MMSN Input Formaldehyde 7.10E-04 6/MMBtu Input Acotaldahyda 6.00E$ b/MMMu Input AwhNn 6.40E-06 6/MMBm Input Benzene 120EQf b/MMBb Input 1,3-Bubdlene 4.30E-0! b/MMBtulnput 61306m:en. 3.211E-05 3/MM6du Input Toluene 130E -0a b/MMBtu Input 220E-06 b/MM6tu Inert Edlene 6.40E-05 b/MMBtu Input •Emlobu for MM. 12,-130 nmm 04.6.0[441Mmgh tM Mme 1.+01614. A•4164, d6tr spre4AMx Pro rldu an analysis for aad mrbin0 u eMubo an identical horn ud. Turbine Emissions Inventory Section 01- Administrative Information Facility AIRS ID: County Plant Point 901.2," 5ectlon 02- Eauloment Desolation Details. Detailed Emissions Unit 'One (1) Solar Taurus 70; natural gas fired combustion turbine (SN: TOO) rated at 6638 MMBtu (1HV)/hr heat Input Description: is�nd 9,071horsepower (HP).. .. :, Emission Control Device tNo control: Turbines are:equlpped With SotaNOxiechnology Which are Inherent tcf the operation of the. equipment 1 Description: Land are not considered a control device. - _ - - Requested Overall VOC & HAP Control Efficiency 96: 0 Section 03 - Processing Rate Information for EmIssions Estlmatel Heat Input Rate (HHV) _ Heat content of fuel gas (HHV)= Actual Hours of Operation = Requested Hours of Operation = Actual heat input rate = Requested heat input rate = Potential to Emit (PIE) heat input rate = Actual Fuel Consumption = Requested Fuel Consumption = Potential to Emit (PIE) Fuel Commotion = Section 04- Emissions Factors & Metodoloeie4 73.01 MMBtu/hr 1050 Btu/sd hrs/year hrs/year New Source - not yet installed 0.00 MMBTU per year 639,637.68 MMBTU per year 639,637.68 MMBTU per year 0.00 MMscf/year 609.18 MMscf/year 609.1.8 MMscf/year Emission Factors Turbine Emission Factor Source Pollutant Uncontrolled Uncontrolled (lb/MMBtu) (Ib/MMscf) (Fuel Input) (Fuel Consumption) VOC : 2.10E-03 - 2.205 - AP -42 Chapter 3 Table3.1-2a € ` ManufacturerK Manufacturer yx a Ya" xfi m `� �... .ar. PM10 .-5.85E-03 6.143 PM2.5 5.85E-03 6.143 SOx 3.40E-03 3.570 AP Chapter 3 Table 3 1-2axv NOx : 3.97E-02 41.702 Manufacturer - CO 5.53E-02 ≥. 57.808 Manufacture 7 , AP-0Ch 2apter3Table 3:1-3 Formaldehyde 7.10E -0l' - 7.46E-01 Acetaldehyde '.=: 4.00E-05- 4.20E-02 AP -42 Chapter 3 Tabie3.i3 AP -42 Chapter 3Table 3:1-3 AP -42 Chapter 3 Table 3.1-3 3 T AP -42 Chapterable, 3.1-3 t Acrolein 6.40E -00.:.!;].g 6.72E-03 Benzene '=1.20E-05 _ L26E-02 1,3 -Butadiene _:.:.4.300-07 .: 4.52E-04 Ethylbenne ze :3:20E-05 ' 3.36E-02 _ ss. Ch AP -42 apter&Table 3:1-3 Toluene 1:300-04 1.37E-01 AP -4I Chapter 3 Table 31,3 AP-42•Chapter3 Table 3.1-3 ar AP¢42 ] app 3,Table-: 3.1-3 PAM 2.20E-06 2.31E-03 Xylene .; , 6.40E-05 >.... 6.72E-02 5ectIon 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC PMSO P M 2.5 SOx NOx CO 0.67 0.00 0.00 0.67 0.67 1.87 0.00 0.00 1.87 1.87 1.87 0.00 0.00 1.87 1.87 1.09 0.00 0.00 1.09 1.09 12.70 0.00 0.00 12.70 12.70 17.61 0.00 0.00 17.61 17.61 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Units Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (Ru/year) (ibs/yearl Formaldehyde 2.271E-01 0.000E+00 0.000E+00 2.271E-01 2.271E-01 454.1 454.1 Acetaldehyde 1.279E-02 0.000E+00 0.000E+00 1.279E-02 1.279E-02 25.6 25.6 Acrolein 2.047E-03 0.000E+00 0.000E+00 2.047E-03 2.047E-03 4.1 4.1 Benzene 3.838E-03 0.000E+00 0.000E+00 3.838E-03 3.838E-03 7.7 7.7 1,3-Butadlene 1.375E-04 0.000E+00 0.000E+00 1.375E-04 L375E-04 0.3 0.3 Ethylbenzene L023E-02 0.000E+00 0.000E+00 1.023E-02 L023E-02 20.5 20.5 Toluene 4.158E-02 0.000E+00 0.000E+00 4.158E-02 4.158E-02 83.2 83.2 PAH 7.036E-04 0.000E+00 0.000E+00 7.036E-04 7.036E-04 1.4 1.4 Xylene 2047E-02 0.000E+00 0.000E+00 2.047E-02 2047E-02 40.9 40.9 30 of 52 K:\PM2011\11WE1481.CP5.alsm Turbine Emissions Inventory )eRion ub - Regulatory summary Analysis Regulation 1 Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission Into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section IIIA. 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: III.A.1.b. For fuel burning equipment with designed heat inputs greater than 1x10' BTU per hour, but less than or equal to 500x10' BTU per hour, the following equation will be used to determine the allowable particulate emission limitation. PE=0.5(FI)'ex' Where: PE = Particulate Emission in Pounds per million BTU heat input Fl = Fuel Input in Million BTU per hour. The turbines covered under this emission point has a design heat input rate of 73.0 MMBtu/hr. Asa result, the turbines are subject to this portion of the regulation. Using the above equation, the allowable particulate emission limitation is 0.1641b/MMBtu. The AP -42 emission factor of 6.6010' lb/MMBtu used in the calculations above is below this particulate emission threshold. Section VI.8.4. New sources of sulfur dioxide shall not emit or cause to be emitted sulfur dioxide In excess of the following process -specific limitations (Heat input rates shall be the manufacturer's guaranteed maximum heat input rates.) VI.8.4.c.(i). Combustion Turbines with a heat input of less than 250 million BTU per hour: 0.8 pounds of sulfur dioxide per million BTU of heat input The turbines covered under this emission point has a design heat input rate of 73 MMBtu/hr. As a result, the turbine is subject to this portion of the regulation. The AP -42 emission factor of 3.4x10' lb/MMBtu used in the calculations above is below this sulfur dioxide emission threshold. 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. Regulation 3 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. Applicant Is required to file an APEN since emissions exceed 1 ton per year NOx. Part B — Construction Permit Exemptions Applicant Is required to obtain a permit since uncontrolled NOx emissions from this facility are greater than the 2.0 TPY threshold (Reg. 3, Part 8, Section II.D.2.a) Regulation 6 Part B Section II: Standards of Performance for New Fuel Burning Equipment: AC Standard for Particulate Matter: On and after the date on which the required performance test is completed, no owner or operator subject to the provisions of this regulation may discharge, or cause the discharge into the atmosphere of any particulate matter which is: II.C2. For fuel burning equipment generating greater than one million but less than 250 million Btu per hour heat input, the following equation will be used to determine the allowable particulate emission limitation: PEv.5(FI)-0.26 - Where: PE Is the allowable particulate emission in pounds per million Btu heat input Fl is the fuel input in million Btu per hour. If two or more units connect to any opening, the maximum allowable emission rate shall be the sum of the individual emission rates. II.C3. Greater than 20 percent opacity. II.D Standard for Sulfur Dioxide: On and after the date on which the required performance test is completed, no owner or operator subject to the provisions of this regulation may discharge, or cause the discharge into the atmosphere sulfur dioxide in excess of: II.D.3.a. Sources with a heat input of less than'250 million Btu per hour: 0.8 lbs. SO2/million Btu ' The turbines covered under this point has a design heat input rate of 73 MMBtu/hr and was constructed after 01/30/79. As a result, the turbine Is subject to this portion of the regulation. NSPS GO: The provisions of this subpart are applicable to the following affected facilities: All stationary gas turbines with a heat Input at peak load equal to or greater than 10.7 glgajoules (10 million Btu) per hour, based on the lower heating value of the fuel fired. The heat Input at peak load for each of these turbines Is 66.4 MMBtu/hr (LIEV) which is greater than 10 MMBtu/hr. Asa result, the turbines would be subject to this NSPS; however, the turbines are also subject to NSPS KKKK (see applicability discussion below). According to NIPS KKKK §60.4305(b) Stationary combustion turbines regulated under this subpart are exempt from the requirements of subpart GG of this part. Heat recovery steam generators and duct burners regulated under this subpart are exempted from the requirements of subparts Da, Db, and Dc of this part. Asa result, NSPS GG does not apply NSPS KKKK: If you are the owner or operator of a stationary combustion turbine with a heat input at peak load equal to or greater than 10.7 gigajoules (10 MMBtu) per hour, based on the higher heating value of the fuel, which commenced construction, modification, or reconstruction after February 18, 2005, your turbine is subject to this subpart. Each of these turbines has a heat input at peak load of 73 MMBtu/hr (> 10MMBtu/hr) and will commence construction after February 18, 2005. Asa result, NSPS KKKK applies to each of these turbines. The applicable requirements have been included in th permit 31 of 52 K:\PA\2011\11 W E1481.CP5.xlsm Turbine Emissions Inventory Regulation 7 Section M.D. Combustion Process Adjustment XVLD.L As of January 1, 2017, this Section XVI.D. applies to the following combustion equipment with uncontrolled actual emissions of NO: equal to or greater than five (5) tons per year, and that are located at existing major sources of NOx, as listed In Section XIXA. XVI.D.Ld. Stationary combustion turbine _ This facility is not a major source of Ntnl and therefore the turbine covered under this point is not subject to this rule. MALI TnT: You are subject to [MS subpart a you own or operate a stationary combustlon turbine located at a major source or HAP emissions. Since this is a major source of HAP and is therefore subject to this subpart. This turbine Is 'new' per 63.6090(a)(2) since it w01 commence construction after 1/14/03. Per the 'Stay of standards for gas -fired subcategories' 63.6095(d) 'If you start up a new or reconstructed stationary combustion turbine that is a lean premix gas -fired stationary combustion turbine or diffusion flame gas -fired stationary combustion turbine as defined by this subpart, you must comply with the Initial Notification requirements set forth in 663.6145 but need not campy with any other requirement of this subpart until EPA takes final action to require compliance and publishes a document In the Federal Register.' Regulation 8 'lean premix gas -fired stationary combustion turbine' is defined in 63.6175 as 'Each stationary combustion turbine whkh is equipped only to fire gas using lean premix technology...'. Furthermore, lean premix technology is defined as 'a configuration of a stationary combustion turbine where the air and fuel are thoroughly mixed to form a lean mixture for combustion in the combustor. Mixing may occur before or in the combustion chamber.' Since these turbines are classified as lean premix gas -fired stationary combustion turbines (see note a3), they must only comply with the repotting requirements in 63.6145 until such time that the stay is lifted via publishing in the Federal Register. Section 07 - Technical Analysis Notes L The manufacturer spedflation sheet provided for this sourie,indicated the fuel Flow perto:oe 66•3 MMBtu/hr however the operator scaled the fuel flow by a factor of 1.1 for alculationsand ...: permitting purposes. Ttils is due to tfu! fact that thremiss{onYates provided on the turbine ma • nufacturer specffintion sheet are haseE on a lower fteaUng vane of natural gas (LHV). Therefore, as conservative measurefor permitting purposes, OCP,.converts the LFiV heat input rate of 66:38 MMBtu/hr to a ht .. , :._eating valu a (HHV) To wmert to the higher heating value the LiiV racing is; „,: ,,u plc.. by.,,,,1 conversion from tHVto HHV). -This methodology result; in a:conservative estimate of fuel consumption and emissions resulting from this sourcer As a result,:this is acceptable for permitting purposes. As such the fuel flow has been corrected td 73.0 MMBtIi/hr. Also, the emission factors.for r NOx and CO (provided by the manfucturer on basis of lb/hr) irate converted to unitsoflb/MMBtu using the corrected heat input rate (Le. 73.0. MMBtu/hr).. - .:' - :.. 2. ,The Solar Turbinespedflcatlon sheet rcportsemiss{ons Info�matlon for unpumed hydrocarbons. However, the spec does not differentiate betweenand non-VOC constituents As'such the VOC' .. .:a.,,, m .. :. 3. Upon request OCP.'provided the r 9ufacturer,brodwre descrfbbg the SoLoNOx technology that meets the deflnidonof a'le •ci premix gas-flrfr stationary;comblistidn ss. i,Mco•Ch; It d s §63:6 The brochure states SoLoNOx utOzeslean-premised combu•ston tech•nology.to ensure• as ex•tremely uniform atr/fuel •mlidure• any t .. , determined that this turbine meets the definitlonaf a'lean premix gas Bred'.tationarycombustion turbine, for the purposes of. '4. It was.tosnmunicated to:DCP on 9/12/17 that the requested. emissions increase of PM2.5. associated with this modification exceed, modeling Lhresholds.:Asa result, OCP iommuniated that ... n ,.. •manfuacturer test data:indiotes lowet PM 2.5 emissions than the • AP -02 emission factors. Although the PM2.S emission rate not guaranteed by e the data I Wasmanfuacturer, trusts that it an l dueve compliance with the IowerPM25 emisswn factor. As a resuh; the emission factor included In the anahfsis'above' is based on non-warianted manufacturerdata:-Itwas agreed that the permit would Inlcudearequ(rement to conduct aztack tort to demonstrate compliance vdtht6e PM2.5 emission rate ..:. gyp_ 5 On 1[26/18 DCPsubmitted a revised application including an ADEN forthis point With. this submittal, DCP s requesting to increase the 2 PMSemission facotorand emission limit Since tAis will be., •tested and reduced PM facto•rs for the heaters (based oni manufacturer guarantee providedWith 1/2018 app( have been proposed, DCP well buffer the emission factor to help ensure compliance forthis pectlon 08 - Inventory SCC Coding and Emissions Facia% AIRS Point R 014 Process N 01 5CC Code l2 Ut-002.01,1 Turbine'Natural;0as Firad"-n uncontrolled Emissions Pollutant Factor Control % Units PM10 5.85E-03 0 lb/MMBtu Input PM2.5 5.85E-03 0 lb/MMBtu Input NOx 3:97E-02 0 lb/MMBtu Input VOC 2.10E-03 0 lb/MMBtu Input CO 5.51E-02 0 lb/MMBtu Input SOx 3.40E-03 0 lb/MMBtu Input Formaldehyde 7.10E-04 0 lb/MMBtu Input Acetaldehyde 4.00E-05 0 lb/MMBtu Input Acrolein 6.40E-06 0 lb/MMBtu Input Benzene 1.20E-05 .0 lb/MMBtu Input 1,3 -Butadiene 4.30E-07 lb/MMBtu Input Ethylbenzene 3.20E-05 lb/MMBtu Input Toluene 1.30E-04 lb/MMBtu Input PAH 2.20E-06 lb/MMBtu Input Xylene 6.40E-05 lb/MMBtu input 32 of 52 K:\PA\2011\11 W E1481.CP5.xlsm Heater Emissions Inventory Section 01- Administratlne Information Facility AIRS ID: County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: One(1)Heatec (ModeI::7BD, SN: 1BD) datunl ps Bred regeheraticn heater. The':Aeater h'desige rated at 93:: Emission Control Device [Equipped with a Low.NOx system for minimizing emissions of Nitrogen Oxides. The Low NOM combustloo roc .- Description: system Is considered Integral to the Process and not an add-on'control device. Requested Overall VOC & HAP Control I Efficiency %: ...:i._..._ Low NOx combustion system Is considered an integral control device. Section 03- Processing Rate Information for Emissions Esthnates Heat Input Rate • Heat content of waste gas= Actual Hours of Operation • Requested Hours of Operation • Actual heat input rate • Requested heat input rate • Potential to Emit (PIE) heat Input rate • Actual Fuel Consumption • Requested Fuel Consumption • Potential to Emit (PIE) Fuel Consmption • Section 04- Emissions Factors & Methodologies 6.51. MMBtu/hr (7O% fuel opacity) 1050 etu/srf hrs/year New Source - not yet Installed 8760 hrs/year 0.00 MMBTU per year 57,025.50 MMBTU per year 57,025.50 MMBTU per year 0.00 MMscf/year 54.31 MMscf/year 54.31 MMscf/year Emission Factors Regeneration Heater Emission Factor Source Pollutant Uncontrolled Ib/MMscf (Fuel Consumption) VOC ',5 5Pti AP -43 Chapter S Tebie 14.2 Martis"fLctutett'c, Mmu z het AP-42tltapterirable i.4-2 AP-42:Chepter l Table,A able La - AP.12Chapteri Table1i PM1O PMLS 5.3 ' 500 0 6 NOx 500; CO 84.0 r"≥ Formaldehyde 752E-02Chapter 1TablelA-3 APJYGapter 1Tabla Ld-3� Benzene . 2.10E-03 Toluene 3.40E-03 AP -02 Chapter,11Tabe 1.43 AP -42 gwp[m 1�Tab1e 2.4.3 n -Hexane ...1:8:: Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC PM1O PM2S 5Ox NOx CO 0.15 0.14 0.14 0.02 1.36 2.28 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.15 0.14 0.14 0.02 1.36 2.28 0.15 0.14 0.14 0.02 1.36 2.28 LB/Month 24.21630822 24.21630822 2.767578082 230.6315069 387.4609315 Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Formaldehyde Benzene Toluene n -Hexane 2.042E-03 5.703E-05 9.233E-05 4.888E-02 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 _ 2.042E-03 5.703E-05 9.233E -0S 4.888E-02 2.042E-03 5.703E-05 9.233E-05 4.888E-02 4.0841 0.1141 0.1847 97.7580 4.0841 0.1141 0.1847 97.7580 33 of 52 K:\PA\2O11\11 W E1481.CPS.xlsm Heater Emissions Inventory - Reautatory Summary Ana • Regulation 1 Section 11.0.1- Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is In excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 - second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section tILA. No owner or operator shall cause or permit to be emitted into the atmosphere from any fuel -burning equipment, particulate matterin the flue gases which exceeds the following: III.A.1.b. For fuel burning equipment with designed heat inputs greater than 1x10° BTU per hour, but less than or equal to S00x10s BTU per hour, the following equation will be used to determine the allowable particulate emission limitation. PE=5(FI)am Where: PE. Particulate Emission in Pounds per million BTU heat input. Fl - Fuel Input in Million BTU per hour. The regeneration heater covered under this point has a design heat input rate of 9.3 MMBtu/hr. Asa result, the heater Is subject to this portion of the regulation. Using the above equation, the allowable particulate emission limitation is 0.28 m/MMBtu. The AP -42 emission factor of 7.6 Ib/MMsd (724x10' lb/MMBtu) used In the cakulatians above is below this particulate emission threshold. Section VI.BS. My new source of sulfur dioxide not specifically regulated above shall: VI.BS.a. Limit emissions to not more than two (2) tons per day of sulfur dioxide. Based on the calculations above, this source will emit 0.02 tons per year of sulfur dioxide. This is below the requirement of 2 tons per day and therefore the source is in compliance with the above regulation. 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 result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 3 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. Applicant is required to file an APEN since emissions exceed 1 ton per year NON. Part B - Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled NOx emissions from this facility are greater than the 2.0 TPT threshold (Reg. 3, Part B, Section II.D.2.a) Regulation 6 Part B Section II: Standards of Performance for New Fuel Burning Equipment II.C. Standard for Particulate Mater. On and after the date on which the required performance test is completed, no owner or operator subject to the provisions of this regulation may discharge, or cause the discharge into the atmosphere of any particulate matter which Is: II.C2. For fuel burning equipment generating greater than one million but less than 250 million 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 Is the allowable particulate emission in pounds per million Btu heat input. Fl is the fuel input In million Btu per hour. If two or more units connect to any opening, the maximum allowable emission rate shall be the sum of the individual emission rates. II.C3. Greater than 20 percent opacity. The regeneration heater covered under this point has a design heat input rate of 9.3 MMBtu/hr. Aga result, the heater Is subject to this portion of the regulation. Using the above equation, the allowable particulate emission limitation is 0.28 m/MMBtu. The AP -42 emission factor of 7.6 lb/MMad (724.10-3 lb/MMetu) used In the calculations above is below this particulate emission threshold. MPS Dc Except as provided in paragraphs (d), (e), (f), and (g) of this section, the affected facility to which this subpart applies is each steam generating unit for which construction, modification, or reconstruction is commenced after June 9, 1989 and that has a maximum design heat Input capacity of 29 megawatt (MW) (100 million British thermal units per hour (MMBtu/h)) or less, but greater than or equal to 2.9 MW (10 MMBtu/h). This heater win be constructed after 06/09/89. However,Tha design heat input rate foe this regeneration heats Is 93 MMBtu/hr which is less than 10 MMBtu/hr. Asa result, the regeneration heater is not subject to MPS Dc. Regulation 7 Section XVI.D. Combustion Process Adjustment XVI.D.1. As of January 1, 2017, this Section XVI.D. applies to the following combustion equipment with uncontrolled actual emissions of NON equal to or greater than five (5) tons per year, and that are located at existing major sources of NOx,"as listed In Section XDt.A. This facility is not a major source of NON and is therefore not subject MAR MAR DDDDD: This subpart establishes national emission limitations and work practice standards for hazardous air pollutants (HAP) emitted from industrial, commercial, and institutional boilers and process heaters located at major sources of HAP. This subpart also establishes requirements to demonstrate initial and continuous compliance with the emission limitations and work practice standards The regeneration heater covered under this point is located at ■ major source of HAP and is an affected source as a "proms heater as defined in 63.7575. This unit is 'nevr since It ill commence construction after lune 4, 2010. This process heater is among the subcategory listed in 63.7499 Identified as 'units designed to burn gas 1' as defined in 63.7575 since this heater bums only natural gas. Pen 463.7500(e) this proms heater Is not subject to the emission limit and work practice standard in Tables 1, 2 and 11 through 13 nor operating Emits In Table 4 since It is In the gas 1 fuels cateogry. This unit must complete a tune-up every 2 years as specified in 463.7540. The requirement contained in Table 3 to conduct a one-time energy assessment does not apply to 'new' proms heaters and boilers. As such, the requirement to certify'this facility has had an energy assessment performed according to 63.7530(e)' does not apply. Otherwise, the Notification of Compliance Status shall be submitted per 63.1545(e)(8). 34 of 52 K:\PA\2011\11 W E148LCPS.xlsm Heater Emissions Inventory Section 07 - Technical AnaNsh Notes 1 ThI r is th 'cetego Ical perm i exe Otion In Beg I ti 'n 3 P rt B Section ILD l.e wBiat states Each nd' d I piece f fuel bum g egwpment other than-srnokehouu genmtors th "t Ses . gaseousfuel nd that has a design.rate less than or equal to ten million Brltish thermthernialZiniti per. hour. Howe4er DCP is request ng a perm t and 11 request an entorcc bl 11 t on I ei use (lessahan, 2- The perm t *41 not contain emrsstods (actors for the HAPs associated with this source because the emissions are below repot 3 Thrs heater s eq ppgd with a to NOn combustion system per em (8/25/17"Az a rewit, the operator Theeutilized the NOx em Lawn (actor Itom AP 42 Table 14.1 that is based on tnt ( boilers (0100•- MMBtu( equipped vnth low NOx bumero. 4 Applicant doted that th s unit is cap hie of running at reduced; load nd he ce reduced fuel sage m soon cal<ul atlons n [h s analsps are based o teq epennng meat 70%full capacity .: =s 7 I 5 Appl coot whmitted"a rev sed APEN on 1/26/18. With this evision OCP s request ng to decrease [he requested particulate emissions based on he sted manufact a guaranteed emissionrates of 0.005 I Ib/MMBtuJ A manufacturer spec sheet woo provided ' - .` ' " ( 6. An morel c mpiiancetest will be requved for this Beater to demonstrate comprono with' NOx, PM 25 and.CO eoron. Section 08 - Inventory 5CC Coding and Emissions Factors AIRS Point e 015 Process g 01 5CC Code Pollutant PM10 PM2.5 NOx VOC CO SOx Formaldehyde Benzene Toluene n -Hexane Uncontrolled Emissions Factor 5.3 5.3 50.0 5.5 84.0 0.6 7.52E-02 2.10E-03 3.40E-03 1.8 Control% Units O Ib/MMscf Burned O Ib/MMscf Burned O Ib/MMscf Burned O Ib/MMscf Burned O Ib/MMscf Burned O Ib/MMscf Burned O Ib/MMscf Burned O Ib/MMscf Burned O Ib/MMscf Burned O Ib/MMscf Burned 35 of 52 K/,PA\2011\11 W E1481.CP5.xlsm Heater Emissions Inventory Section 01- Administrative Information Facility AIRS ID: County 9012 5: 016 Plant Point Section 02 - Equipment Description Details ;One (1) natural pa hostWak e: aker TBD, Model: TBD, SitTBD) natural Ps fired hot oil heater. The heater Is design rated Detailed Emissions Unit at 48.4 MMIStuthr. The heater provides heat for the condensate •tab04er :.. - Emission Control Device (Equipped with a Low We combustion system for minimising emissions of N[trogen Oxides. The Low NOs contbnad in - _.. Descdptlon: isynem b-mnsideed integral to the prxesa andeot an sAdon corrtml.devke. Requested Overall VOC & HAP Control _ ;I Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Heat Input Rate = Heat content of waste gas = Actual Hours of Operation Requested Hours of Operation = Actual heat input rate = Requested heat input rate = Potential to Emit (PTE) heat input rate = Actual Fuel Consumption • Requested Fuel Consumption Potential to Emit (PIE) Fuel Consmptlon v Section 04- Emissions Factors & Methodologies Low NOs combustion system Is considered an integral control device. New Source - not yet installed 0.00 MMBTU per year • 423,984.00 MMBTU per year 423,984.00 MMBTU per year 0.00 MMscf/year 403.79 MMscf/year 403.79 MMscf/year Emission Factors Regeneration Heater Emission Factor Source Polhrtant Uncontrolled Ib/MMscf (Fuel Consumption) VOC 5.5 `- - AP42 Chapter I Table04.2 PM10Manufacturer Ph125 - 5.3 >- ManuhQurer A SOs 0.6 '.. APw42 Chapter1 Table 1-4.24 NOa 50.0 A(M2Cnapter 1Tablei4.1 ) ' CO 840 '. AP42 Chapter l Table1.4.1::' " Formaldehyde 7.52E-02' AP -42 Chapterl Table 14-3 Benzene 210E-03 A942Chapter1Tablel.4-3' Toluene 3.40E-03 APB Chapter l Table L44 a Rq st n.Heane : . ..... 18' a APiiCliaptrn'1 Tobte,3.4-3 ., ettlon 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC PM10 PM25 SOa NOa CO 1.11 1.06 1.06 0.12 10.09 16.96 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.11 1.06 1.06 0.12 10.09 16.96 1.11 1.06 1.06 0.12 10.09 16.96 lb/month 188.6 180.0 180.0 20.6 1714.7 2880.8 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled Imn./y•ar) (mnnNaarl Requested Permit Umits Uncontrolled Controlled (tons/year) (tons/year). Requested Permit Umits Uncontrolled Controlled (tbs/etar) (mortar) Formaldehyde Benzene Toluene n-Hesane 1.518E-02 4.240E-04 6.865E-04 3.634E-01 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 1.518E-02 4.240E-04 6.865E-04 3.634E-01 1.518E-02 4.240E-04 6.865E-04 3.634E-01 30.3653 0.8480 1.3729 30.3653 0.8480 1.3729 726.8297 726.8297 36 of 52 NAPA \ 2011 \ 11WE148LCP5.xisrn Heater Emissions Inventory Section 06 - Regulatory Summary Analysis Regulation1 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 an pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 1.5 - second Intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. ' Section IIIA. 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: IIIA.1.b. For fuel burning equipment with designed heat inputs greater than 1010' 8TU per hour, but less than or equal to 500x10' BTU per hour, the following equation will be used to determine the allowable particulate emission limitation. PE•0.5(FI)an Where: PE • Particulate Emission in Pounds per million BTU heat input. Fl • Fuel Input in Million BTU per hour. . The hot o0 heater covered under points 016 has a design heat input rate of 48.4 MMBtu/hr. As a result, the heater is subject to this portion of the regulation. Using the above equation, the allowable particulate emission limitation is 0.162 lb/MM8tu. The AP -42 emission factor of 7.6 lb/MMscf (7.24x104Ib/MMBtu) used in the calculations above is below this particulate emission threshold. Section W.B.S. Any new source of sulfur dioxide not specifically regulated above shall: VI.B.5a. Limit emissions to not more than two (2) tons per day of sulfur dioxide. Based on the calculations above, this source will emit 0.1 tons per year of sulfur dioxide. This Is below the requirement of 2 tons per day and therefore the source is in compliance with the above regulation. Regulation 2 Section IA - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it h a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 3 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 Applicant is required to file an ADEN since emissions exceed 1 ton per year NO. Part B — Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled NOx emissions from this facility are greeter than the 2.0 TPY threshold (Reg. 3, Part 8, Section II.D.2.a) Regulation 6 Part B Section II: Standards of Performance for New Fuel Burning Equipment: ll.C. Standard for Particulate Matter. On and after the date on which the required performance test is completed, no owner or operator subject to the provisions of this regulation may discharge, or cause the discharge into the atmosphere of any particulate matter which is: ll.C.2. For fuel burning equipment generating greater than one million but less than 250 million Btu per hour heat input, the following equation wig be used to determine the allowable particulate emission limitation: PE•O.5(FI)-0.26 Where: PE is the allowable particulate emission in pounds per million Btu heat input. Fl is the fuel input in million Btu per hour. If two or more units connect to any opening, the maximum allowable emission rate shall be the sum of the individual emission rates. Il.C.3. Greater than 20 percent opacity. . NSPS Dc Except as provided In paragraphs (d), (e), (f), and (g) of this section, the affected facility to which this subpart applies is each steam generating unit for which construction, modification, or reconstruction is commenced after tune 9, 1989 and that has a maximum design heat Input capacity of 29 megawatts (MW) (100 million British thermal units per hour (MMBtu/h)) or less, but greater than or equal to 2.9 MW (10 MMBtu/h). The deign hat Input rate for this hot oil hater Is YA MMBtu/hr which Is grater than 10 MMBtu/hr. Additionally, this heater will be constructed after 06/09/89. According to NSPS Dc, a steam generating unit Is defined as "a device that combusts any fuel and produces steam or heats water or heats any heat transfer medium. This term includes any duct burner that combusts fuel and is part of a combined cycle system. This term does not include process heaters as defined in this subpart.' Since this hot oil heater is used to heat a heat transfer medium (hot oil in this instance), the heater meets the definition of a steam generating unit. Asa result, the hat oil heater is subject to NSPS Dc. Regulation 7 Section OVI.D. Combustion Process Adjustment . XVI.D.1. As of January 1, 2017, this Section KVI.D. applies to the following combustion equipment with uncontrolled actual emissions of NOx equal to or greater than Me (5) tons per year, and that are located at existing major sources of NOx, as listed in Section RIX,A. This heater is not located at a major source of NO. Therefore this equipment in not subject to this section Regulation 8 MALT DDDDD: This subpart establishes national emission limitations and work practice standards for hazardous air pollutants (HAP) emitted from industrial, commercial, and institutional boilers and process heaters located at major sources of HAP. This subpart also establishes requirements to demonstrate initial and continuous compliance with the emission limitations and work practice standards The regeneration heater covered under this point is located at a major source of HAP and is an affected source as a 'process heater" as defined in 63.7575. This unit is 'new' since It will commence construction after June 4, 2010. This process heater is among the subcategory listed in 63.7499 identified as 'units designed to bum gas 1' as defined in 63.7575 since this heater burns only natural gas. Per 663.7500(e) this process hater is not subject to the emission limit and work practice standard in Tables 1, 2 and 11 through 13 nor operating limits in Table 4 since it Is In the gas 1 fuels cateogry. This unit must complete a tune-up annually as specified in 663.7540. The requirement contained in Table 3 to conduct a one-time energy assessment does not apply to 'new' process heaters and boilers. As such, the requirement to certify "this facility has had an energy assessment performed according to 63.7530(er does not apply. Otherwise, the Notification of Compliance Status shall be submitted per 63.7545(e((8). 37 of 52 K:\PA\2011\11W E 1481.CP5.%Ism Heater Emissions Inventory ;ectbn 07 - Technical Analysis Notes 1 Thesulfur dioidde(SOr)requirementaof§60.42c applyto affected fadlities Nat combust coal, coal tth aMerNeh or off The.par[kulate matter(PM)rsm requients of§0:4 63c apply to iffected hdgtlei ... ... .that comourt snit, 08; wood, a miature:ot these Nets Dots mixture of these Nell With any other Nets Ance this hot oil h eater will only combustb natural gas produce heat, It h notwhject to the wlfur::: dbxide'orparticohteMatter emission Itinits of NSPS Dc As wch, the aourca b only sub(ect to the reportingand recomketp crag requirements of §60.48c The, heater. wiA comply with the folbwing . requirements of §60.08c (I) §6o.4ac(a):-me owner or of:tach affected faritty sha0:wbmit notlflcation otthe date of construction or remrtstruttlortind actual sbrNp, x provided by §60.7 of this'- . . _.. .. .. -,.;:r . .. , part' 181460.A8c(v121"As an altemat(ve to meeting the requirements of parsgnph (g)(l) of this section, the owner or operator of an affected hcg ity that combusts only natural gx, woody Nets usingNel certification in §60ABc(t) m demonstrate compfunrx with the SOtihntlud, fuels not wbjectto in emissions mordard (esdudbg opacity), or i muht a of these fuels may elect to record and maintain records of the amount of each Nel combusted doting each calendar month -"((B) §60 48c(l)'All recods required Dower this sectlon shall be maintained by:the owner or operator of the affected facility fore,, e , . ::.. a period of two years folbvnny the date of wrh record:' DCP has expressed they will comply with the have mentioned requ've. menu. •, L Thb heater is equipped with a low NOx co bustbn cycle per ematl8/25/2037. As a result, the opentw utll¢ed th NOx emis slon factor from AP 42 Table:l.bl that N)is s .. MMBeputpped lo withw NOs b men. .3. APplIcant s+bmitted a revised APEN:on 1/26/18. W ith this revtsbn; OCP o requesting to decrease the requested �p rtkulate emissions based do"manufacturer goara lend emasto rates of0.005 Ib/MMBtcr A manufacturer spec,sheat was provided wish the guaranteed emission hcton for minufa[turer. Heater : . -0. An bitlal compltance..test will be required for this heater to demonrtnte comp0anca wish NOz and CO emission Omits. ARnwgh DCP busing manuhcturergwnnteee emission facNrs for PM25; h was , P to: remove PM2-5:from the initial compliance test becuase i)emissions ofPM25are below7reporting thresh hisand'u)'.00P pmvided aletter from the manuhcts r(Heatec)that goirantee the .; partIculatematteremtss-answill not esceed00051h/MMBTU.Thnguarantee spedfwlly references Me O•tonnor:llpmteR ;ectbn 05 - Inventnry SCC Coding and Emissions Factors AIRS Point 8 016 Process 8 SCC Code 01 i3:t0.00404'-Natutat Gas ,. 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Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A. Section 11.0.1..)? 2. Are total facility uncontrolled VOC emissions greater than S TPY, N00 greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.3)7 ,.✓!✓ :?n You have indicated that sour. la in the Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this Individual source rester than 1 TPY (Regulation 3, Pan A, Section 11.0.1..)? YescrclijSource Requires an APEN. Go to the next question 2. Are total facility uncontrolled VOC emissions horn the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than S TPY (Regulation 3, Part B, Section ll.D.2)? Yes-ir�a%4 Source Requires s permit (Source requires a permit Colorado Regulation 7. Section %II.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 011.11.1 and 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 2. %11.X.1 and 2)7 3. Is the sum of actual uncontrolled emissions of VOC from any style dehydrator or group of dehydrators at a single stationary source equal to or greater than 15 tpy (Reg 7, Section 011.0.3.0)? 4. Are actual uncontrolled emissions of VOC from the Individual glycol natural gas dehydrator equal to or greater than I spy (Reg 7, Section XII.H.3.a)7 IDehydrator Is subject to Regulation 7, Section XO.11 Section XII.N — Emission Reductions from glycol natural gas dehydrators MACT Analysis 1. Is the dehydrator located at an oil and natural gas production facility that meet either of the following criteria: 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 end b. users (63.7601a737? 2. Is the dehydrator located at a facility that is a major source for HAPs7 Ito to MACT Hit Major Source Requirement section to determine MAR 110 applWhilily 40 CFR. Part 63. Subpart MAR Hit Oil and Gas Production FaciRtley Area Source Requirements 1. Is the dehydrator a trlethylene glycol (TEG) dehydration unit (63.700(b)(2))? Enmotions 2a. Is the actual annual enrage Rowrate of natural gas to the glycol dehydration unit less than 3.001747 MMsd 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)(B)? 3. Is the unit located inside of a UA plus offset and UC boundary area? Innis have indicated that this facility Is not subject to Area Source requirements of MAR NH. Subpart A, General provisions per §63.764 (a) Table 2 §63.76S - Emissions Control Standards §63.773 - Monitoring Standards §63.774 - Recordkeeping 453.775 Reporting Melor Source Requirement 1. Does the facility have a fadliry-wlde actual annual average natural gas throughput less than 0.65 MMsd/day AND a facility -wide actual annual hydrocarbon liquid throughput less than 249.7 Small or hares Deity Determination 2a. Is the actual annual avenge Oowrate of natural gas to the glycol dehydration unit less than 3.001747 MMsd per day (63.761(7 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 ;mall DeM Resulrementy 3. Did construction of the small glycol dehydration unit commence on or before August 23, 2011163.760(b)(1)(H(B) and (C )1 4. For this small dehy, is a control device required to meet the BTEX emission limit given by the applicable equation? ITN, unit Is a new .small daisy and subject to MACT 1111 emission limit per Equation 1163.765(bl(1)(Ii). This unit Is subject to MAR control standard 63.765 Subpart A, General provisions per §63.764 (a) Table 2 §63.765 - Emissions Control Standards §63.773 = Monitoring §63.774 - Rewrdkeeping §63.775 -Reporting Yes Yes Yrs Continue - You have Indicated the attainment status on the Project Summary Sheet. Continue - You have indicated the facility type on the Project Summary Sheet. to to the next question Dehydrator is subject to Regulation 7, Section %11.11 Continue - Source Is subject to MAR OH requirement. You have indicated the source category cn the Project Summary Sheet. IYes i 1 Ito to MAR Hit Major applicability suction NOR-7,^',cal Go to the next question 900000 Now go to question 2b Yen The dehy unit is a small dehy -Go to next questions N -.? ?n) The unit is a new small deny and subject to emission Minh per Equacoat 2163.765(b((1)(10) Yesx'Ysi?'i This unit has an applicable MACT control standard, and is not subject to regulation 7, Section XVII 40 RR.Part 53. Subvert MAR FIRM. Natural Gee Treysmission end Sterne Fac111tie2 1 is the facility wide actual annual average natural gas throughput less than 0.9994051 MMsd/day and glycol dehydrators the only HAP emission source (63.1270(0)? jmall Or Unite Dehir Determination 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 9.994051 MMtd per day (63.1270(b)(2))? 2b.- Are actual annual avenge emissions of benzene from the glycol dehydration unit process vent to the atmosphere lets than 1,984.2 lb/yr (63.1270(b1121(? jmall Debt Requirement( 3. Did construction of the small glycol dehydration unit commence on or before August 23, 2011(63.1270(6)(2) and (3)17 e. For this entail dehy, Is a control device required to meet the BTEX emission lime (standard?) given by the applicable equation? 'You how indicated tut this facility is not sublecl to MAR HHH. Subpart A. General provisions per 963.1274 (a) Table 2 563.1275 - Emissions Control Standards 563.1281 -Control Equipment Standards 563.1213 - Inspection and Monitoring 563.128 - Retordkeeping 563.1285- Reporting Colored. RMuletlen 7. SentlOn fan ID 1. Is the dehydrator subject to an emissions control requirement under MAR HH or HHH (Regulation 7, Section XVII.B.5)? 2. Is this dehydrator located eta transmbsion/storage facility? 3. Is this dehydrator located el an oil and gas exploration and production operation , natural gas compressor station or gas processing plant (Reg 7, Section IMI.D.3)? 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 horn a single glycol natural gas dehydrator equal to or greater than 6 tons per year VOC or 2 spy VOC If the dehydrator 4a. Is bated within 1,320 feet of a building unit or designated outside actMly 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)? 'Dehydrator Is not sublecl to Regulation 7, Section XVII.0, D.3 Section IMI-B—General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section X1111.0.3 - Emissions Reduction Provisions Alternative Emissions Control Motional Sectonl 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? 'The control device for this dehydrator is not subject to Regulation 7, Section 21/11.5.2.6 Section XVII.8.2.a -Alternative emissions control equipment Disclaimer This document assists operators aith determining applicability of certain requirements of the Clean Air Ad, its implementing regulation, and Air Duality Control Commission repoletlons. This document is not a who or regulation, and the analysis it contains may not apply to a parOcidar situation based upon the individual fads end dmumstences. This document does nol change or substitute for any law reputation, or any other legally b/ndng requirement and Is not legally enforceable. M the event of any congicf baiaeen the language of this document and the language of ta. Clean Air Ad,. its Implementing regulations, and Air Duality Control Commission regulations, the language of the astute or regulation Hill Oontr0l. The use of non -mandatory language such as 'recommend'may, "she/d,' and 'can,'is intended to describe APCD interpretations end recommendations. Mandatory terminology such as 'must' and 'required ere intended to describe controlling requirements under the termg of the Clean Air Ad and Air Duality Conti Commission regulations, but this document does not establish legally binding requirements in and of Itself. Yet No yes No''�i:%::;v.3 rei Source is not subject to Rag 7, Section IMI - You have prMoudy Indicated this in the MAR Halo. Continue - you have previously indkated this hr the beginning of the MAR section Continue - You have previously indicated this in the Reg 7, Section XII determination Go to question s Section 01 - Administrative Information Facility AIRS ID: 9012 f.:i:019. Plant . Point County Section 02 - Equipment Description Details Detailed Emissions Unit Description: !Preisurked unbaEin(sit taw.caWeroote Emission Control Device Description: ... .. P Wilouf'ii conducted using subnieryed;Ril Noadd-on controls Liquid Hose Hose Diameter 0.25000 feet Vapor Hose Diameter 0.25000 feet Uquid Hose Length. 1 feet Vapor Hose Length' 1 feet Uquid Hose Volume 0.0491 cubic feet Vapor Hose Volume 0.0491 cubic feet Truck and Tank Pressure 97 109.2 psig psla 1Loadout Capacity 7000 gallons/load Condensate Production 5,110,000 gallons/month 730 loadouts/month .. .. ..... .._... - . 8760 loadouts/year •length accounts for length of isolation valve on pressurized hose 1,460,000 lbbl/yr All liquid lines contain liquid products at individual specific gravity. All vapor return lines contain products that behave as Ideal Gases at 60 deg F and storage tank pressure P•V-n•R•T Where: P - pressure in hose at time of disconnect = storage tank pressure (psia) V = Volume of hoses (cubic feet) number of Ibmoles of product in hoses R = Universal Gas Constant = 10.73 ftu3 • psi / Ibmole / deg R T = avg loadout temp = 60 deg F - 519.67 deg R Vapor Density. 0.000961314 0.019583724 Ibmol Ibmol/fM3 lb/Ibmol Ib/ft03 n/V MW 44 Vapor Density 0.861683837 Vapor VOC Emissions 370.5287843IIb/yr 0.185264392 tpy Total VOC Emissions Emission Factor 8.45 1.930 tPy lb/loadout event 1408.928351 ton/month HAP Mass Fraction Benzene Toluene Ethylbenzene Xylenes n -Hexane 0.96% 0.95% 0.05% 0.30% 8.07% Emissions Summary Uquid Density 5G 0.6172 Density of Water 8.33 lb/gal Uquid Density 5.141276 lb/gal 38.46 lb/ft=3 Uquid VOC Emissions 16536.611431 lb/yr 8.27 tpy Pollutant Uncontrolled Emission Factor Ucontrolled Emissions Controlled Emissions VOC 1.9300 Ib/loadout 8.45 tpy 8.45 tpy Benzene 0.0186 lb/loadout 163 lb/yr 163 lb/yr Toluene 0.0184 Ib/loadout 161 lb/yr 161 lb/yr Ethylbenzene 0.0010 Ib/loadout 8 lb/yr 8 lb/yr Xylenes 0.0058 Ib/loadout 51 lb/yr 51 lb/yr n -Hexane 0.1558 Ib/loadout 1.365 lb/yr 1365 lb/yr Section 06 - Renulatory Anafysiy Regulation 1- Particulate, Smoke, Carbon Monoxide and Sulfur Dioxide Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Reference: Regulation No- 1, Section ILA.L) Jtetolatlon2 Odor - Section IA - No person, wherever located, that 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 Omits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous an has been diluted with seven (7) or more volumes of odor free air. j2eglllador J ADEN aIM Pertnfttllq.Requirornent4' Is this site considered an exploration and production location (e.g. well pad)? ( .:: No ..1 If yes, review the following two exemptions for applicability: Does the operator unload less than 10,000 gallons (238 BBL.$) per day of crude oil on an annual average bash? If yes, this emissions point is categonalfr exempt from permit requirements per Regulation 3, Part B, Section 11.0.1.1 Does this operator unload less than 6,750 bbls per year of condensate via splash till or 16,308 bbls per year of condensate via submerged fill procedure? If yes, this emissions point it categorically exempt from permit requirements per Regulation 3, Part B, Section IID.1.1 WA Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are requiredfor: 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 iummed) for which the area is non -attainment 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 11-D.2.a) Part B. 111.02 - RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is located in the B -hour ozone nonattainment area, but not the 1 -hour ozone area. The date of interest for determining whether the source is new or modified is therefore November 20, 2007 (the date of the 8 -hour ozone NA area designation). Since the tank battery from which loadout Is occurring came into service after the date above, this source is considered 'new or modified.' New storage vessels will be constructed upon issuance of this permit loadout is done from a pressurized vessel to a pressurized vessel. Vapors from disconnected hose vent to the atmosphere. Operator b using vapor balance via pressurized tank. Therefore, RACT requirements are satisfied- ,.—..„-.: 6 New Soszrcn rrnanc..S ohms . .,...,.....�.,.. jtendatlon 4 -New Source Per(ortmnce Standards No applicable subpart- ml, fadBH b not dasdflad as a bulk gasoline tennirnl. No sections apply. Per Regulation 7, Section VI -C, a terminal and a bulk plant are defined as a petroleum liquid storage and distribution facility that has a daily average throughput of more than 76,000 liters of gasoline (20,000 gallons), which is loaded directly Into transport vehicles. This facility I, neither a terminal, nor a bulk plant per definitions in Reg 7, Section VEC. ,R ._....___._ _... Re[tdatlon 8' -Hazardous Air Pdlufants-_ _ � _:..:- . MALT EEEE: This subpart applies to organic Bquid distribution operations (OLD operations). Per 63.2334, you are subject to this subpart if you own or operate an OLD operation that is located at, or is part of, a major snore of HAP emissions. Furthermore, this section identifies that OLD operations do not include the activities and equipment, including product loading ratio, used to process, store, or transfer organic liquids at ;oil and natural gas production field facilities, as the term "facility" is defined in 63.761 of subpart HH. EPA has confirmed that natural gas processing plants are included in the definition of 'natural gas production field facilities" for the purposes of this subpart Therefore, this source is not subject to this subpart method logy used to estimate emissions from the prensurloed loadout b a mass halance thatessumes [he only vapor released t o the atmosphere ate from fluid. mntained'.m the hoses when they are discennectedand exposed to atmospheric pressure. , RACT for this sourcehasbeen determined to be vapor balance = „ Hydrocarbon Loadout Emissions Inventory section 01- AdmkststratM Information Facility AIRS ID: 123 2 "020 County s5et0on 02 - Eapbnsent DesoHPtlon DIMO N • Detailed Emissions Unit Description: Plant Point )SbWO5d rsdensati bedout to teak tnsrlo. Emission Control i "T IEmbsbns from this Mums iiiitaidribilied by Wiebeiopad eomhurtor5 .. Requested Overall VOC & HAP Control Efficiency Sedlon 03 - Processing Rote Information for Emissions Estimates Annual Actual Through put = Annual requested Throughput • Section 04 - Emissions Fecton, & Methodologies SPodeut Emu Ma L • 12.46•S.P.M/T (AP -42: Chapter 5.2, Equation 1) L>• loading losses In lb per 1000 gallons loaded Barrels (bul) per veer 675,250 Barrels (bbl) Par Misr 25360500 gal/yr Factor Meaning Value Units Source S Saturation Factor -0.6 AP -42 Chapter 5, Tab. 5.21 Sumer bg.d ksedlrig- dadluatad siarmet fades P True Vapor Pressure :.':50032 �psia Avergd;wpor presses .fromPA Nis5 ETAio.9d w/ 080 RIP 101aot'nd In Denver, CO +- , :550 '.' M Molecular Weight o/ Vapors : : 66 lb/lb-mole AP-2Cbaptar7Tab. 712:evp 10 .. T Uquld Temperature %""-512:45 deg. R UgWd Bulk Tempaaturifrom EPATanka409d-/GaioO RVP:, 101osated bs Denser,"CO " NCRPs Component 4.52 lb/10a3 gal 2.02E-01 Ib/bbt Mass Fraction Benzene Toluene Ethylbenzene 0yien ,Hexane 2,2,4 -IMP Source: 3.66%.'III: Combustor Emiab,e Control Device: Total VOC Emissions Vapor MW: Molar emissions: Std Temperature: Std Pressure: Gas Constant (R): Waste Gas Volume: Pilot Flow Rate: Pilot Gas Volume: Assist Gas Flow Rate: L:".: Assist Gas Volume: Waste Gas HHV: Fuel Gas HHV: Waste Heat Input: Pilot Heat Input: Assist Gas Heat Input: Waste Gas Combustion: Pollutant NOa CO Stabilised all sample from condensate -stomp :gene EILLdoied Combustor : (Make::TBD; ModelTOD) ::.::: i;.A 136622,59 lb/yr 66.00 ib/Ibmol 2070.04 Ibrriol/W 512:45 R 3212 psi* 'I i10.73 sd-psia/R-Ibmol 0.94 MMsd/yr sd/hr 0.53 MMsd/yr 1200AOIsd/br 10.51 MMsd/yr Btu/sal Btu/sd 3453.71 MMBto/yr 551.03 MMBtu/yr 11037.60 MMBtu/yr 3677.20 ;1050.00 Emission Factor Uncontrolled Emissions Controlled Emissions 0.238 Itpy 0.949 spy Source TNRCC (.138 lb/MMBTU) TNRCC (0.5496 tb/MMeTU) Pilot Gas Combustion: Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Sour. NOs 100 Ib/MMsd 0.026 tpy 0.026 tpy 4042 Section 1.4 CO 84 Ib/MMsd 0.022 spy 0.022 spy 4042 Section 1.4 VOC 5.5 Ib/MMsd 0.001 Spy 0.001 spy AP42 Section 1.4 PM 7.8 Ib/MMsd 0.002 spy 0.002 spy AP42 Section 1.4 502 0.8 lb/MMsd 0.000 tpy 0.000 tpy AP42 Section 1.4 7.08E-04IIb/bbI 2.81E-03 lb/bed 0.238 I Spy 0.949 spy Assist Gas Combustion: Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source NOa 100 Ib/MMsd 0.526 spy 0.526 spy AP42 Section 1.4 CO 84 Ib/MMsd 0.442 spy 0.442 spy AP42 Section 1.4 VOC 5.5 lb/MMsd 0.029 spy 0.029 tpy AP42 Section 1.4 PM 7.8 Ib/MMsd 0.040 spy 0.040 spy AP42 Section 1.4 SO2 0.8 Ib/MMsd 0.003 spy 0.003 spy AP42 Section 1.4 Total Combustion Emissions (Waste gas ♦ Pilot Gas ♦ Assist Gas) Pollutant Uncontrolled Emissions Controlled Emissions NOs 0.79 tpy 0.79 tpy CO 1.41 tpy 1.41 tpy - VOC 0.03 spy 0.03 tpy PM 0.04 WY 0.04 tpy 102 0.00 tpy 0.00 tpy Hydrocarbon Loadout Emissions Inventory Section 05 - Emissions Inventor( uasbd Emisbns Emission Factor Uncontrolled Emissions Controlled Emissions Source 'Pollutant VOC 0.2023 Ib/bbl 68.31 tpy 3.42 tpy AP -42 NOx 7.06E-04 Ib/bbl 0.79 tpy 0.79 tpy TNRCC CO 2A1E-03 lb/bbl • 1.41 tpy 1.41 tpy TNRCC Benzene 2689E-03 Ib/bbl 1815 lb/yr 91 lb/yr Mass Balance Toluene 7.452E-03 Ib/bbl 5032 lb/yr 252 lb/yr Mass Balance Ethylbenzen. 5.552E-04 Ib/bbl 375 lb/yr 19 lb/yr Mass Balance %ylenes 5.633E-03 Ib/bbl 3804 lb/yr 190 lb/yr Mass Balance r -Hexane 1.447E-02 Ib/bbl 9770 lb/yr 488 lb/yr Mass Balance 2,2,4-TMP 1.072E-05 Ib/bbl 7 lb/yr 0 lb/yr . Mass Balance Actuel Emissions Pollutant . Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.2023 lb/bbl 0.00 my 0.00 for AP -42 NOx 7.06E-04 lb/bbl 0.00 toy 0.00 toy AP -42 CO ' 2.31E-03 Ib/bbl 0.00 con 0.00 toy AP.42 Benzene 2639E-03 Ib/bbl 0.00 lb/yr 0.00 lb/yr Mass Balance Toluene 7.452E-03 Ib/bbl 0.00 lb/in 0.00 Ito/yr Mass Balance Ethylbentene 5.552E-04 Ib/bbl 0.00 lb/yr 0.00 lb/yr Man Balance Xylenes 5.633E-03 Ib/bbl 0.00 lb/yr 0.00 lb/Yr Mass Balance n-Houane 1.447E-02 Ito/bbl 0.00 lb/yr 0.00 lb/yr Mass Balance 2.2.4-TMP 1.072E-05 Ib/bbl 0.00lb/yr 0.00 lb/yr Man Balance Section 06 - Recursion, Anelydq FKisliOon 1- Pertlmrbte. Smoke, Cirbon Monoxide end Sulfur. Dioxide Uncontrolled Itpr) Controlled (tpy) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source Miring periods of startup, process modltbotbn, or adjustment of control equipollent visible emissions shall not exceed 30% opacity for more than sit minutes in any stray consecutive minutes. Section IA - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source sudr es to result In detectable odors which are measured in excess of the following units: Forareas used predominantly for residential or commerdal purposes it b dolatbn 0 odors are detected after the edoroe ak has been diloted with seven (7) or volumes o/ odor free air. No is Mb site considered en eapbretbn end produxon baton (.4 well pad)? If yes, mow the following two exemptions for applicability) Dom the op.nbr unload its than 10,000 gallons (238 BBts) per dry of [rude a0 on an ann.el maraca basis? If yes, this emissions point is otaewbliy exempt from permit requirements per Reeularon 3. Part B. Sectlen 11.0.13 Does this opunetor soloed less then 6,750 bbb per yes of condensate via splash fi0 or 16,307 bbb per year of eedenate ole submerged MI procedure? If ye. this *Makin pole b ategeriolly exempt from permit requirements per Regulation 3, Pan B, Section II.D.1J Pert A-APEN Requirements Criteria Pollutants: For criteria po0utants, Air Pollutant Emission Notices am required for: each individual emission point Ina non -attainment area with uncontrolled actual embsbns of one ton per year or more of any individual criteria pollutant (polutanb are not summed) for which the area is non - attainment. Applicant is required to file an APEN shse. omissions caned 1 ton per per VOC Pert B—Csnsbuctbe Penult Exemptions Appliont Is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TRY threshold (Reg. 3, Part B, Section 11.02a) Part B,10.0.2- PACT requbw.rsb for new or modified minor sources This section of Regulation 3 requires RACE for new or modlrbd mbar sources bated In nonattalnment or attainment/maintenance area This source is bated in the 6 -hour ozone nonattabment area, but not the 1 -hour ozone area. The date of Interest for determining whether the source Is new or modified b therefore November 20. 2007 'the date of the ihour ozone NA area designation). Since the tank battery from which loadout is occurring came Into service after the data above, this source is considered 'new or modified.' New storage vessels will be constructed upon bsuena of this permit. Operator b using submerged ml, and controlling emissions via enclosed combustor. Therefore, PAR requirements ere satisfied. • Jteeri.ebn 7—Yolatle Oraank Ce rounds � -:... : .... � ' __ No section epply. Per Regulation 7, Section VI.C, a terminal and a bulk plant are defined as a paroiaum liquid storage end distribution facllty that has a deity aveap throughput of more than 76,000 liters of pso0n. (20,000 plans), which is loaded directly Into transport vehicles. TM %dirty b neither termind bulk pWrt par deOnhlaa,M Reg7 Section VI G RaeubHvn 8- "444d.. AIr Pofiutenb ..:.::.:.......:....—.............-,.-....i« ...: ,,. r.. ...w...e....... �:�.,..—...- ....::..,:....-_—...:....:::......-,--......a...:_...:,.:..::..... PACT (FEE: This subpart apple to organic liquid distribution operations (OLD operations). Per 63.2334, you are subject to this subpart If you own or operate an OLD operation that is located at, or Is part of, a major sure of HAP emissions. Furthermore, this section identifies that OLD operations do not Include the activities and equipment, Including product beding arks, used to proms, store, or transfer orpnk liquids at 'dl and natural gas production field • fad5tie, es the term 'facility" be defined in 63.761 of subpart NH. EPA has confirmed that natural ps processing plants are Included In the definition of 'natural gas production field facilities' for the purposes of this subpart. Therefore, this source is not subject to this subpart. Hydrocarbon Loadout Emissions Inventory Section 07 - Technkel Anebab Notes 1 The samPleuxdd t estim t M MAP "1 b fr thie . t t 'obwl ed fr the M b m gas plan[ on Mardi 11 2009. This sample results lo mast haabni that arc more miuenative (i.e: greacer.M )chase approved) iw .nrt4 Since ih4co po Itlon wlllbe ery Unifier to hat mrepresented for Point 004 It wag determined Mt -a' a sample would not be required to 'establlM new a Isslcri factors. .:. -:, �� . :: ...• 3. In" rider to alcubtocornb do emissions;operatohcalculated the volume vented during loadoutoporatlo Bust gth Ida 1p I (PV nOT) The values used fn thiscaloxiation are as foil (I) (166:16 ton/yea ) (]000Ib/ton) (Sib-mol/66(b)...1035151p+noi/yn i (II)P, !,,(141T.= 512.15 R (52FI (hl) N =,10.731 psW'R^3/9 lb -tool •.. .: V (5035.151Dnro1/y ): (10.731 ps1 R^3UR Ih-nrol)'(51245R)/11212 POI) 2,284,554ft 3/y In orderto cilcufaie the lame vented• theoneritor Utilised actual conditioni of to penro (52F) and pressure' (12;12 pdal• Typically, the vol eidd ih need to be rmd to standa 016dsofte peatore andpezte :mss b doneWll ingthe•rambl edge lawwhich sttes:(Piml)/.TIe (p2'V2)/T2- Using this. egatlo' Iong with the Standardtemperetere (607)and •pr'etture (34.7 pda); the volume vetoed would hm been;detemti ed to he th following::' � �:; " � ' � � �• ;" ' � VS (,((12.12 yzla)'(2,2045540 3/year)!(519676(1/5512450) (147psha)1 1;9130 id/yea . . e .. ..10, i. .Sinthe actual standard vented using them pined g slaw � less nserva[Ive dun ha'op teratw estimated actual volume, Me'arxual volume is an estimate:: .. .. ...... o... °parer° determined Meh at value.usedl 660dombustlon akrwulatl ih u gh int rpol 'Bi'sedm Me auumed RVP, of 10 [tie,mrrezpondin{ 1 id me1gM (M W) ai Aete 1 ed be 661b/Itrmal based diief.42 Ch pt 7:Tible 7 1 2'Bued onthls molecular weight it was rimmed theeet m tent of the gas would fait between that of Butane (ad.W a 58.1221b/IDinol Content >' 3;262.4 Bte/ed) and Pentane (MW 72149 (b/Itimot Neat Content 40009 Bto/uf) Ush[gt!Ii leoWarweighesrld r.u,a.eri1oI 6utane'and Pemano; tie operaror nterpotated Me" '[[ heat Phitenf of ttie Waite gas to be 3,677 etu/sd Oh heat content is the grove heat vat a (LW high r heatiri{ fuel which ie more conservative than the net heel value.(( lower ha dng value). The TNRCC document spedhnlN Identlfloe Meuse to the net heat value for NM and CO emissions v0lctdatlmi: A h the use of the grow heat value here is ceeptable co floe). : 5 7he.NOaend CO emissions ereefddetedusina the emltt(nv factoec factors how the TNRCCThnial Supplement). Flares.Th tooled toot to tedare 0138'0/MMBtu and 0.54% M Ib/MBtu far NOi and W e pec1y: ISased on 66e'di><umenf, file emission ledtor Utilised for CO is for ilr/unaiilsted (Iarn wIM a azte gas :tram 'diet has a IOW em content Th¢ doormen[ dlfltus IOW OW :content as 392-1;000 etu/sd Terh lony,th¢ waste gaiavouid De tlasilhed as high ate ,,.®riding to this document since the wa Ste Ps heat content was estynated.tO he 3,677 Btu/sd; however, the :.: emission hdor prodded for low Btu U more conservative than the emission furor provided Tor, high Btu (0.2755IWMMBtu) "MSS result, the b mri e peretorestimatn of emissions servithreand therefore aaropteb(e ..., .: :; ... .. ..... .... ... 6. The TNRCC emissions faaore for Boo and CO iosed tar mate gri m bueu n) converted ho Ib/MMBtu t ib/bht usng the blowing aIoei 6 u:' p)Ceiculatoga0-co-od(yai)raf (2304554eo1/y ((19 /1642500nhp 13909ut/bw :; ' "...J; ... °: (IQ Convert from ib/MMBm to lb/ tbl :..:.. (a)NOY( roibIb/MMBro)'(3677 MMBtu/MMd) (I MMsd/1000000 fd)'1-3909 sd/btl)=0.00071 m/htl' (1.) "CO = (05496 Ib/MM&u)'(3677 MMBtu/Mbl .. .. ..• . . so(l: (1 MMia/1,000,OOo td)'11.3939.sd/btiil'.a.omll m/DDI ,,7.,The operator did hat °Old:date flPernIsilOns attoei tad with the mtidstla boadoUt and hohide to ianir that ire. routed hiend tl trolled M the endoeed here The perotoWicked! I that d no the endosed flare U designed to be if s k leee,nomb stto devihe perttmiate rnattee bbielP,ected tobe generated from the mmbusttonbf m d to tank ne loedoet mete g.e .routed toarid mm Iled by the hare.• .' .> .,_� :�,: � .'' .: ..... �.. .. :'::• 5 .. . _ I orde : to aEdress ifds Statement, tlx emhsb factor Bourn for combustion emiulom (NOB end CO)' AP -a2 Owpte 13.5,, � { may ... evlemed.mbdoamenteapresse [he.'emlttlo lrminadn Dirlude carbon parUdes (soot), mbumed hydroarbons; CO WWI Pitted./ tamed and altered hytronrtions: Alto eMtted are i[ropn'oaldes (Noel and'; if wlfur containing materfal suds as hydroge .sulfide a mernPtans li Mired, sulfur. diedde 502).' Based m this t t 'men). the d mint d 'i' t r . ( _.., provide i brmatlon with egards co particvlate ' aaer aieptwah rcprds ro rood: The dom nent Nr[he proWdei theta okingharc directly result I soot for"mitlon he alt Stites Tha,teiidenq ai a fueItosmoke" m to snot Is Nhuennd by NN tiiaracterltW and Oil the amount ', • and distribution of oxygen In the combustion cone Thls is huller supported by footnote., c':'• below able 135 3 which provides thNRowl g Soot Inconcentration vetoes rtommoldngMaro 0 mlcograrm per liter . . , (ua/11; IlghtN smoking naves, 40 D6/L iverage smokiiq hares, 177 µg/l; and heavily srnokingflarei, 274 pg/L ;: At chit ume Mere la not snotherource a eta that q antlM •• PM10 or PM2.5 from Indeotd l Mares and thereore it will be a umed that the mN source of wrticu4te matttt trout a Mre b toot from smoke as expreisetl M AP32 Chapter 135 d ft should be noted tlutthe OdM pia' requires that dell Nidw be conducted to determine It the endosed Mrc Is smoking. If whole¢ b observed dodos tha,daity Bieck Me source Is egiiircd m either mndud a method 22 or immedts[e .shut in the W i d .. N ... q Pmentto invmdpte the aus¢ofiha,zmok all conouct epairsmru:cessary., based on this eq IrememN the ¢ndosedh re .ti.the:l manufacture design torthe enclosed Mere to ba smokeleii It operi[ed Drgp dy Ira 'safety be ¢swnied M t the endosed ha a win operate with° t imok an a regular. Psis,. Also, if smoke % bserved; the opemmr.will he eq bed m is M biem nd do.nq.nor . • .. e.,. pr pe ry rnaNte nn to prevent the enclosed Ma ham smoking -As such; I am mmfoRible assuming a cot m tradon of 0 m grams pe lite as provided I AP -42 Chapter 135 for nonsmoking Mares. r" If the.totat PMernisilon facto of 7 6 ib/MMsd fron, 0, pte 14 reused, die total PMeinissioni (for both PM 10 a d 25) woud he below APEN thresholdAt sod1, the emkslons would not It in permit Iknla to PM uR I addltb I regulatory ragas n[i :. Based an the) f atl dhurs ed bone;itwii.defeihifbid thatthe operator' asurtlonthat °tales: Marcwotdd not ee pettedtoh ve PMemissbnssates v.11d. However, n '6etier dm is .. developed in "the fut eforetl atlngPas :ernisilOns from'Gdoelrisl fares; itsnouid heinduded infumrean lyres , B 9n¢ this loadeixt oderation has isnobinroiled.VOC ZD. tpy peretlon arras s :nonaolusing an;eeolosed combutor.he been determined to satisfy RACT.: ; "'" " "' "•"• 9 dirt./13/2.018.O.CFfiutiniltted eppl(ation reti I this indoded Chingeihe thi P Inc: OCP.Iricikates that they h ve reallied theneccessity..foh:TUelPiX.for the ndosed mmbutto "receiving gas fro this s u (t62) Slnre th mbustor My i i ga �ro Me l0ada t, It alio hai,ilbel eq I me t b d t pt.A0 a esua emiulo s fro'mromb tl f isiiit gm were added to this , point and a Nei Ilmtt(aiilst gm+pilot fuel) was included fc`r Me enclosed <ombutor. In aoditbn, OCP fret reduced [Ire requested chrou{liput from 1 6x2,500 plot m 675,250 bbl. OCP iridlatm that the., voome loaded will be limited by inaease. use of'UC7''pipellne badout " • 10. As menib ed above, load° t of mndeniite mfr °tours via this ocesi when the tACT. peune loadoot h uneva0able lout " ., p pl ages or issues) Since too N to.momh basis mcnthty limps wig not be ind.ded:for this emissioripoint. A monthN Ilrnit Is Incliided for TANKS -2 (point of l) Section OS • bwntare SCC Cedine end Emission Factor% AIRS Point 020 Process a SCC Code 01 14.0600132 crud:at 5ubmwiad twdkia(Normal SentiigtP4.9'7a7`M" `°.+7'� Uncontrolled Emissions Pollutant Fecor Control % PM60 401F+ QOM AMP,' 4044 0404 NO. 1.68E-02 0.00% VOC 4.817 95.00% CO 6.69E-02 0.00% Benzene 6.40E-02 95.00% Toluene 1.77E-01 95.00% Ethylbenzene 1.32E-02 95.00% Kylene 1.34E-01 95.00% n -Haan 3.44E-01 95.00% 224 TMP 2.55E-04 95.170% Untb b/1,000 gallons condensate throughput b/1,000 gallons condensate throughput b/1,000 gallons condensate throughput b/1,000 gallons condensate throughput 6/1,000 gallons condensate throughput b/1,000 gallons condensate throughput b/1,000 gallons condensate throughput b/1,000 gallons condensate throughput b/1,000 gallons condensate throughput Summary of Project Emissions DCP Operating Company, LP O'Connor 2 Gas Plant Permit# 11WE1481 AIRS ID 123/9012 • PTE - WITH ENFORCEABLE CONTROLS (TM Equipment Description TSP I PM10 • H2S SO2 I NOx VOC PM2.5 I Fug VOC CO Modifications, with this Issuance, (change from existing permitted emissions) Point 004 (Loadout) - - - - 0.39 0.03 - - 0.50 Point 005 (condensate tanks) - - - - - (0.45) - - - Point 008 (PW tanks) - - - - - 1.74 - - - Point 009 (Plant flare) - - - (0.10) (4.30) (10.20) - - (12.50) New Equipment withthis ssuancez a._..,-�•._,_ Point 010 (Plant Flare) 0.01 0.01 - 0.03 4.66 28.09 0.01 - 20.94 Point 011 (Condensate Tanks) - - - - 0.00 0.08 - - 0.01 Point 012 (Fugitives OOOOa) - - - - - - - - 21.52 - Point 013 (Turbine) 1.87 1.87 - 1.09 12.70 0.67 1.87 - 17.61 Point 014 (Turbine) 1.87 1.87 1.09 12.70 0.67 1.87 - 17.61 Point 015 (HT -01) 0.14 0.14 - 0.02 1.36 0.15 0.14 - 2.28 Point 016 (HT -02) 1.06 1.06 - 0.12 10.09 1.11 1.06 - 16.96 Point 017 (AM002) - - 0.98 31.31 1.33 10.29 - - 6.06 Point 018 (D-01) - - 0.00 0.00 0.04 1.01 - - 0.18 Point 019 (UL -1) - - - - - 8.45 - - 1.41 Point 020 (LO -2) 0.04 0.04 - - 0.79 3.42 0.04 - 1.41 Wet ProjectIncrease,,_,_ ,. 4 95 '= _._ O 98 33.55 ,;38 98 4163' 4 4;95 21,52 71.07: Modeling thresholds Major Source Thresholds 250 250 15 40 40 250 100 100 250 5 100 250 COLORA AIR POLLUTION.CONTROL DIVISION TELEPHONE: (303) 692-3150 COLORADO D ENS MENT CONSTRUCTION PERMIT PERMIT NO: 11WE1481 E1481 Issuance 5 DATE ISSUED: ISSUED TO: DCP Operating Company, LP THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural gas processing facility, known as the O'Connor Plant, located in Section 31, Township 5 North, Range 64 West, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description AM001 001 Natural gas sweetening system using a solution of Methyldiethanolamine (MDEA), process feed gas design rated at 160 MMSCF per day, and an amine recirculation rate of 780 gallons per minute. This system consists of: natural gas amine contactor, amine flash tank, and amine regenerator (heating unit under AIRS PT ID: 123/9012/002). Emissions from the acid gas stream are routed to the sales line or to a regenerative thermal oxidizer (RTO) with a destruction efficiency of 95%. Emissions during permitted 3% annual RTO downtime will be vented to atmosphere. Emissions from the flash tank stream are routed back to the plant inlet with a vapor recovery unit (VRU). Emissions during permitted 5% annual VRU downtime will be routed to plant flare (point 009 or 010). H-0886 002 Hot oil heater (Optimized Process Furnaces, SN: J121092)) rated at 47 MMBtu/hr that heats oil for several processes within the gas plant. H-0286 003 Regenerative heater (Optimized Process Furnaces, SN: J121091) rated at 8.80 MMBtu/hr used for molecular sieve regeneration. LO -1 004 Loadout of stabilized condensate to tank trucks. Emissions are controlled by an enclosed combustor (John Zink, VC -9127791) with a control efficiency of 95%. TANKS 005 Four (4) tanks, 400 bbl each, for storage of stabilized natural gas condensate. Emissions are controlled by an enclosed combustor (John Zink VC -9127791) with a control efficiency of 95%. AIRS ID: 123/9012 Page 1 of 60 NGEngine Version 2009-1 DC Permi LP 48 Co ado De nd Environment Control Division jiSriPti7 FUG 006 Equipment leaks (fugitive VOCs) from a natural gas processing facility. Emissions are minimized by Leak Detection and Repair Program per 40 CFR Part 60 Subpart OOOO or 40 CFR Part 60 Subpart OOOOa. H-0887 007 Hot oil heater. (Optimized Process Furnaces, SN: J121108) rated at 25 MMBtu/hr that heats oil for several processes within the gas plant. FLARE 009 Plant flare with a VOC destruction efficiency of 95% to control emissions from maintenance and malfunction events. FLARE -2 010 Plant flare used for blowdowns,maintenance and malfunction events. Device is used to control emissions from point 001, 004, 005, 017 and 018 during primary control device downtime. TANKS -2 011 Four (4) tanks, 1,000 bbl each, for storage of stabilized natural gas condensate. Emissions are collected via VRU and recycled to the plant inlet. During VRU downtime emissions are routed to an enclosed combustor. FUG -2 012 Equipment leaks (fugitive VOCs) from a natural gas processing facility associated with O'Connor 2. Emissions are minimized by Leak Detection and Repair Program per 40 CFR Part 60 Subpart OOOOa. TURB-1 013 One (1) Solar, Taurus 70, natural gas fired combustion turbine (SN: TBD), rated at 66.38 MMBtu (LHV)/hr heat input and 9,071 horsepower (HP). This is equipped with Dry Low NOx combustion system for minimizing emissions of Nitrogen Oxides. TURB-2 014 One (1) Solar, Taurus 70, natural gas fired combustion turbine (SN: TBD), rated at 66.38 MMBtu (LHV)/hr heat input and 9,07-1 horsepower (HP). This is equipped with Dry Low NOx combustion system for minimizing emissions of Nitrogen Oxides. HT -01 015 One (1) Heatec (Model: TBD, SN: TBD) natural gas fired regeneration heater. The heater is design rated at 9.3 MMBtu/hr. The heater provides heat for mole sieve regeneration. This heater is equipped with a low NOx combustion system. HT -02 - 016 One (1) Heatec (Model: TBD, SN: TBD) natural gas fired hot oil heater. The heater is design rated at 48.4 MMBtu/hr. The heater provides heat for the condensate stabilizer. This heater is equipped with a low NOx combustion system. AIRS ID: 123/9012 Page 2 of 60 DC Perm' LP Col # ado De nd Environment Control Division acility y uipme All Po S %t1 D s ripti•a z `> AM002 017 One (1) Methyldiethanolamine (MDEA) natural gas sweetening unit (Make: TBD, Model: TBD, Serial Number:. TBD) with a design capacity of 230 MMscf per day. This emissions unit is equipped with three (3) (Make: TBD, Model: TBD) electric driven amine recirculation pumps with a total limited capacity of 945 gallons per minute of lean amine. Only two (2) amine recirculation pumps will be operated at any given time. The third amine recirculation pump serves as a back-up only. This amine unit is equipped with a natural gas/amine contactor, reflux condenser, flash tank, still vent and amine regeneration reboiler. Emissions from the flash tank are routed directly to a Vapor Recovery Unit (VRU) that recycles emissions back to the plant inlet. The VRU has a maximum of 3% annual downtime. During VRU downtime, flash tank emissions are routed to the plant flare covered under point 010. The acid gas stream from the still vent is routed to a reflux condenser and then to a regenerative thermal oxidizer (RTO) with a VOC destruction efficiency of 96%. During RTO downtime, emissions from the still vent are vented to the atmosphere. The RTO has a maximum of 2% annual downtime. D-01 018 One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: TBD, Model: TBD, Serial Number: TBD) with a design capacity of 230 MMscf per day. This emissions unit is equipped with two (2) (Make: TBD, Model: TBD) electric driven glycol pumps with a limited total capacity of 40 gallons per minute. This dehydration unit is equipped with a still vent and glycol flash tank. Emissions from the still vent are routed to an air-cooled condenser and subsequently to a vapor recovery unit (VRU) that recycles the emissions back to the plant inlet. Emissions from the flash tank are routed directly to the VRU. During VRU downtime, the still vent and flashtankstreams are routed to the plant flare (point 010). UL -1 019 Pressurized raw condensate unloading. LO -2 020 Loadout of stabilized condensate to tank trucks. Emissions are controlled by an enclosed combustor (John Zink, VCD-90127791) with a control efficiency of 95%. Point 013 and 014: This turbine may be replaced with another Solar, Taurus 70 turbine rated at 9,071 HP in accordance with the temporary turbine replacement provision or with another Solar Taurus 70 turbine rated at 9,071 HP in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Point 018: The glycol pump may be replaced with another pumpof the same design capacity in accordance with the provisions of the Alternate Operating Scenario (AOS) included in this permit as . Attachment B. AIRS ID: 123/9012 Page 3 of 60 LP ,,, Col 3 ado 'sA1/2d,- n'" _ -"nd Environment utioControl Division THIS aE' MIT IS NT ED SU = CT T • LL RU AN' ' GULATIONS OF THE COLORADO AIR QU OL ASS 9 ►® .► ..THE, .- .e +x•..: IR POLL I,QN PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. Points 010 - 020: 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 I II.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) after commencement of operation, compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. Points 013 - 016: 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. • manufacturer _ • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation Number 3, Part B, III.E.) 5. Point 017 and 018: 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 manufacturer name, model number and serial number • The recirculation 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.) 6. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Reference: Regulation No. 3, Part B, Section III.E.) AIRS ID: 123/9012 Page 4 of 60 DC Pei 7. LP Cola ado De� =: ed truct per lut milo. 11 ► 481 it eompleti he oper tor s o ` of • _, d on . al the per ®��A�. . authoni sIf- c icatio with h - most lone _ pro _ • e • airciii iss con b io r etter current . rity fort nd Environment oControl Division y the Division after on permit. This ition of this source. EMISSION LIMITATIONS AND RECORDS 8.. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Monthly Limits: - Facility Equipment ID AIRS Point Pounds per Month Emission Type - PM2.5 PM10 Sox H2S NOX VOC CO FUG -2 012 --- --- --- --- --- 3,656 --- Point TURB-1 013 318 318 --- --- 2,158 -- 2,991 Point TURB-2 014 318 318 --- -- 2,158 -- 2,991 Point HT -01 015 25 25 --- --- 231 --- 388 Point HT -02 016 180 180 --- --- 1,715 189 2,881 Point AM002 017 --- --- 5,318 167 226 1,749 1,029 Point D-01 018 --- --- --- --- --- 172 -- Point UL -1 019 --- --- --- --- --- 1,436 -- Point Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type pM2.5 PM,() SOx H2S NOx VOC CO AM001 001 -- --- 29.7 1.3 1.2 23.4 5.5 Point H-0886 002 --- --- --- --- 11.2 1.2 18.9 Point H-0286 003 --- --- --- --- 2.1 --- 3.5 , Point LO -1 004 --- --- --- --- --- 3.2 --- Point TANKS 005 -- --- --- --- --- 1.7 -- Point FUG 006 --- --- --- --- --- 38.8 --- Fugitive H-0887 007 a --- --- --- --- 6.0 --- 10.0 Point FLARE 009 --- --- --- --- 4.3 10.2 . 12.5 Point AIRS ID: 123/9012 Page 5 of 60 nd Environment Control Division. Fa Equi it Alftns , t Emission Type perfEar OX O VOCE O - CO . .: �.. r��, ., . .. ,.?. �� FLARE -2 010 --- — -- 4.7 28.1 20.9 Point TANKS -2 011 --- -- — -- --- 0.1 --- Point FUG -2 012 — — — — — 21.6 — Fugitive TURB-1 013 1.9 1.9 -- --- 12.7 — 17.6 Point TURB-2 .014 1.9 1.9 — -- 12.7 -- 17.6 Point HT -01 015 0.1 0.1 ' — -- 1.4 . — • 2.3 . Point HT -02 016 1.1 1.1 — — 10.1 1.1 17.0 Point AM002 017 -- --- 31.3 1.0 1.3 10.3 6.1 Point D-01 018 — -- — — — 1.0 -- Point UL -1 019 — — — -- — 8.5 --- Point LO -2 020 — --- --- -- -- 3.4 -- Point See `Notes to Permit Holder #4 for information on emission factors and methods used to calculate limits. During the first twelve (12) months after issuance of this permit, compliance with both monthly and annual emission limitations shall be required. After the first twelve (12) months after issuance of this permit, compliance with only the annual limitations shall be required. Compliance with the annual 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 actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 9. Point 001 and 017: Compliance with the emission limits in this permit shall be demonstrated by running the Promax simulation model or Division -approved software model on a monthly basis using the most recent amine unit inlet extended sour gas analysis and recorded operational values including: sour gas throughput, lean amine strength, lean amine recirculation rate, VRU downtime, RTO downtime, flash tank temperature and pressure, and sour gas inlet temperature and pressure. Recorded operational values, except for plant inlet gas throughput, shall be averaged on a monthly basis for input into the Promax simulation. Compliance with emission limits shall be demonstrated by utilizing the acid gas composition, flash gas composition, flashgas volumetric flow from the Promax simulation and the metered acictgas volume to the RTO. 10. Point 006 and 012: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas AIRS ID: 123/9012 Page 6 of 60 DC' �� , LP _a�CoI ado De Permi nd Environment Control Division pling s - ion of this permit. The ponent cou is and sampling events at thes owatts and events were completed. These records shall be provided to the Division upon request. 11. Point 018: Compliance with the emission limits in this permit shall be demonstrated by running the GRI GlyCalc model version 4.0 or higher on a monthly basis using the most recent extended wet gas analysis and recorded operational values, including: total actual gas throughput, lean glycol recirculation rate, vapor recovery unit (VRU) downtime, flash tank temperature and pressure, wet gas inlet temperature, and wet gas inlet pressure. Recorded operational values, except for total actual gas throughput, shall be averaged on a monthly basis for input into the model and be provided to the Division upon request. 12. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation Number 3, Part B,Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled AM001 001 Still Vent: Routed to regenerative thermal oxidizer (RTO) VOC & HAP Flash Tank: Recycled to plant inlet via VRU. Routed to plant flare during VRU downtime LO -1 004 Enclosed Combustor During Combustor downtime, emissions are routed to the plant flare (Point 009. or Point 010) VOC & HAP TANKS 005 Enclosed Combustor. During combustor downtime, emissions are routed to the plant flare (point 009 or point 010) VOC & HAP TANKS -2 011 Recycled to plant inlet via VRU. Routed to enclosed combustor during VRU downtime VOC & HAP AM002 017 Still Vent: Routed to regenerative thermal oxidizer (RTO) VOC & HAP Flash Tank: Recycled to plant inlet via VRU. Routed to plant flare (point 010) during VRU downtime. D-01 018 Still Vent and Flash Tank: Recycled to plant inlet via VRU. Routed to Open Flare during VRU downtime VOC & HAP 'LO -2 020 Enclosed Combustor. During combustor downtime, emissions are routed to the plant flare (point 010) VOC & HAP AIRS ID: 123/9012 Page 7 of 60 nd Environment Control Division folio _ maitnum process' "g' rates as listed below. recore - . - . ess 1 e maint- - : the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment ID . AIRS Point . Process Parameter Annual Limit Monthly Limit (31 days) AM001 001 Natural gas throughput 58,400 MMscf --- Natural gas processed during VRU downtime 2,920 MMscf -- Still vent waste gas (acid gas) vented to the atmosphere 40.89 MMscf — H-0886 002 Consumption of natural gas as a fuel 449.0 MMscf -- H-0286 003 Consumption of natural gas as a fuel 84.1 MMscf — LO -1 004 Throughput of stabilized condensate 638,229 Barrels — Tanks 005 Condensate throughput 638,229 Barrels -- H-0887 007 Consumption of natural gas as a fuel 238.82 MMscf -- FLARE 009 volume (waste gas and fuel gas 92.7 MMscf — FLARE-2 010 Combustion of waste gas and purge gas 107.13 MMscf -- Combustion of pilot fuel ' 1.71 MMscf --- TANKS -2 011 Condensate throughput 1,642,500 Barrels 139,500 Barrels Condensate throughput during VRU downtime 32,850 Barrels — TURB-1 013 Consumption of natural gas as fuel 609.18 MMscf 51.74 MMscf TURB-2 014 Consumption of natural gas as fuel 609.18 MMscf 51.74 MMscf HT -01 015 Consumption of natural gas as fuel 54.31 MMscf 4.62 MMscf HT -02 016 Consumption of natural gas as fuel 403.79 MMscf 34.29 MMscf AM002 017 Natural gas processed 83,950.00 MMscf 7 130.00 MMscf Natural gas processed during VRU downtime 2,518.50 MMscf --- Still vent waste gas (acid gas) vented to atmosphere 47.80 MMscf — 018 Natural gas processed 83,950.00 MMscf 7 130.00 MMscf AIRS ID: 123/9012 Page 8 of 60 DC Permi , .LP Col ado De nd Environment Control Division �. atural g a a s d during grhul679.00MrAscf U dow e --- -1 0.19 P nloa 8,76e36.4s3 a4 744 loads LO -2 020 Throughput of stabilized condensate 675,250 Barrels --- Combustion of pilot light fuel in enclosed combustor 0.53 MMscf --- Combustion of assist gas in enclosed combustor 10.51 MMscf -- 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. 14. Point 001: This unit shall be limited to the maximum lean amine recirculation pump rate of 780 gallons per minute. The lean amine recirculation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. Amine recirculation rate shall be monitored by one of the following methods: assuming maximum design pump rate or using amine flow meter(s).(Reference: Regulation No. 3, Part B, II.A.4) 15. Point 001: The owner or operator shall monitor and record VRU downtime for this emission point on a daily basis. VRU downtime shall be defined as times when the waste gas vented from the amine unit flash tank is routed to the open flare (point 009 or 010) rather than the VRU. The total hours of VRU downtime, total volume of gas processed and total volume of gas processed during VRU downtime shall be recorded on a monthly basis. The owner or operator must use monthly VRU downtime records, monthly records of gas processed, and monthly records of gas processed during VRU downtime to demonstrate compliance with the process limits contained in this permit. 16. Point 001: The owner or operator shall monitor and record regenerative thermal oxidizer (RTO) downtime for this emission point on a daily basis by use of RTO run status. RTO downtime shall be defined as times when the waste gas from the amine unit still vent (acid gas) is vented to the atmosphere. The total volume of acid gas vented to the atmosphere shall be continuously metered and recorded on a monthly basis. The owner or operator must use monthly records of acid gas vented to the atmosphere to demonstrate compliance with the process limits contained in this permit. 17. Point 009 and 010: The owner or operator shall continuously monitor and record the total volumetric flow rate of process/waste gas and purge gas routed to the flare using a flow meter. The owner or operator shall use monthly throughput records to demonstrate AIRS ID: 123/9012 Page 9 of 60 nd Environment Control Division rmit and t calculate emissions as 18. Point 011: The owner or operator shall monitor and record VRU downtime for this emission point on a daily basis. VRU downtime shall be defined as times when the waste gas vented from the storage tank is routed to the enclosed combustor. The total hours of VRU downtime, total condensate throughput, and total throughput during VRU downtime shall be recorded on a monthly basis. The owner or operator must use monthly VRU downtime records, monthly records of throughput during VRU downtime, and the emission factors established in the Notes to Permit Holder to demonstrate compliance with the process and emission limits specified in this permit. 19. Point 013 and 014: The owner or operator shall continuously monitor and record volumetric flow rate of natural gas combusted as fuel for each turbine using an operational continuous flow meter at the inlet. The owner or operator shalluse monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. 20. Point 015 and 016: 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 emission as described in this permit. 21. Point 001, 017 and 018: The volume of gas processed shall be measured by gas meter. 22. Point 017: This unit shall be limited to the maximum lean amine recirculation pump rate of 945 gallons per minute. The lean amine recirculation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. Amine recirculation rate shall be monitored by one of the following methods: assuming maximum design pump rate or using amine flow meter(s (Reference: Regulation Number 3, Part B, II.A.4) 23. Point 001 and 017: On a weekly basis, the owner or operator shall monitor and record operational values including: flash tank temperature and pressure and sour gas inlet temperature and pressure. These records shall be maintained for a period of five years. 24. Point 017: The owner or operator shall monitor and record VRU downtime for this emission point on a daily basis. VRU downtime shall be defined as times when the waste gas vented from the amine unit flash tank is routed to the open flare (point 010) rather than the VRU. The total hours of VRU downtime, total volume of gas processed and total volume of gas processed during VRU downtime shall be recorded on a monthly basis. The owner or operator must use monthly VRU downtime records, monthly records of gas processed, and monthly records of gas processed during VRU downtime to demonstrate compliance with the process limits contained in this permit. 25. Point 017: The owner or operator shall monitor and record regenerative thermal oxidizer (RTO) downtime for this emission point on a daily basis by use of RTO run status. RTO downtime shall be defined as times when the waste gas vented from the amine unit still vent (acid gas) is vented to the atmosphere. The total volume of acid gas vented to the AIRS ID: 123/9012 ' Page 10 of 60 DC Per ' mi • LP o. 11 481 Col ado De. l U 1 $ A it ` tmosph r sh II tinuousl .RL L =. and r vented r.eJ -fined on a mgr to the in t ,...p hly IN osphe a it. °a r opera m ....,., ate ise " o'thly r - .rds o Via id ga n - .roc- �l ..'tom nd Environment Control Division sis. The owner re to 26. Point 001 and 017: The owner or operator shall continuously monitor and record the volumetric flow rate of waste gas vented from the amine unit still vent using a flow meter. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. 27. Point 018: On a weekly basis, the owner or operator shall monitor and record operational values including: flash tank temperature and pressure and wet gas inlet temperature and pressure. These records shall be maintained for a period of five years 28. Point 018: The owner or operator shall monitor and record VRU downtime for each emission point on a daily basis. VRU downtime shall be defined as times when the waste gas vented from the glycol dehydrator flash tank and/or still vent is routed to the open flare rather than the VRU. The total hours of VRU downtime, total volume of gas processed and total volume of gas processed during VRU downtime shall be recorded on a monthly basis. The owner or operator must use monthly VRU downtime records, monthly gas processing records, and the calculation methods established in the Notes to Permit Holder to demonstrate compliance with the process and emission limits specified in this permit. 29. Point 018: 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.. (Reference: Regulation Number 3, Part B, II.A.4) STATE AND FEDERAL REGULATORY REQUIREMENTS 30. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable). 31. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.1. & 4.) 32. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) AIRS ID: 123/9012 Page 11 of 60 DC Fermi Amin 33. LP � -� Col ado De 481 nd Environment lutio :. Control Division esse 113,001 is stplaje:44o the New Source Performance Standards requirements o Regu ation No. 6, Part A, Subpart OOOO, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution including, but not limited to, the following: • 40 CFR, Part 60, Subpart A — General Provisions • §60.5365 — Applicability and Designation of Affected Facilities o §60.5365(g)(3) - Facilities that have a design capacity less than 2 long tons per day (LT/D) of hydrogen sulfide (H2S) in the acid gas (expressed as sulfur) are required to comply with recordkeeping and reporting requirements specified in §60.5423(c) but are not required to comply with §§60.5405 through 60.5407 and §§60.5410(g) and 60.5415(g). • §60.5423 — Record keeping and reporting Requirements o §60.5423(c) - To certify that a facility is exempt from the control requirements of these standards, for each facility with a design capacity less that 2 LT/D of H2 S in the acid gas (expressed as sulfur) you must keep, for the life of the facility, an analysis demonstrating that the facility's design capacity is less than 2 LT/D of H2 S expressed as sulfur. Heaters 34. Point 002, 007, 016: These sources are subject to the New Source Performance Standards requirements 'of Regulation No. 6, Part A Subpart Dc, Standards of Performance for Small Industrial -Commercial -Institutional Steam Generating Units including, but not limited to, the following: • 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)). • Monthly records of fuel combusted required under the previous condition shall be maintained by the owner or operator of the facility for a period of two years following the date of such record (40 CFR Part 60.48c(i)). 35. Points 002, 003, 007, 015 and 016: Each heater is subject to the National Emissions Standards for Hazardous Air Pollutants requirements of Regulation No. 8, Part E, Subpart DDDDD (40 CFR Part 63, Subpart DDDDD), for Industrial, Commercial, and Institutional Boilers and Process Heaters including, but not limited to, the following: • § 63.7495 When do I have to comply with this subpart? o (c) If you have an area source that increases its emissions or its potential to emit such that it becomes a major source of HAP, paragraphs (c)(1) and (2) of this section apply to you. o (c)(1) Any new or reconstructed boiler or process heater at the existing source must be in compliance with this subpart upon startup o (c)(2) Any existing boiler or process heater at the existing source must be in compliance with this subpart within 3 years after the source becomes a major source. AIRS ID: 123/9012 Page 12 of 60 nd Environment Control Division (d) You must meet the notification requirements in §63.7545 according to the schedule in §63.7545 and in subpart A of this part. Some of the notifications must be submitted before you are required to comply with the emission limits and work practice standards in this subpart. • § 63.7500 What emission limitations, work practice standards, and operating limits must I meet? o (e) Boilers and process heaters in the units designed to burn gas 1 fuels subcategory with a heat input capacity of less than or equal to 5 million Btu per hour must complete a tune-up every 5 years as specified in §63.7540. Boilers and process heaters in the units designed to burn gas 1 fuels subcategory with a heat input capacity greater than 5 million Btu per hour and less than 10 million Btu per hour must complete a tune-up every 2 years as specified in §63.7540. Boilers and process heaters in the units designed to burn gas 1 fuels subcategory are not subject to the emission limits in Tables 1 and 2 or 11 through 13 to this subpart, or the operating limits in Table 4 to this subpart. This unit is a new boiler or process heater in the units designed to burn gas 1 fuels subcategory. The work practice standards in Table 3 that apply to this unit are as follows: • Point 003, 015: Conduct a tune-up of the boiler or process heater biennially as specified in §63.7540. • Point 002, 007 and 016: Conduct a tune-up of the boiler or process heater annually as specified in §63.7540. Units in either the Gas 1 or Metal Process Furnace subcategories will conduct this tune-up as a work practice for all regulated emissions under this subpart. Units in, all other subcategories will conduct this tune-up as a work practice for dioxins/furans. (Table 3 to Subpart DDDDD, Item 3). • § 63.7505 What are my general requirements for complying with this subpart? o (a) You must be in compliance with the emission limits, work practice standards, and operating limits in this subpart. These emission and operating limits ,apply to you at all times the affected unit is operating except for the periods noted in §63.7500(f). • § 63.7510 What are my initial compliance requirements and by what date must I conduct them? o (g) For new or reconstructed affected sources (as defined in §63.7490), you must demonstrate initial compliance with the applicable work practice standards in Table 3 to this subpart within the applicable annual, biennial, or 5 -year schedule as specified in §63.7515(d) following the initial compliance date specified in §63.7495(a). Thereafter, you are required to complete the applicable annual, biennial, or 5 -year tune-up as specified in §63.7515(d). • § 63.7515 When must I conduct subsequent performance tests, fuel analyses, or tune-ups? o (d) If you are required to meet an applicable tune-up work practice standard, you must conduct an annual, biennial, or 5 -year performance tune-up according to §63.7540(a)(10), (11), or (12), respectively. Each annual tune-up AIRS ID: 123/9012 Page 13 of 60 DC Permi , LP Col ado De nd Environment Control Division specified in §63.7540(a)(10) must be no more than 13 . months after the previous tune-up. Each biennial tune-up specified in §63.7540(a)(11) must be conducted no more than 25 months after the previous tune-up. Each 5 -year tune-up specified in §63.7540(a)(12) must be conducted no more than 61 months after the previous tune-up. Fora new or reconstructed affected source (as defined in §63.7490), the first annual, biennial, or 5 -year tune-up must be no later than 13 months, 25 months, or 61 months, respectively, after April 1, 2013 or the initial startup of the new or reconstructed affected source, whichever is later. • § 63.7530 How do I demonstrate initial compliance with the emission limitations, fuel specifications and work practice standards? o (f) You must submit the Notification of Compliance Status containing the results of the initial compliance demonstration according to the requirements in §63.7545(e). • § 63.7540 How do. I demonstrate continuous compliance with the emission limitations, fuel specifications and work practice standards? o (a) You must demonstrate continuous compliance with the work practice standards in Table 3 to this subpart that applies to you according to the methods specified in Table 8 to this subpart and paragraphs (a)(1) through (19) of this section. o Point 002, 007, and 016: (a)(10) If your boiler or process heater has a heat input capacity of 10 million Btu per hour or greater, you must conduct an annual tune-up of the boiler or process heater to demonstrate continuous compliance as specified in paragraphs (a)(10)(i) through (vi) of this section. You must conduct the tune-up while burning the type of fuel (or fuels in case of units that routinely burn a mixture) that provided the majority of the heat input to the boiler or process heater over the 12 months prior to the tune-up. This frequency does not apply to limited -use boilers and process heaters, as defined in §63.7575, or units with continuous oxygen trim systems that maintain an optimum air to fuel ratio. ■ (i) As applicable, inspect the burner, and clean or replace any components of the burner as necessary (you may perform the burner inspection any time prior to the tune-up or delay the burner inspection until the next scheduled unit shutdown). Units that produce electricity for sale may delay the burner inspection until the first outage, not to exceed 36 months from the previous inspection. At units where entry into a piece of process equipment or into a storage vessel is required to complete the tune-up inspections, inspections are required only during planned entries into the storage vessel or process, equipment; • (ii) Inspect the flame pattern, as applicable, and adjust the burner as necessary to optimize the flame pattern. The adjustment should be consistent with the manufacturer's specifications, if available; • (iii) Inspect the system controlling the air -to -fuel ratio, as applicable, and ensure that it is correctly calibrated and functioning properly (you may delay the inspection until the next scheduled unit shutdown). Units AIRS ID: 123/9012 Page 14 of 60 DC Perm Cole ado De nd Environment Control Division elay thirspection until the first from the pre us inspection; s'' - .tal CO. Thization should be consistent with the manufacturer's specifications, if available, and with any NOx requirement to which the unit is subject; • (v) Measure the concentrations in the effluent stream of CO in parts per million, by volume, and oxygen in volume percent, before and after the adjustments are made (measurements may be either on a dry or wet basis, as long as it is the same basis before and after the adjustments are made). Measurements may be taken using a portable CO analyzer; and • (vi) Maintain on -site and submit, if requested by the Administrator, a report containing the information in paragraphs (a)(10)(vi)(A) through (C) of this section, • (A) The concentrations of CO in the effluent stream in parts per million by volume, and oxygen in volume percent, measured at high fire or typical operating load, before and after the tune-up of the boiler or process heater; • (B) A description of any corrective actions taken as a part of the tune-up; and • (C) The type and amount of fuel used over the 12 months prior to the tune-up, but only if the unit was physically and legally capable of using more than one type of fuel during that period. Units sharing a fuel meter may estimate the fuel used by each unit. o Point 003, 015: (a)(11) If your boiler or process -heater has a heat input capacity of less than 10 million Btu per hour (except as specified in paragraph. (a)(12) of this section), you must conduct a biennial tune-up of the boiler or process heater as specified in paragraphs (a)(10)(i) through (vi) of this section to demonstrate continuous compliance. o (a)(13) If the unit is not operating on the required date for a tune-up, the tune- up must be conducted within 30 calendar days of startup. • § 63.7545 What notifications must I submit and when? o (a) You must submit to the Administrator all of the notifications in §§63.7(b) and (c), 63.8(e), (f)(4) and (6), and 63.9(b) through (h) that apply to you by the dates specified. o (c) As specified in §63.9(b)(4) and (5), if you startup your new or reconstructed affected source on or after January 31, 2013, you must submit an Initial Notification not later than 15 days after the actual date of startup of the affected source. o (e) If you are required to conduct an initial compliance demonstration as specified in §63.7530, you must submit a Notification of Compliance Status according to §63.9(h)(2)(ii). For the initial compliance demonstration for each boiler or process heater, you must submit the Notification of Compliance AIRS ID: 123/9012 Page 15 of 60 DCLP Col ado De Perm Is and f ng the comp • nstratio nd Environment Control Division analyses, before the on of all performance I boiler, or process heaters at the facility according to §63.10(d)(2). The Notification of Compliance Status report must contain all the information specified in paragraphs (e)(1) through (8) of this section, as applicable. If you are not required to conduct an initial compliance demonstration as specified in §63.7530(a), the Notification of Compliance Status must only contain the information specified in paragraphs (e)(1) and (8) of this section and must be submitted within 60 days of the compliance date specified at §63.7495(b). o (e)(1) A description of the affected unit(s) including identification of which subcategories the unit is in, the design heat input capacity of the unit, a description of the add-on controls used on the unit to comply with this subpart, description of the fuel(s) burned, including whether the fuel(s) were a secondary material determined by you or the EPA through a petition process to be a non -waste under §241.3 of this chapter, whether the fuel(s) were a secondary material processed from discarded non -hazardous secondary materials within the meaning of §241.3 of this chapter, and justification for the selection of fuel(s) burned during the compliance demonstration. o (e) (8) In addition to the information required in §63.9(h)(2), your notification of compliance status must include the following certification(s) of compliance, as applicable, and signed by a responsible official: ■ (i) "This facility completed the required initial tune-up for all of the boilers and process heaters covered by 40 CFR part 63 subpart DDDDD at this site according to the procedures in §63.7540(a)(10)(i) through (vi)." • § 63.7550 What reports must I submit and when? o (a) You must submit each report in Table 9 to this subpart that applies to you. o (b) For units that are subject only to a requirement to conduct subsequent annual, biennial, or 5 -year tune-up according to §63.7540(a)(10),.(11), or (12), respectively, and not subject to emission limits or Table 4 operating limits, you may submit only an annual, biennial, or 5 -year compliance report, as applicable, as specified in paragraphs (b)(1) through (4) of this section, instead of a semi-annual compliance report. o (c) A compliance report must contain the following information depending on how the facility chooses to comply with the limits set in this rule. o (c) (1) If the facility is subject to the requirements of a tune up you must submit a compliance report with the information in paragraphs (c)(5)(i) through (iii) of this section, (xiv) and (xvii) of this section, and paragraph (c)(5)(iv) of this section for limited -use boiler or process heater. o (h)(3) You must submit all reports required by Table 9 of this subpart electronically to the EPA via the CEDRI. (CEDRI can be accessed through the EPA's CDX.) You must use the appropriate electronic report in CEDRI for this subpart. Instead of using the electronic report in CEDRI for thissubpart, you may submit an alternate electronic file consistent with the XML schema listed on the CEDRI Web site (http://www.epa.gov/ttn/chief/cedri/index.html), once the XML schema is available. If the reporting form specific to this subpart is not AIRS ID: 123/9012 Page 16 of 60 DC , LP Col ado De Perm' nd Environment Control Division available in CEDRI at the time that the report is due, you must submit the report o the Administrator at the appropriate address listed in §63.13. You must begin submitting reports via CEDRI no later than 90 days after the form becomes available in CEDRI. • § 63.7555 What records must I keep? o (a) You must keep records according to paragraphs (a)(1) and (2) of this section. o (a)(1) A copy of each notification and report that you submitted to comply with this subpart, including all documentation supporting any Initial Notification or Notification of Compliance Status or semiannual compliance report that you submitted, according to the requirements in §63.10(b)(2)(xiv). o (a)(2) Records of performance tests, fuel analyses, or other compliance demonstrations and performance evaluations as required in §63.10(b)(2)(viii). • § 63.7560 In what form and how long must I keep my records? o (a) Your records must be in a form suitable and readily available for expeditious review, according to §63.10(b)(1). o (b) As specified in §63.10(b)(1), you must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. o (c) You must keep each record on site, or they must be accessible from on site (for example, through a computer network), for at least 2 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to §63.10(b)(1). You can keep the records off site for the remaining 3 years. ' Condensate Loading 36. Point 004 and 020: This source is located in an ozone non -attainment or attainment - maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 37. Point 019: This source is located in an ozone non -attainment or attainment -maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Raw condensate unloading shall be conducted by unloading from a pressurized tank truck to a pressurized vessel via vapor balance system. 38. Point 004 and 020: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation Number 3, Part B, III.D.2): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. AIRS ID: 123/9012 Page 17 of 60 DC Fermi LP Col, ado De nd per ing thief perations ar of perso nd Environment Control Division ches) shall be closed of active, except for • equipment. c. The owner or operator shall inspect loading equipment and operations onsite at the time of inspections to monitor compliance with above conditions. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 39. Point 004,019 and 020: 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. Condensate Storage Tanks 40. Point 005 and 010: The open flare covered by this permit (Point 010) has been approved as an alternative emissions control device under Regulation Number 7, Section XVII.B.2.e. The open flare must have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16, and be designed so that an observer can, by means of visual observation from the outside of the open flare, or by other convenient means approved by the Division, determine whether it is operating properly. This open flare must be equipped with an operational auto -igniter. 41. Point 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 according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 42. Point 005 and 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. AIRS ID: 123/9012 Page 18 of 60 nd Environment Control Division +vered Lri erhis permita e subject to the gulati n Numb:r 7, Section XIa .3. The owner or ect t• s""=. qu Nip. or XV 'a st maintain records of STEM, if applicable, including theplan, any updates, and the certification, and:make them available to the Division upon request. In addition, for a period of two (2) years, the owner or operator must maintain records of any required monitoring and make them available to the Division upon request, including: • XVII.C.3.a. The AIRS ID for the storage tank • XVII.C.3.b. The date and duration of any period where the thief hatch, pressure relief device, or other access point are found to be venting hydrocarbon emissions, except for venting that is reasonably required for maintenance, gauging, or safety of personnel and equipment. • XVII.C.3.c. The date and duration of any period where the air pollution control equipment is not operating. • XVII.C.3.d. Where a combustion device is being used, the date and result of any EPA Method 22 test or investigation pursuant to Section XVII.C.1.d.(v). • XVII.C.3.e. The timing of and efforts made to eliminate venting, restore operation of air pollution control equipment, and mitigate visible emissions. • XVII.C.3.f. A list of equipment associated with the storage tank that is designated as unsafe, difficult, or inaccessible to monitor, as described in Section XVII.C.1.e., an explanation stating why the equipment is so designated, and the plan for monitoring such equipment. 44. Point 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: • 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). AIRS ID: 123/9012 Page 19 of 60 Col ado De. nd Environment Control Division 0.112bThe 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. o §60.113b — Testing and procedures • 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 AIRS ID: 123/9012 Page 20 of 60 DC' , , LP Col ado De Permi Fugitive Emissions nd Environment Control Division 65.42(b)(4), (b)(5), (b)(6), or (c) is exempt from the requirements of paragraphs (c) and (d) of this section can 45. Point 006 and 012: This source is subject to Regulation No. 7, Section XII.G.1 (State only enforceable). For fugitive VOC emissions from leaking equipment, the leak detection and repair (LDAR) program as provided at 40 C.F.R. Part 60, Subpart OOOO or 0000a shall satisfy Regulation Number 7, Section XII.G.1 in lieu of following 40 CFR 60 NSPS KKK. 46. Point 006: The fugitive emissions addressed by AIRS ID 006 associated with equipment within a process unit that commenced construction, modification or reconstruction prior to September 18, 2015 are subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart OOOO, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution including, but not limited to, the following: • §60.5365 Applicability - The group of all equipment, except compressors, within a process unit for which you commence construction, modification or reconstruction after August 23, 2011, and on or before September 18, 2015, is an affected facility per §60.5365(f). • §60.5400 Standards - The group of all equipment, except compressors, within a process unit must comply with the requirements of §60.5400 and §60.5401. • §60.5410 - Owner or operator must demonstrate initial compliance with the standards using the requirements in §60.5410(f). • § 60.5415 - Owner or operator must demonstrate continuous compliance with the standards using the requirements in §60.5415(f). • § 60.5421 - Owner or operator must comply with the recordkeeping requirements of §60.5421(b). • § 60.5422 - Owner or operator must comply with the reporting requirements of paragraphs (b) and (c) of this section in addition to the requirements of § 60.487a(a), (b), (c)(2)(i) through (iv), and (c)(2)(vii) through'(viii). 47. Point 006 and 012: This source is subject to the requirements of 40 CFR, Part 63, Subpart HH - National Emission Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities including, but not limited to, the following: • §63.769 — Equipment Leak Standards o §63.769(b) - The requirements of §63.769 do not apply to ancillary equipment and compressors for which the owner or operator is subject to and controlled under the requirements specified in 40 CFR part 60, subpart OOOO. o §63.775(e) - Ancillary equipment and compressors subject to and controlled under 40 CFR part 60, subpart OOOO shall submit the periodic reports specified in §63.775(e)(1) and (2). AIRS ID: 123/9012 Page 21 of 60 Col t; ado De nd Environment Control Division 48. Point ' and 1r' : T ivisi• ° has de ine• is flare shall o ply with the New erfo - St- = -quir- p T :�-.:��art A Se0.18, General Control Device and Work Practice Requirements, including, but not limited to, the following: a. §60.18(b) Flares. Paragraphs (c) through (f) apply to flares. b. §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. c. §60.18(c)(2) Flares shall be operated with a flame present at all times, as determined by the methods specified in paragraph (f). d. §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. 1. a.i.1.1.1.1 §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). (ii) §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. (iii) §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. AIRS ID: 123/9012 Page 22 of 60 DC Permi LP Col ado De 0.1 'city rag r, rmined by t nd Environment Control Division ed and pprated with an exit method specified in f. §60.18(c)(6) Flares used to comply with this section shall be steam -assisted, air -assisted, or nonassisted. g. §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 statinghow owners or operators of flares shall monitor these control devices. h. §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. i. §60.18(f)(1) Method 22 of appendix A to this part shall be used to determine the compliance of flares with the visible emission provisions of this subpart. The observation period is 2 hours and shall be used according to Method 22. j. §60.18(f)(2) The presence of a flare pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame. k. §60.18(f)(3) The net heating value of the gas being combusted in a flare shall be calculated using the following equation: 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; tortstant,..� ( 1 •}. { mole}, {.,..}; 1.740 x..;10 OW scm rea-17,: where-:thestandard tewperatur for ; mo1e" is; }< 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. AIRS ID: 123/9012 Page 23 of 60 DC , LP ,, Col ado De Permi ..• o. 11 ► r . 481 nd Environment utio Control Division ity of afl re shall be d termined by dividing etric%o rate units • tanda d emperature nd pressure), as terry ded bry ~eth • ati ' t2 or 2D as p o.priate; by the unobstructed (free) cross sectional area of the flare tip. m. §60.18(f)(5) The maximum permitted velocity, Vmax, for flares complying with paragraph (c)(4)(iii) shall be determined by the following equation. Log 10 (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). n. §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). Turbines 49. Point 013 and 014: The combustion turbines are subject to the New Source Performance Standards requirements of Regulation Number 6, Part A, Subpart KKKK, Standards of Performance for Stationary Combustion Turbines including, but not limited to, the following: • 40 CFR, Part 60, Subpart A — General Provisions • §60.4320 — Nitrogen Oxide Emissions Limits o §60.4320 (a) - NOx emissions shall not exceed 25 ppm at 15% O2 or 1.2 lb/MW- hr; • §60.4330 - Sulfur Dioxide Emissions Limits O §60.4330 (a)(1) - SO2 emissions shall not exceed 0.9 lb/MW-hr gross output; or o §60.4330 (a)(2) - Operator shall not burn any fuel that contains total potential sulfur emissions in excess of 0.060 lb SO2/MMBtu heat input. • §60.4333 — General Requirements o §60.4333 (a) Operator must operate and maintain your stationary combustion turbine, air pollution control equipment, and monitoring equipment in a manner consistent with good air pollution control practices for minimizing emissions at all times including during startup, shutdown and malfunction. • §60.4340 — NO, Monitoring O §60.4340 (a) Operator shall perform annual performance tests in accordance with §60.4400 to demonstrate continuous compliance with NOx emissions limits. If the NOx emission result from the performance test is less than or equal AIRS ID: 123/9012 Page 24 of 60 nd Environment Control Division o 75 percent of the NOx emission limit for the turbine, you may reduce the requency of subsequent performance tests to once every 2 years (no more than 26 calendar months following the previous performance test). If the results of any subsequent performance test exceed 75 percent of the NOx emission limit for the turbine, you must resume annual performance tests. • §60.4365 (or §§60.4360 and 60.4370) — SO2 Monitoring o The operator shall comply with §60.4365 or with both §§60.4360 and 60.4370 to demonstrate compliance with SO2 emissions limits. • §60.4375 — Reporting o §60.4375 (b) - For each affected unit that performs annual performance tests in accordance with §60.4340(a), you must submit a written report of the results of each performance test before the close of business on the 60th day following the completion of the performance test. • §§60.4400 and 60.4415 — Performance Tests o Annual tests must be conducted in accordance with §60.4400(a) and (b). o Unless operator chooses to comply with §60.4365 for exemption of monitoring the total sulfur content of the fuel, then initial and subsequent performance tests for sulfur shall be conducted according to §60.4415. 50. Point 013 and 014: This source is subject to the major source requirements of 40 CFR, Part 63, Subpart YYYY - National Emissions Standards for Hazardous Air Pollutants for Stationary Combustion Turbines including, but not limited to, the following: • §63.6090 — What parts of my plant does this subpart cover? o §63.6090(a) An affected source is any existing, new, or reconstructed stationary combustion turbine located at a major source of HAP emissions. • §63.6090(a)(2) A stationary combustion turbine is new if you commenced construction of the stationary combustion turbine after January 14, 2003. • §63.6095 — When ido I have to comply with thissubpart? o §63.6095(d) Stay of standards for gas -fired subcategories. If you start up a new or reconstructed stationary combustion turbine that is a lean premix gas - fired stationary combustion turbine or diffusion flame gas -fired stationary combustion turbine as defined by this subpart, you must comply with the Initial Notification requirements set forth in §63.6145 but need not comply with any other requirement of this subpart until EPA takes final action to require compliance and publishes a document in the Federal Register. • §63.6145 — What notifications must I submit and when? o §63.6145(a) You must submit all of the notifications in §§63.7(b) and (c), 63.8(e), 63.8(0(4), and 63.9(b) and (h) that apply to you by the dates specified. o §63.6145(c) As specified in §63.9(b), if you start up your new or reconstructed stationary combustion turbine on or after March 5, 2004, you must submit an initial notification not later than 120 calendar days after you become subject to this subpart. o §63.6145(d) If you are required to submit an Initial Notification but are otherwise not affected by the emission limitation requirements of this subpart, in accordance with §63.6090(b), your notification must include the information AIRS ID: 123/9012 Page 25 of 60 DC Permit, Col ado De , LP 481 nd Environment Control Division t that yo r new or reconstructed no additionemission limitation f the exc TEG Dehydrator 51. Point 018: 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.) 52. Point 018: The glycol dehydration unit at this facility is subject to National Emissions Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities, Subpart HH. This facility shall be subject to applicable major source provisions of this regulation, as stated in 40 C.F.R Part 63, Subpart A and HH. (Regulation Number 8, Part E, Subpart A and HH): AIRS ID: 123/9012 Page 26 of 60 DC Permi LP Colctado De nd Environment Control Division HH App c ble it ; quirem s M3ar Msoigrce mall Dkh drat° s Controlled wtk Flare Shutdowns, and Malfunctions in §63.762 - The provisions set forth this subpart shall apply at all times. §63.764 - General Standards §63.764(c)(1) - For each glycol dehydration unit process subpart, the owner or operator shall comply with the in paragraphs (c)(1)(i) through (iii) of this section. $63.764(c)(1)(i) - The owner or operator shall comply requirements for glycol dehydration unit process vents §63.764(c)(1)(ii) - The owner or operator shall comply requirements specified in §63.773 §63.764(c)(1)(iii) - The owner or operator shall comply recordkeeping and reporting requirements specified §63.764(j) - At all times the owner or operator must any affected source, including associated air pollution and monitoring equipment, in a manner consistent with pollution control practices for minimizing emissions. whether such operation and maintenance procedures based on information available to the Administrator is not limited to, monitoring results, review of operation procedures, review of operation and maintenance records, the source. requirements in operate Determination are which vent subject to this specified with the control specified in §63.765 with the monitoring with the §63.774 and §63.775 and maintain control equipment safety and good air of being used will be may include, but and maintenance and inspection of §63.765 - Glycol Dehydration Unit Process Vent Standards §63.765(b)(1) - For each glycol dehydration operator shall control air emissions by §63.765(b)(1)(iii) - You must limit BTEX glycol dehydration unit process vent, determined in Equation 2 of this section. Equation 2 must be met in accordance in paragraphs (b)(1)(iii)(A) through (D) ELBTEx = (4.66 x 10-6) x Throughput X C;.BTEX Where: ELBTEX = Unit -specific BTEX emission limit, 4.66 x 10-6 = BTEX emission limit, grams BTEX/standard Throughput = Annual average daily natural gas Ci,BTEX = average annual BTEX concentration dehydration unit, ppmv. §63.765(b)(1)(iii)(A) - Connect the combination of control devices through system shall be designed and operated of §63.771(c) The control device(s) accordance with the requirements of §63.765(b)(1)(iii)(D) - Demonstrate actual uncontrolled operation of the operational parameters in accordance §63.771(e) and emissions in accordance §63.765(b)(2) - One or more safety atmosphere may be used on the air comply with paragraphs (b)(1) of this unit process paragraph (b)(1)(iii) emissions from as defined in §63.761, The limits with one of the of this section. X 365 days t Mgrams determined vent, the owner or of this section. each new small to the limit using alternatives specified X year 1x 106grams megagrams per year; cubic throughput, standard of the natural gas process vent a closed -vent in accordance shall be designed §63.771(f) that the emissions small glycol dehydration with the requirements with §63.772(b)(2) devices that emission control section. meter-ppmv; at to system. equipment (Equation 2) cubic meters per day. the inlet to the glycol a control device or The closed vent with the requirements and operated in limit is met through unit. Document specified in vent directly to the installed to J AIRS ID: 123/9012 Page 27 of 60 DC Permi , LP 481 Col ado De nd Environment Control Division 1(a) T g—sectio applie h cover, con ® device ' tailed • oper by k he owner emis @ as quiredb a he pr vi ions of this sib t`:sed-vent system, and or sperator to control air a art. Compliance with of records required review of performance ~' p ` '= 'his `1 b rag :' se ="'`` rmined by §63.774 and the reports required by §63.775, by test results, and by inspections. §63.771(c) - Closed -vent system requirements. §63.771(0(1) -- The control device used to meet BTEX the emission limit calculated in §63.765(b)(1)(iii) shall be the control device specified in §63.771 - Control paragraph (f){1 )(iii) of this section. Equipment $63.771(f)(1)(iii) - A flare, as defined in §63.761, that is designed and Requirements operated in accordance with the requirements of §63.11(b). §63.771(0(2) - The owner or operator shall operate each control device in accordance with the requirements specified in paragraphs (f)(2)(i) and (ii) of this section. $63.771(f)(2i0) - Each control device used to comply with this subpart shall be operating at all times. An owner or operator may vent more than one unit to a control device used to comply with this subpart. §63.771(f)(2)(ii) - For each control device monitored in accordance with the requirements of §63.773(d), the owner or operator shall demonstrate compliance according to the requirements of either §63.772(f) or (h). §63.772(b) - Determination of glycol dehydration unit flowrate, benzene emissions, or BTEX emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate, benzene emissions, or BTEX emissions. §63.772(d)(1) - If the owner or operator is using a control device to comply §63.772 - Test with the emission limit in §63.765(b)(1)(iii), the requirements of paragraph Methods, Compliance (e) of this section apply. Compliance is demonstrated using the methods Procedures and specified in paragraph §63.772(f) of this section. Compliance §63.772(e)(2) - An owner or operator shall design and operate each flare, as Demonstration defined in §63.761, in accordance with the requirements specified in §63.11(b) and the compliance determination shall be conducted using Method 22 of 40 CFR part 60, appendix A, to determine visible emissions. §63.772(f) - Compliance demonstration for control device performance requirements. This paragraph applies to the demonstration of compliance with the control device performance requirements specified in §63.771(f)(1) AIRS ID: 123/9012 Page 28 of 60 §63.773 - Inspection and Monitoring Requirements nd Environment Control Division 73(c) - closed v stem inspection and monitoring regiir: ments. 63 3 )(1) or each [ ed-ve it ystem or cover r, quired to comply with t is s ` own .. ' all compl -tie requirements of paragraphs (c) (2) through (7) of this section. $63.773(c)(2) - Except as provided in paragraphs (c)(5) and (6) of this section, each closed -vent system shall be inspected according to the procedures and schedule specified in paragraphs c)(2)(i) and (ii) of this section, each cover shall be inspected according to the procedures, and schedule specified in paragraph (c)(2)(iii) of this section, and each bypass device shall be inspected according to the procedures of paragraph (c)(2)(iv) of this section. $63.773(c)(3) - In the event that a leak or defect is detected, the owner or operator shall repair the leak or defect as soon as practicable, except as provided in paragraph (c)(4) of this section. §63.773(c)(4) - Delay of repair of a closed -vent system or cover for which leaks or defects have been detected is allowed if the repair is technically infeasible without a shutdown, as defined in §63.761, or if the owner or operator determines that emissions resulting from immediate repair would be greater than the fugitive emissions likely to result from delay of repair. Repair of such equipment shall be complete by the end of the next shutdown. $63.773(c)(5) - Any parts of the closed -vent system or cover that are designated, as described in paragraphs (c)(5)(i) and (ii) of this section, as unsafe to inspect are exempt from the inspection requirements of paragraphs (c)(2)(i), (ii), and (iii) of this section if: $63.773(c)(5)(i) - The owner or operator determines that the equipment is unsafe to inspect because inspecting personnel would be exposed to an imminent or potential danger as a consequence of complying with paragraphs (c)(2)(i), (ii), or (iii) of this section; and §63.773(c)(5)(ii) - The owner or operator has a written plan that requires inspection of the equipment as frequently as practicable during safe -to - inspect times §63.773(c)(6) - Any parts of the closed -vent system or cover that are designated, as described in paragraphs (c)(6)(i) and (ii) of this section, as difficult to inspect are exempt from the inspection requirements of paragraphs (c)(2)(i), (ii), and (iii) of this section if: §63.773(c)(6)(i) - The owner or operator determines that the equipment cannot be inspected without elevating the inspecting personnel more than 2 meters above a support surface; and §63.773(c)(6)(ii) - The owner or operator has a written plan that requires inspection of the equipment at least once every 5 years. §63.773(c)(7) - Records shall be maintained as specified in §63".774(b)(5) through (8) §63.773(d)(1) - The owner or operator shall comply with the requirements specified in this subpart including but not limited to: §63.773(d)(1)(ii) - A site -specific monitoring plan must be prepared that addresses the monitoring system design, data collection, and the quality assurance and quality control elements outlined in paragraph (d) of this section and in §63.8(d). Each CPMS must be installed, calibrated, operated, and maintained in accordance with the procedures in your approved site - specific monitoring plan. §63.774 - Recordkeeping Requirements §63.774(b) - Except as specified in paragraphs (c), (d), and (f) of this section, each owner or operator of a facility subject to this subpart shall maintain the records specified in paragraphs (b)(1) through (11) of this section AIRS ID: 123/9012 Page 29 of 60 DC Perm' ,LP 481 Col ado De nd Environment Control Division 563..775 Re .ii - Rep eme fg ` 75(b) - Ea r-- r opera ord'najor ed d sour in paragrap in paragr essubject p to this subpart 63.775(b)(1) through 563.775(b)(7) and sha ". bmit info tion h §63. )(6) ` except a pro Requirements Covering Multiple Sources 53. This source is located in an ozone non -attainment or attainment -maintenance area and subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.b. The following requirements were determined to be RACT for this source: Facility Equipment ID AIRS Point RACT Pollutants AM001 001 Still Vent: Regenerative thermal oxidizer (RTO) and sales line Flash Tank: Vapor recovery unit (VRU) and open flare VOC H-0886 002 Natural gas as fuel, low NOx burners, good combustion practices NOx, VOC H-0286 . 003 Natural gas as fuel, low NOx burners, good combustion practices NOx, VOC LO -1 004 Submerged fill; and Enclosed Combustor or Open Flare VOC TANKS 005 Enclosed Combustor or Open Flare VOC FUG 006 LDAR as provided at 40 CFR Part 60 Subpart OOOO/OOOOa VOC H-0887 007 Natural gas as fuel, low NOx burners, good combustion practices NOx, VOC TANKS -2 011 Vapor recovery unit (VRU) and Enclosed Combustor VOC FUG -2 012 LDAR as provided at 40 CFR Part 60.Subpart 0000a VOC TURB-1 013 Natural gas as fuel, low NOx burners, good combustion practices NOx, VOC TURB-2 014 Natural gas as fuel, low NOx burners, good combustion practices NOx, VOC HT -01 015 Natural gas as fuel, low NOx burners, good combustion practices NOx, VOC HT -02 016 Natural gas as fuel, low NOx burners, good combustion practices NOx, VOC AM002 017 Still Vent: Regenerative Thermal Oxidizer (RTO) VOC Flash Tank: Recycled to plant inlet via VRU. Routed to plant flare (point 010) during VRU downtime D-01 018 Still Vent and Flash Tank: Recycled to plant inlet via VRU. Routed to plant flare (point 010) during VRU downtime VOC AIRS ID: 123/9012 Page 30 of 60 DC nd Environment Control Division Facile Equip = t 1 SR o nt Pollutants _ CT UL -1 019 Unloading using pressurized vessels and vapor balance VOC LO -2 020 Submerged fill and Enclosed Combustor or Open Flare VOC 54. Point 001, 002, 006, 007, 009, 010, 011, 012, 013, 014, 016, 017: 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. The flare shall be designed and operated, and records and reports shall be furnished, as required under § 60.18: AIRS ID: 123/9012 Page 31 of 60 DCLP �....�_ Col ado De Perm 55. a. urces are ulations of R III.A.1): nd Environment Control Division ubject to the lation 1 including, 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): (1) For fuel burning equipment with designed heat inputs greater than 1x106 BTU per hour, but less thanor equal to 500x106 BTU per hour, the following equation will be used to determine the allowable particulate emission limitation. PE=0:5(FI)-°.26 Where: PE = Particulate Emission in Pounds per million BTU heat input. Fl = Fuel Input in Million BTU per hour. b. Emissions of sulfur dioxide shall not emit sulfur dioxide in excess of the following combustion turbine limitations. (Heat input rates shall be the manufacturer's guaranteed maximum heat input rates). (1) Points 013 and 014: Combustion Turbines with a heat input of less than 250 Million BTU per hour: 0.8 pounds of sulfur dioxide per million BTU of heat input. (Regulation 1 Section VI.B.4.c) (2) Points 015 and 016: Limit emissions to not more than two (2) tons per day of sulfur dioxide. (Regulation 1 Section VI.B.5.a.) 56. Points 002, 003, 007, 013, 014, 015, 016: These sources are subject to the New Source Performance Standards requirements of Regulation 6, Part B including, but not limited to, the following (Regulation 6, Part B, Section II): a. Standard for Particulate Matter — On and after the date on which the required performance test is completed, no owner or operator subject to the provisions of _ this regulation may discharge, or cause the discharge into the atmosphere of any particulate matter which is: (1) For fuel burning equipment generating greater than one million but less than 250 million Btu per hour heat input, the following equation will be used to determine the allowable particulate emission limitation: PE=0.5(FI)-o.26 Where: PE is the.allowable particulate emission in pounds per million Btu heat input. _ Fl is the fuel input in million Btu per hour. If two or more units connect to any opening, the maximum allowable emission rate shall be the sum of the individual emission rates. (2) Greater than 20 percent opacity. AIRS ID: 123/9012 ' Page 32 of 60 DC Per LP Col ado Dept mi , o 1 ► z 481 _' lutio fir P S = daro p- "orm s re • n; I "'• o ' e t 'fur Dio t s co =; o • -ted, ge, • can and o, owner c. 6a,er to e .he date subject roi whit to tl ati operator scharge nd Environment Control Division h the required e provisions of iosphere sulfur dioxide in excess of: (1) Points 013 and 014: Sources with a heat input of less than .250 million Btu per hour: 0.8 lbs. SO2/million Btu. . OPERATING & MAINTENANCE REQUIREMENTS 57. Points 001, 004, 005, 011, 017, 018, 020: Upon startup of these points, the applicant shall follow the operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) 58. Point 004 and 020: The owner or operator of a loadout at which an enclosed combustor is used to control emissions shall: a. Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks and route these vapors to the enclosed flare. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. d. Operate all recovery and disposal equipment at a back pressure less than the pressure relief valve setting of transport vehicles. e. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. g. Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 59. Point 010: 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 AIRS ID: 123/9012 Page 33 of 60 DC' , , LP -;., Col � ado De Perm' nd Environment Control Division all be su " itted to the Division must -mons' a e the emissi factor established r eq .I e .• sions fa r" •miffed 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. 60. Point 012: 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. 61. Point 012: Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self -certification process to ensure compliance with emissions limits. 62. Point 013 and 014: These turbines are subject to the initial testing requirements of 40 C.F.R. Part 60, Subpart KKKK, as referenced in this permit. 63. Points 013 and 014: A source initial compliance test shall be conducted on each of the combustion turbines 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. Particulate Matter < 2.5 pm (filterable + condensable) using EPA approved methods Carbon Monoxide using EPA approved methods This test may be conducted concurrently with the initial testing required by 40 C.F.R. Part 60, Subpart KKKK. 64. Point 016: A source initial compliance test shall be conducted on each 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 AIRS ID: 123/9012 Page 34 of 60 LP e h,. Col ado De nd Environment Control Division view andapproval at least thirty plianc e conducted w thout prior approval test •rigf how conl.ar with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. 65. Point 017: 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 annual extended sour gas analysis testing required by this permit. The owner or operator shall use this sour gas analysis to calculate actual emissions, as prescribed in the Emission Limitations 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. 66. Point 017: Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, the operator shall complete an initial sample of the inlet gas to the plant to determine the concentration of hydrogen sulfide (H2S) in the gas stream. The owner or operator shall use the sample results to calculate actual emissions, as prescribed in the Emission Limitations 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. 67. Point 017: Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, a source initial compliance test shall be conducted on this emissions point to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits in this permit. The operator shall also demonstrate the regenerative thermal oxidizer achieves a minimum destruction efficiency of 96% for VOC. The operator shall measure and record, using EPA approved methods, VOC mass emission rates at the thermal oxidizer inlet and outlet to determine the destruction and removal efficiency of the thermal oxidizer (process models shall not be used to determine the flow rate or composition of waste gas (acid gas stream from the still vent) sent to the thermal oxidizer for the purposes of this test). The natural gas throughput, lean amine recirculation rate, MDEA concentration, sulfur content of the sour gas entering the amine unit, and thermal oxidizer combustion chamber temperature shall be monitored and recorded during this. test. This test shall be run with the thermal oxidizer operating at the minimum combustion chamber temperature of 1,550°F as indicated in the O&M plan for this point. 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) AIRS ID: 123/9012 Page 35 of 60 DC Permi LP o. 11Vt;N 481 ado De u ®'oxideus'1o``'-pprovedm-` �� .des a Nitrog- usinA approved methods .mp• s '9 A 'A appro Carbon Monoxide using EPA approved methods. ods. nd Environment Control Division heihods. 68. Point 018: The owner or operator shall complete an extended wet gas analysis prior to the inlet of the TEG dehydrator 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. Periodic Testing Requirements 69. Point 001 and 017: The operator shall sample the inlet gas to the plant on an annual basis to determine the concentration of hydrogen sulfide (H2S) in the gas stream. The sample results shall be monitored to demonstrate that this amine unit qualifies for the exemption from the Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution (§60.5365(g)(3). 70. Point 001 and 017: The owner or operator shall complete an extended sour gas analysis prior to the inlet of the amine unit on an annual basis. Results of the sour gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants. 71. Point 001 and 017: The permit holder shall measure and record the lean amine strength on a daily basis. The lean amine strength is defined as the combined weight percent of MDEA and piperazine in the lean amine stream. Records of these operating parameters shall be made available to the Division for inspection upon request. 72. Point 006 and 012: 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. 73. Point 010: On an annual basis, the owner/operator shall complete site -specific extended gas analyses ("Analyses") of the plant inlet gas stream and the 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 site -specific emission factors for VOC (in units of lb/MMSCF gas vented) using Division approved methods. Results of the Analyses shall be used to demonstrate that the emissions factor established through the Analyses are less than or equal to, the emission 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. 74. Point 013 and 014: These turbines are subject to the periodic testing requirements of 40 C.F.R. Part 60, Subpart KKKK, as referenced in this permit. AIRS ID: 123/9012 Page 36 of 60 DC' , LP Col ado De Perm i o. 11.481 nd Environment Control Division 75. �� oint 01 "' d "� = operator"',l �'o duct, - . mi'mum, q erly portable analyzer outle issio of nitrogen es (NOX) and carbon ianc- i •- fissions I 'esults of all tests conducted shall be kept on site and made available to the Division upon request. 76. Point 018: The owner or operator shall complete an extended wet gas analysis prior to the inlet of the TEG dehydrator 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. ADDITIONAL REQUIREMENTS 77. All previous versions of this permit are cancelled upon issuance of this permit. 78. This permit replaces Point 009, which shall be cancelled upon startup of Point 010. The owner or operator shall submit a cancellation request for Point 009 within 30 days of startup of Point 010. Existing Emission Point New Emission Point 123/9012/009 123/9012/010 79. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine or turbine under the alternative operating scenario outlined in this permit as Attachment A or B. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine or turbine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative -operating scenario and is installing a permanent replacement engine or turbine. Submittal of an updated APEN is also required for replacement of components if such replacement results in a change of serial number. AIRS ID: 123/9012 Page 37 of 60 LP CoI Dei. : irf` utio nd Environment Control Division DC' Permi • , o. 11 ' 1P,y 481 ado ' 80. his sour - is s itle V •' e 1 � - . '= due • C t e • the prov egula Fe .I Cle Air A end ' on �� he e - i o =nts). cement ber 3, ' The app • - C, Operating Permits tion for the Operating :o - ation of any of the following pieces of equipment covered by this permit: Point 010, Point 011, Point 012, -- Point 013, Point 014, Point 015, Point 016, Point 017, Point 018, Point 019, and Point 020. 81. 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, VI.B.4N.A.7.B). GENERAL TERMS AND CONDITIONS: 82. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 83. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self - Certify for Final Authorization section of this permit. 84. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 85. 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. 86. 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 applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. AIRS ID: 123/9012 Page 38 of 60 DC Pe mi_ 1, Lr e o. 11''" 481 . '..OI GUU LJe it utio .ection -11 missio otic(P ' tio C.R.S. that al s e i requird the o.ts to file of er ur-s to cover ntinued , _ must s" y an`ri� ual f so ivity ' t nd Environment Control Division 87. an Air Pollution inspections and must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 88. - Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Bradley Eades Permit Engineer Permit History Issuance Date Description Issuance 5 This Issuance Issued to DCP Operating Company, LP Company name change application was received by the - Division on May 25, 2017. Point 001: Update emission limit to reflect 95% flare control efficiency and update conditions to align with AM002 Cancel point 009 upon startup of point 010. Point 005: Update emission factors and update equipment description (number of tanks). Addition of points 010-020 for new O'Connor 2 processing train. Source status changed from synthetic minor to major source of HAP with addition of new points. Issuance 4 8/1.3/16 Modification to emissions to include VRU and RTO downtime at point 001 and new point 009 plant flare Issuance 3 02/28/2014 Modification to change the emission and throughput limits for point 003. Updated description to include make and serial numbers for points 002, 003 and 007. Facility name changed to the DCP O'Connor Plant. Issuance 2 5/9/2013 Modification to include new Hot oil heater (point 007) and exempted Produced water tank (permit #13WE1454). Process feed gas design rate increased from 110 mmscf/d to 160 MMscf/d. RTO destruction efficiency changed from 99% to 95%. Also increase amine recirculation rate to 780 gpm from 520 gpm. Increase AIRS ID: 123/9012 Page 39 of 60 DC Permi , LP 48 Ccl ado De nd Environment Control Division " tuber o ° e tanks ( on h 5) to 8. In ut. rease dens load '" throw Is .. " ... 10/18 , wid t one (1) hot oil heater, one (1) condensate loadout, four storage tanks, and associated (1) ng: One regenerative (4) 400 -bbl condensate fugitive emissions. , heater, a unit, one AIRS ID: 123/9012 Page 40 of 60 DC' x a , LP Col ;u ado De Perms o.1 ► 481 Notes 1) T nd Environment Control Division for th p ocess ns time for this p= it. An invoice for these suedd. Tshall pa � ice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: http://www. cdphe.state.co. us/regulations/airregs/100102aocccommonprovisionsreq. pdf. 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's - analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emission Rate (lb/yr) Are the emissions reportable? Controlled Emission Rate (lb/yr) 001 Benzene 71432 179,380 Yes 13,240 Toluene 108883 149,160 Yes 11,120 Ethylbenzene 100414 8,020 Yes 600 Xylenes 1330207 49,800 Yes 3,760 n -Hexane 110543 4,080 Yes 1,140 Methanol 22,646 Yes 650 002 Formaldehyde 50000 34 No 34 n -Hexane 110543 808 No 808 003 Formaldehyde 50000 6 No 6 n -Hexane 110543 151 No 151 004 Benzene 71432 1,717 Yes 86 Toluene 108883 4,757 Yes 238 Ethylbenzene 100414 354 Yes 18 Xylenes 1330207 3,596 Yes 180 n -Hexane 110543 9,237 . Yes 462 005 Benzene 71432 876 Yes 44 Toluene 108883 2,426 Yes 121 Ethylbenzene 100414 181 No 9 AIRS ID: 123/9012 Page 41 of 60 DC Perm' LP Col ado De nd Environment Control Division Xylene 3 07 ;-,N, s 92 n - 110 , 4, , L L Yes � 236 006 Benzene 71432 2,326 ' Yes 780 Toluene 108883 6,161 Yes 2,080 Ethylbenzene 100414 454 Yes 154 Xylenes `1330207 4,602 Yes 1,557 n -Hexane 110543 14490 Yes 4,758 007 Benzene 71432 . 0.5 No 0.5 Toluene 108883 0.8 No 0.8 n -Hexane 110543 430 Yes 430 009 Benzene: 71432 1,320 Yes 66 Toluene 108883 1,078 - Yes 54 Ethylbenzene 100414 69 No V - 4 Xylenes 1330207 304 Yes 15 n -Hexane 110543 3,163 Yes 223 010 Benzene 71432 1,992 Yes 100 Toluene 108883 2,833 Yes 142 Ethylbenzene 100414 313 Yes 16 Xylenes 1330207 935 Yes 47 n -Hexane 110543 43,346 Yes 2,170 224-TMP 540841 1,915 Yes 96 011 Benzene 71432 2,197 No 2 Toluene 108883 6,089 No 6 Ethylbenzene 100414 454 No 1 Xylenes 1330207 4,603 No 5 n -Hexane 110543 11,822 No 12 012 Benzene 71432 626 No 100 Toluene 108883 890 No 142 Ethylbenzene 100414 98 No 16 Xylenes 1330207 294 No 47 n -Hexane 110543 13,621 No 2,178 224-TMP 540841 602 Yes 96 013 Formaldehyde 50000 454 Yes 454 Acetaldehyde 75070 26 No 26 AIRS ID: 123/9012 Page 42 of 60 DC Permi LP COIado De nd Environment Control Division _- Acrolei 8 oH,: 4 = 4., Be 714 2°; J No � 8 No 21 Ethylbenzene 100414 21 Toluene 108883 83 No 83 Xylenes 1330207 41 No 41 014 Formaldehyde 50000 454 Yes 454 Acetaldehyde 75070 26 No • 26 Acrolein 107028 4 No 4 Benzene 71432 - 8 No 8 Ethylbenzene 100414 21 No .21 Toluene 108883 83 No 83. Xylenes 1330207 41 No 41 015 Benzene 71432 <1 No <1 Toluene 108883 <1 No <1 Formaldehyde - 50000 4 No 4 n -Hexane 110543 98 ' No 98 016 Benzene 71432 1 No 1 Toluene 108883 1 No 1 Formaldehyde 50000 30 No 30 ,n -Hexane 110543 727 Yes 727 017 Benzene 71432 , 139,826 Yes 7,323 Toluene 108883 65,699 Yes 3,477 Ethylbenzene 100414 2,409 Yes 126 Xylenes 1330207 4,940 Yes 264 n -Hexane 110543 18,296 Yes 112 Hydrogen Sulfide 7783064 34,914 Yes 1,966 018 Benzene 71432 6,009 Yes 300 Toluene 108883 5,743 Yes 287 Ethylbenzene 100414 0 No 0 Xylenes 1330207 0 No 0 ,n -Hexane 110543 2,231 Yes 112 Hydrogen Sulfide 7783064 2 No <1 019 Benzene 71432 163 No 163 AIRS ID: 123/9012 Page 43 of 60 nd Environment Control Division ,� Toluen 8 83 161 l'4,§0 Eth zene 100 1;r No 8 51 Xylenes 51 No 1330207 n -Hexane 110543 1,365 Yes 1,365 - 020 Benzene 71432 . 1,816 Yes 91 Toluene 108883 5,032 Yes • 252 Ethylbenzene 100414 375 Yes 19 Xylenes 1330207 3,804 Yes 190 n -Hexane 110543 9,770 Yes 488. 5) The emission levels contained in this permit are based on the following emission factors: Point 001: Compliance with the emission limits in this permit shall be demonstrated by running the Promax simulation model on a monthly basis using the most recent amine unit inlet extended sour gas analysis and recorded operational values (including plant inlet gas throughput, lean amine strength, lean amine recirculation rate, VRU downtime, and other operational values as specified in the O&M plan). Recorded operational values, except for plant inlet gas throughput, shall be averaged on a monthly basis for input into the Promax simulation model to determine acid gas composition. Compliance with emission limits shall be demonstrated by utilising the acid gas composition from the Promax simulation and the actual acid gas volume to the RTO. Emissions limits are based on flash tank controlled at 100% (with 5% VRU downtime to plant flare) and still vent emissions routed to RTO controlled at 95% (with 2.7% RTO downtime.) CAS # Pollutant Emission Factors Controlled lb/MMBtu Source NOx 0.068 AP -42 CO 0.31 AP -42 NOx and CO permit limits calculated using a burner rating of 4 MMBtu/hr. Equation for Actual Emissions Calculations for each pollutant Y (where Y = VOC, HAP, or H2S): lb YTotal (month/ — Still vent to RTO + 'Still vent to atmosphere + YFlash tank to Flare scf 17 Still vent to RTO = Y concentration (wt %) - 100 x Still Vent Waste Gas to RTO ( ) month lb scf ll x Gas Molecular Weight (—lbmol) : ,379 (lbmol I x (1 — 96% control) Ystill vent to atmosphere = Y concentration (wt %) ± 100 x Still Vent Waste Gas to Atmosphere x Gas Molecular Weight (Lb lbmoll l I ' 379 (—scf) [bmol lb 'Flash tank to flare = Y flash tank mass flow (--) x (1 — 95% control) month (scf month/ hours) VRUdowntime (month) x hours l Total Operation (month) AIRS ID: 123/9012 Page 44 of 60 DC Perm L Col - ado Dea ^` he am Oa ' n) ^1". end Environment 7utio Control Division on strea `_ composition from model ent waste gas =atr am. ste Gas ,�a ' A+,� sphere are metered monthly flow rates from the amine unit still vent. *Flash tank mass flow is the mass flow of pollutant "Y" (lb/month) when modeled using the total monthly gas throughput as required by this permit. Points 002, 003 and 007: CAS Pollutant Emission Factors — Uncontrolled-lb/MMscf Uncontrolled EF Source NOx 50 AP -42, Section 1.4, Tables 1.4-1 CO 84 AP -42, Section 1.4, Tables 1.4-1 VOC 5.5 AP -42, Section 1.4, Tables 1.4-2 Point 004: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 7.06x10-' 7.06x10-4 TNRCC CO 2.81x10-3 2.81x10-3 TNRCC VOC 2.023x10-1 1.011x10-2 AP -42 71432 Benzene 2.689x10-3 1.34x10-4 Mass Balance 108883 Toluene 7.45x10-3 3.72x10-4 Mass Balance 100414 Ethylbenzene 5.55x10-4 2.77x10-5 Mass Balance 1330207 - Xylene 5.63x10-3 2.81x10-4 Mass Balance 110543 n -Hexane 1.446x10-2 7.23x10-4 Mass Balance Note: The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46*S*P*M/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 5.0032 psia M (vapor molecular weight) = 66 lb/lb-mol T (temperature of liquid loaded) = 512.45 °R The uncontrolled non -criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. Controlled emission factors are based on an enclosed combustor efficiency of 95%. The NOx and CO emissions factors (EF) in the table above are based on the TNRCC Technical Supplement 4 emissions factors of 0.138 lb/MMBtu and 0.5496 lb/MMBtu respectively. The emissions factors from TNRCC were converted to units of lbs/bbl using a waste gas heating value of 3,677 Btu/scf and a "gas emitted per barrel of oil loaded" factor of 1.3909 scf/bbl. An example of this calculation is as follows: EFNOx (bbl) — (0.138 lb\ (3677 MMBtu) * ,. MMscf tu) * k1,000,000scf) 1MMscf * (1.3909 bb1scf) _ 0.000706 lb AIRS ID: 123/9012 Page 45 of 60 DC Perm' LP 005: Col ado De nd Environment Control Division E ,sion F "` ors , t ont r—,,` Emission Facto ontrolle Source CAS # Pollutant lb/BBL Condensate Throughput lb/BBL Condensate Throughput VOC 1.03E-1 5.16E-3 Tanks 4.0.9d 71432 Benzene 1.37E-3 6.86E-5 Eng. Estimate 108883 Toluene 3.81E-3 1.90E-4 Eng. Estimate 1330207 Xylenes 2.87E-3 1.44E-4 Eng. Estimate 110543 n -Hexane 7.38E-3 3.69E-4 Eng. Estimate Note: The controlled emissions factors for point 005 are based on the combustor control efficiency of 95%. Point 006: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2297 --- 7279 --- Flanges 2062 --- 1375 -- Open-Ended Lines 0 --- 0 --- Pump Seals 0 -- 46 --- Valves 3026 --- 2378 --- Other 178 --- 43 VOC Content (w.t%) 24.16% 100% 100% 100% *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 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 Source: EPA -453/R95-017 Note: The controlled emissions factors for point 006 are based on 75% control efficiency, except for flanges and connectors which are based on 30% control efficiency. 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 gas analysis. AIRS ID: 123/9012 Page 46 of 60 DC Permi LP 481 009: Col ado De nd Environment Control Division eig t issio E Controlled lb/MMscf i sion o rce F io Gas (%) �:,; cto Uncontrolled lb/MMscf o utant NOx (Ib/ Ob/MMBTU) --- 0.068 0.068 AP -42 CO (Ib/MMBTU) --- 0.31 0.31 AP -42 VOC 23.01 7302.42 369.98 Gas Analysis Benzene 0.0459 24.13 1.22 Gas Analysis Toluene 0.0375 19.70 1.00 Gas Analysis Ethylbenzene 0.0024 1.26 0.06 Gas Analysis Xylenes 0.0106 5.55 0.28 Gas Analysis n -hexane 0.1677 57.77 4.07 Gas Analysis Point 010: Emissions associated with the open flare result from the combustion of maintenance gas (inlet and residue), 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 (identified as process 01 below) and the combustion of pilot light gas (identified as process 02 below). Process 01: Combustion of maintenance (residue and inlet) gas and purge gas Pollutant Emission Factors Uncontrolled lb/MMscf Emission Factors Controlled lb/MMscf Source NOx 85.48 85.48 AP -42 Chapter 13.5 CO 389.67 389.67 VOC 10485.05 524.25 Gas Analysis Benzene 18.60 0.93 Toluene 26.45 1.32 Ethylbenzene 2.92 0.15 Xylenes 8.73 0.44 n -Hexane 404.60 20.23 224-TMP 17.87 0.89 Note: The uncontrolled VOC and HAP emissions were calculated using a weighted average of a representative residue gas analysis obtained from the Lucerne II gas plant on August 27, 2015 and an inlet gas sample obtained from the O'Connor gas plant on October 20, 2016. The weighted average is based on the relative contribution of residue and purge gas volume (50%) and inlet gas volume (50%) to the total volume of gas vented to the flare. 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 heating value of 1,257 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. AIRS ID: 123/9012 Page 47 of 60 nd Environment Control Division CAS # E ' ssion --- tors r Source Uncontrolled lb/MMscf pilot fuel combusted Pollutant NOx 100 AP -42 Chapter 1 Table 1.4-3 CO 84 VOC 5.5 110543 n -Hexane 1.8 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 011: Process 01: Throughput while emissions are recycled via VRU CAS # Pollutant Emission Factors Uncontrolled lb/BBL Condensate Throughput Emission Factors Controlled lb/BBL Condensate Throughput Source VOC 1.01x10-1 0 Tanks 4.0.9d 71432 Benzene 1.34x10-3 0 108883 Toluene 3.71x10-3 0 100414 Ethylbenzene 2.76x10-4 0 1330207 Xylenes 2.80x1O3 0 110543 n -Hexane 7.20x1O3 0 Note: The controlled emissions factors for point 011, process 01 are based on the vapor recovery unit control efficiency of 100%. Process 02: Throughput while emissions are routed to enclosed combustor (during VRU downtime) CAS # Pollutant Emission Factors Uncontrolled lb/BBL Condensate Throughput Emission Factors Controlled lb/BBL - Condensate Throughput Source VOC 1.01x10-1 5.03x10-3 Tanks 4.0.9d 71432 Benzene 1.34x10-3 6.69x10-5 108883 Toluene 3.71x10-3 1.85x10-4 100414 Ethylbenzene 2.76x10-4 1.38x1O5 1330207 Xylenes 2.80x1O3 1.40x10-° 110543 n -Hexane 7.20x1O3 3.60x10-4 Note: The controlled emissions factors for point 011, process 02 are based on the combustor control efficiency of 95%. AIRS ID: 123/9012 Page 48 of 60 nd Environment Control Division C • as ice :...., .. f ° s Cot of /° r� ,;:: Li ht: r�* it Light Liquid Control Connectors 15,258 30 2524 30 Flanges 1031 30 • 494 30 Open-ended Lines - 0 75 0 --- Pump Seals 0 --- 36 88 Valves 3652 95 1224 95 Other* 61 75 14 75 Relief Valves 0 95 0 95 VOC Content (wt. %) 28.09% --- 100% --- Benzene Content (wt. %) 0.0653% --- 0.2326% --- Toluene Content (wt. %) 0.0929% --- 0.3308% --- Ethylbenzene (wt. %) 0.0103% --- 0.0365% --- Xylenes Content (wt. %) 0.0307% --- 0.1091% --- n-Hexane Content (wt. /) 1.4216% --- 5.0607% --- 2, 2, 4-TMP Content (wt. %) 0.0628% --- 0.2236% --- *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 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 013 and 014: CAS Pollutant Emission Factors - Uncontrolled lb/MMBtu PM (at 15% O2) Source PMio 5.85x10-3 --- Manufacturer test data PM2.5 5.85x10-3 --- Manufacturer test data NOx 3.97x10-2 11 Manufacturer AIRS ID: 123/9012 Page 49 of 60 Col ado De '_A it tr`r4+,:A end Environment utio Control Division CAS II d 'i sion Fact Uncontroll` d b/M u M at 0 O Sou ` e =: Pollu nt . x Manutacturer VOC 2.1x10-3 -- AP -42 Chapter 3 Table 3.1-2a 50000 Formaldehyde' 7.1x10-4 -- AP -42 Chapter 3 Table 3.1-3 Note: Emission factors are based on a rated heat input of 73.0 MMBtu/hr, a higher heating value of 1,050 Btu/scf and 8,760 hours of operation a year. Point 015: CAS # Pollutant Emission Factors Uncontrolled lb/MMscf Source PMio 5.3 Manufacturer PM2.5 5.3 NOx 50 AP -42 Chapter 1 Table 1.4-1 CO 84 AP -42 Chapter 1 Table 1.4-1 Note: Emission limits for Point 015 are based on a rated heat input of 9.3 MMBtu/hr, a higher heating value of 1,050 Btu/scf, and an annual fuel use limit of 54.31 MMscf/yr. (i.e. limited to 70% of capacity) Point 016: CAS # Pollutant Emission Factors Uncontrolled lb/MMscf Source PMio 5.3 Manufacturer PM2.5 5.3 NOx 50 AP -42 Chapter 1 Table 1.4-1 CO 84 AP -42 Chapter 1 Table 1.4-1 110543 n -Hexane 1.8 AP -42 Chapter 1 Table 1.4-3 Note: Emission factors are based on a rated heat input of 48.4 MMBtu/hr, a higher heating value of 1,050 Btu/scf and 8,760 hours of operation a year. Point 017: The emission levels contained in this permit are based on the ProMax simulation model using the extended sour gas analysis representative of the natural gas processed by this unit submitted with the permit application. Emissions from the amine unit result from venting of acid gas emissions to the regenerative thermal oxidizer (RTO), vented of acid gas emissions to the atmosphere, and venting of flash gas emissions to the plant flare. Actual VOC, HAP and H2S emissions from venting of still vent acid gas emissions shall be calculated based on the acid gas composition from the most recent model simulation (e.g. ProMax) and the most recent monthly acid waste gas flow volume. Actual VOC, HAP and H2S emissions from venting of flash tank waste gas to the flare shall be calculated based on the AIRS ID: 123/9012 Page 50 of 60 DC �� + , LP Col a ado De Perms - o. 11' 481 e o,a'; Oc�rioleffici cyof nd Environment Control Division ions are based on a VRU control re control effi • ie icy of 95%. s resstion •, arm waste gas ng flash tank stream during VRU downtime and acid gas stream from the still vent) are based on a mass balance assuming 64.06 lb SO2/lb-mol and 34.08 lb H2S/lb-mol. The following calculation demonstrates the mass balance: HZS tonsl 64.06 lb S°2 ( lb — mol 11 SOZ(tpy) _ [( year ) * ( lb — mol ) * (34.08 lb,1125)] Combustion emissions associated with thestill vent routed to the regenerative thermal oxidizer and flash tank routed to the plant flare are based on the following emissions factors: Still Vent Controlled by the Regenerative Thermal Oxidizer: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Waste Gas Combusted Source NOx 0.85 AP -42 Chapter 13.5 ,CO 3.88 Note: The combustion emission factors are based on a heating value of 12.5 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the total waste gas flow routed from the amine unit still vent to the regenerative thermal oxidizer as measured by flow meter. Flash Tank Controlled by the Plant Flare: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Waste Gas Combusted Source NOx 63.78 AP -42 Chapter 13.5 CO 290.77 Note: The combustion emission factors are based on a heating value of 937.96 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the total waste gas flow routed from the amine unit flash tank to the plant flare as calculated using ProMax and VRU downtime records. Equation for Actual Emissions Calculations for each pollutant Y (where Y = VOC, HAP, or H2S): lb 17Total (month = YStill vent to RTO + YStill vent to atmosphere + YFlash tank to Flare scf YSttll vent to RTO = Y concentration (wt %) - 100 x Still Vent Waste Gas to RTO ( month) lb l scf x Gas Molecular Weight (lbmol) : 379 (Lbmol I x (1 — 96% control) YSttll vent to atmosphere scf = Y concentration (wt %) _ 100 x Still Vent Waste Gas to Atmosphere (— ) lb scf l month x Gas Molecular Weight (lbmol) ' 379 (lbmol) hours) lb VRUdownttme (month) YFlash tank to flare = Y flash tank mass flow (month) x (1— 95% control) x Total Operation (hours) month) AIRS ID: 123/9012 Page 51 of 60 DC Permit L Col ado De 81 nd Environment Control Division ent"a`° a d Gas Mof eight a MTV on strea composition from model lationp: ( g. r ax) f ` he am unit sU I ent waste gas tr=am. till Vint Waste ste Gas sphere are metered monthly flow rates from the amine unit still vent. .*Flash tank mass flow is the mass flow of pollutant "Y" (lb/month) when modeled using the total monthly gas throughput as required by this permit. Point 018: The emission levels contained in this permit are based on information provided in the application and the GRI GlyCalc 4.0 model. Actual controlled emissions are based on a 100% control efficiency when emissions are routed to the VRU and a 95% control efficiency when emissions are routed to an open flare during VRU downtime (max 2% annually). To determine actual emissions during VRU downtime, the operator will multiply lb/hr emission results from the monthly GlyCalc model (based on the total actual gas throughput during the month) by the total hours of VRU downtime. A 95% control efficiency will be applied to this calculation based on the destruction efficiency of the flare. The operator will determine the actual monthly gas throughput during VRU downtime using the following equation: hours) MMSCf VRU downtime (Talit) Gas ThroughputVRD Downtime = (Total Gas Throughput ) x month hoursTotal Operation (mom) Point 019: CAS Pollutant. Emission Factors (Ib/loadout) - Uncontrolled Source VOC 1.9300 Engineering Calculation 71432 Benzene 0.0186 108883 Toluene 0.0184 100414 Ethylbenzene 0.0010 1330207 Xylenes 0.0058 110543 n -Hexane 0.1558 Emission factors are based on liquid and vapor line volumes of 0.0218 ft^3/loadout venting directly to the atmosphere. Point 020: Loadout Vapors: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl _ Source VOC 2.023x10-1 1.011x10-2 AP -42 71432 Benzene 2.689x10-3 1.34x10-4 Mass Balance 108883 Toluene 7.45x10-3 3.72x10-4 , Mass Balance 100414 Ethylbenzene 5.55x10-4 2.77x10-5 Mass Balance 1330207 Xylene 5.63x10-3 2.81x10-4 Mass Balance 110543 n -Hexane 1.446x10-2 7.23x10-4 Mass Balance Note: The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46*S*P*M/T AIRS ID: 123/9012 Page 52 of 60 DC Permi LP ►_ ._x_.. „_� Coltrrado De 032 ps M (vapcsriifio'f cula"66 lb T (temperature of liquid loaded) = 512.45 °R The uncontrolled non -criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. nd Environment Control Division Controlled emission factors are based on an enclosed combustor efficiency of 95%. Combustion of Loadout Vapors: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 7.06x10-4 7.06x10-4 TNRCC CO 2.81x10-3 2.81x10-3 TNRCC The NOx and CO emissions factors (EF) in the table above are based on the TNRCC Technical Supplement 4 emissions factors of 0.138 lb/MMBtu and 0.5496 lb/MMBtu respectively. The emissions factors from TNRCC were converted to units of lbs/bbl using a waste gas heating value of 3,677 Btu/scf and a "gas emitted per barrel of oil loaded" factor of 1.3909 scf/bbl. An example of -this calculation is as follows: EFNOx \66l/ = (0.138 ) MMBtu* 136 ftu\ 1MMscf * MMsc1,000,000 scf/ * \1,3909 bblscf\ _ 0.000706 bbIbNOx Combustion of Pilot and Assist Gas in dedicated combustor: Uncontrolled Controlled CAS # Pollutant Emission Factors lb/MMscf Emission Factors lb/MMscf Source NOx 100 100 CO 84 84 VOC 5.5 5.5 AP -42, Section 1.4 PM 7.6 7.6 SO2 0.6 0.6 Emission factors are based on liquid and vapor line volumes of 0.0218 ft^3/Ioadout venting directly to the atmosphere. 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) Point 006, 012 and 017: This source is subject to 40 CFR, Part 60, Subpart OOOOa-Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 (See June 3, 2016 Federal Register posting — effective August 02, 2016). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: https://www.qpo.qovffdsys/pkg/FR-2016-06-03/pdf/2016-11971.pdf 8) This facility is classified as follows: AIRS ID: 123/9012 Page 53 of 60 C ado Dew '-^` Y. ^"end Environment it utioControl Division A Require 3plicable tus Operating Permit Major Source: CO, HAP NANSR Synthetic Minor Source: VOC, NOx PSD True Minor Source: CO MACT HH Major Source Requirements: Applicable MACT YYYY Applicable MACT DDDDD Applicable NSPS Dc Applicable NSPS OOOO Applicable NSPS 0000a Applicable NSPS Kb Applicable NSPS KKKK 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 NSPS Part 60 Subpart OOOO 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 7777 - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN — Subpart X)O(XXX 10) An Oil and Gas Industry Construction Permit Self -Certification Form is included with this permit packet. Please use this form to complete the self -certification requirements as specified in the permit conditions. Further guidance on self -certification can be found on our website at: http://www.cdphe.state.co.us/ap/oilgasperrnitting.html AIRS ID: 123/9012 Page 54 of 60 DC Perm' LP -_. Col: ado De nd Environment Control Division AIRS ID: 123/9012 Page 55 of 60 DC' , , LP Col ado De Perm' TURBINES WITHOUT CONTINUOUS EMISSIONS MONITORING August 16, 2011 AL ° nfi' NATO E OP ENARIOS 1. Routine -Turbine Component Replacements nd Environment Control Division The following physical or operational changes to the turbines in this permit are not considered a modification for purposes of NSPS GG, major stationary source NSR/PSD, or Regulation No. 3, Part B. Note that the component replacement provisions apply ONLY to those turbines subject to NSPS GG. Neither pre-GG turbines nor post GG turbines (i.e. KKKK turbines) can use those provisions. 1) Replacement of stator blades, turbine nozzles, turbine buckets, fuel nozzles, combustion chambers, seals, and shaft packings, provided that they are of the same design as the original. 2) Changes in the type or grade of fuel used, if the original gas turbine installation, fuel nozzles, etc. were designed for its use. 3) An increase in the hours of operation (unless limited by a permit condition) 4) Variations in operating loads within the engine design specification. 5) Any physical change constituting routine maintenance, repair, or replacement. Turbines undergoing any of the above changes are subject to all federally applicable and state only requirements set forth in this permit (including monitoring and record keeping). If replacement of any of the components listed in (1) or (5) above results in a change in serial number for the turbine, a letter explaining the action as well as a revised APEN and appropriate filing fee shall be submitted to the Division within 30 days of the replacement. Note that the repair or replacement of components must be of genuinely the same design. Except in accordance with the Alternate Operating Scenario set forth below, the Division does not consider that this allows for the entire replacement (or reconstruction) of an existing turbine with an identical new one or one similar in design or function. Rather, the Division considers the repair or replacements to encompass the repair or replacement of components at a turbine with the same (or functionally similar) components. 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of 'combustion turbines and turbine components has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility- Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any turbine orturbine component replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such turbine or turbine component replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Turbine Replacement The following AOS is incorporated into this permit in order to deal with a turbine breakdown or periodic routine maintenance and repair of an existing onsite turbine that requires the use of a temporary replacement turbine. "Temporary" is defined as in the same service for 90 operating days or less -in any 12 , month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the turbine is in operation. If the turbine operates only part of a day, that day shall count as a single day towards the 90 -day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. AIRS ID: 123/9012 Page 56 of 60 ram 31 Col ado De z/' lutio� it F tur fa I � rn lily F in s bject ":,T ; Testing. e replace to all ap c-0 p er icable t turbir re '^ re a ment u r this O shall r for oses NSPS art all t Ureau' a,«Ra nd Environment Control Division e being considered uirements of that All replacement turbines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with the NSPS requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any turbine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the turbine (s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement turbine. 2.1.1 The owner or operator may temporarily replace an existing turbine that is covered by this permit with a turbine that is the exact same make and model as the existing turbine without modifying this permit, so long as the temporary replacement turbine complies with the emission limitations for the existing permitted turbine and other requirements applicable to the original turbine. Measurement of emissions from the temporary replacement turbine shall be made as set forth in section 2.2. 2.1.2 The owner or operator may permanently replace the existing turbine that is covered by this permit with a turbine that is the exact same make and model as the existing turbine without modifying this permit so long as the permanent replacement turbine complies with the emission limitations and other requirements applicable to the original turbine as well as any new applicable requirements for the replacement turbine. Measurement of emissions from the temporary replacement turbine shall be made as set forth in section 2.2. 2.1.3 An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement turbine shall be filed with the Division for the permanent replacement turbine within' 14 calendar days of commencing operation of the replacement turbine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement turbine. This AOS cannot be used for permanent turbine replacement of a grandfathered or permit exempt turbine or a turbine that is,not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent turbine replacement. The AOS cannot be used for the permanent replacement of an entire turbine at any source that is currently a major stationary source for purposes of Prevention of Significant Deterioration or Non - Attainment Area New Source Review ("PSD/NANSR") unless the existing turbine has emission limits that are below the significance levels in Reg 3, Part D, II.A.42. Nothing in this AOS shall preclude the Division from taking an action, based on any permanent turbine replacement(s), for circumvention of any state or federal PSD/NANSR requirement. Additionally, in the event that any permanent turbine replacement(s) constitute(s) a circumvention of applicable PSD/NANSR requirements, nothing in this AOS shall excuse the owner or operator from complying with PSD/NANSR and applicable permitting requirements. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer' - AIRS ID: 123/9012 Page 57 of 60 DC Permi LP �4.O. _ Col .; ado De operata»a ondce m this Condition, if approved in advance by the Division. s the qi& .etr .est and an nd Environment Control Division ditional portable analyzer tii of the pole alyzer test required by The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement turbine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement turbine. All portable analyzer testing required by this permit shall be conducted using the most current version of the Division's Portable Analyzer Monitoring Protocol as found on the Division's website. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement turbine will be subject to, the results of the test shall be converted to the appropriate units as described in the above - mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the turbine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the turbine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the turbine is taken offline. 2.3 Applicable Regulations for Permanent Turbine Replacements 2.3.1 NSPS for Stationary Gas Turbines: 40 CFR 60, Subpart GG §60.330 Applicability and designation of affected facility. (a) The provisions of this subpart are applicable to the following affected facilities: All stationary gas• turbines with a heat input at peak load equal to or greater than 10.7 gigajoules (10 million Btu) per hour, based on the lower heating value of the fuel fired. (b) Any facility under paragraph (a) of this section which commences construction, modification, or reconstruction after October 3, 1977, is subject to the requirements of this part except as provided in paragraphs (e) and (j) of §60.332. A Subpart GG applicability determination as well as an analysis of applicable Subpart GG monitoring, recordkeeping, and reporting requirements for the permanent turbine replacement shall be included in any request for a permanent turbine replacement Note that under the provisions of Regulation No. 6. Part B, Section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the commence construction date for purposes of determining the applicability of NSPS GG requirements). 2.3.2 NSPS for Stationary Combustion Turbines: 40 CFR 60, Subpart KKKK §60.4305 Does this subpart apply to my stationary combustion turbine? AIRS ID: 123/9012 Page 58 of 60 DC Permi LP Col ado De nd Environment Control Division e th o ne o operato .f a sta io ary co b stio turbine h heat input at peak load grea�r than0.' gigaj. les (10 :tu) pe hour, based on th -hgher heating value of the ich c0»a.. as d mod'•p� = r.u,., ",..nstruction bruary 18, 2005, your turbine is subject to this subpart. Only heat input to the combustion turbine should be included when determining whether or not this subpart is applicable to your turbine. Any additional heat input to associated heat recovery steam generators (HRSG) or duct burners should not be included when determining your peak heat input. However, this subpart does apply to emissions from any associated HRSG and duct burners. (b) Stationary combustion turbines regulated under this subpart are exempt from the requirements of subpart GG of this part. Heat recovery steam generators and duct burners regulated under this subpart are exempted from the requirements of subparts Da, Db, and Dc of this part. A Subpart KKKK applicability determination as well as an analysis of applicable Subpart KKKK monitoring, recordkeeping, and reporting requirements for the permanent turbine replacement shall be included in any request for a permanent turbine replacement Note that under the provisions of Regulation No. 6. Part B, Section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the commence construction date for purposes of determining the applicability of NSPS KKKK requirements). 2.4 Additional Sources The replacement of an existing turbine with a new turbine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; a turbine that is being installed as an entirely new emission point and not as part of an AOS-approved replacement of an existing onsite turbine has to go through the appropriate Construction/Operating permitting process prior to installation AIRS ID: 123/9012 Page 59 of 60 DC Permi. , LP 48 C ado De ` n4 ENT .F E OPTING GLYCOL PUMP —„..,,tea►+�. and Environment it P lutio Control Division CENARIO 1. The dehydrator's electric glycol pump 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. A replacement pump shall be the same capacity as authorized in this permit. 2. 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. 3. 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. AIRS ID: 123/9012 Page 60 of 60 Amine Sweetening Unit - Form APCD-206 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 Amine Sweetening 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.s+ovlcdphelapcd. 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: 11 WE1481 AIRS ID Number: 123 / 9012 /001 [Leave blank unless APCO has already assigned a permit # and AIRS ID] Company equipment identification: AM001 [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: O'Connor Plant Site Location: Section 31, T5N, R64W Mailing Address: (include Zip Code) 370 17th St, Suite 2500 Denver, CO 80202 E -Mail Address2: RShankaran@dcpmidstream.com Site Location County: Weld NAICS or SIC Code: 1321 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 371086 A'..coranra Permit Number: 11 WE1481 AIRS ID Number: 123 / 9gi 001 , i [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source -OR- E 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 0 Transfer of ownership3 i] Other (describe below) OR- ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - '7 Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PIE) Additional Info Et Notes: APEN revision being submitted to account for modification to AM001 permit conditions for Permit 11WE1481 Issuance 5. 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: Amine treating unit for CO2 removal Facility equipment Identification: AMo01 For existing sources, operation began on: 10 /09 /2013 For new or reconstructed sources, the projected start-up date is: / 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 Will this equipment be operated in any NAAQ5 nonattainment area Does this facility have a design capacity less than 2 long tons/day of H25 in the acid gas? Form APCD-206 - Amine Sweetening Unit APEN • Revision 04/2017 days/week Yes Yes D 0 weeks/year No No AV; avioshoo Permit Number: 11 WE1481 MRS ID Number: 123 / 001 [Leave blank unless APCD has already assigned a permit # and AIR5 ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: Tital Fabricators Model : T-0196 Serial Number: 10526 Reboiter Rating: 47 MMBtu/hr Absorber Column Stages: 7 trays stages Amine Type: ❑ MEA ❑ DEA ❑ TEA ❑✓ MDEA ❑ DGA Pump Make and Model: Schlumberger RedaHPS # of pumps: 3man +l backup Sweet Gas Throughput4: Design Capacity: Requested: 160 MMSCF/day 58,400 MMSCF/year Actual: 52,397 MMSCF/year Requested values will become permit limitations. Requested limit(s) should consider future process growth Inlet Gas: Pressure: 900 psig Temperature: 9O °F Rich Amine Feed: Pressure: 912.7 psia Flowrate: 826.4 Gal/min Lean Amine Stream: Temperature: 130.7 °F Pressure: 924.7 psia Temperature: 120.4 °F Flowrate; 780 Gal/min Wt. % amine: 5O Mole loading H2S 5.1E-6 Mole Loading 0 007 Coe • Sour Gas Input: Pressure: 898 psia Flowrate: 16 0 MMSCF/Day Temperature: 90 °F NGL Input: Pressure: Flowrate: psia Gal/min Temperature; 'F Flash Tank: ❑ No Flash Tank Pressure: 747 psia Temperature: 133 ' F Additional Required Information: ❑ Attach a Process Flow Diagram ❑ Attach the simulation model inputs Et emission report ❑ Attach composition reports for the rich amine feed, sour gas feed, NGL feed, Et outlet stream (emissions) ❑ Attach the extended gas analysis (including BTEX Et n -Hexane, H2S, CO2, temperature, and pressure) Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 tplyy COL OR OLOR A40 Permit Number: 11WE1481 AIRS ID Number: 123 /9a/ 001 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack information Geographical Coordinates (Latitude/Longitude or UTM) 40.352206/-104.587772 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. ('r•) Flow Rate (,4 MIA) Velocity (ftlsec) AM001 I Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (cheek one) ▪ Circular Interior stack diameter (inches): ❑ Upward with obstructing raincap ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 A[�a7f CDL ON ArPo 4 I AJ.J�I.�V7' Permit Number: 11 WE1481 AIRS ID Number: 123 001 [Leave blank unless APCD has already assigned a permit t. and AIRS ID] Section 6 - Control Device Information a VRU: Used for control of: Amine flash stream Size: Make/Model: Requested Control Efficiency 100 VRU Downtime or Bypassed 5 Li Combustion ** Li Device: Used for control of: Acid Gas Stream Rating: 4.00 Type: RTO Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency MMBtu/hr Make/Model: Anguil/100 95 99 Minimum Temperature: 1550 Waste Gas Heat Content 13.45 Btu/scf Constant Pilot Light: ❑ Yes ✓❑ No Pilot burner Rating MMBtu/hr ❑ Other: Used for control of: Flash Tank Emissions Description: Control Efficiency Requested During VRU downtime, emissions routed to Plant Flare 95 ** During annual permitted RTO downtime (2.74 %) , emissions will be safely vented to the atmosphere. Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 VCOLORADO Permit Number: 11 WE14$1 AIRS ID Number: 123 198/ 001 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 -Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ® Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction) Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM 5Ox Hz5 NCI. VOC RTO for amine acid gas / VRU for flash emissions (5% DT to Plant Flare) 95% / 100% (95% during DT) CO HAPs RTO for amine acid gas / VRU for flash emissions (5% DT to Plant Flare) 95% 1100% (95% during DT) Other: From what year is the following reported actual annual emissions data? 201 6 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.) Criteria Pollutant Emissions inventory Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source OP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled (Tons/year) Controlled5 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM Sox Hz5 1.01 lb/MMScf ProMax - 1.0 - 29.7 0.54 lb/MMScf ProMax 0.6 0.03 15.73 1.3 NCI. 0.068 lb/MMBtu AP -42 5.2 92.1 0.3 1.19 1.2 VOC 26.43 lb/MMScf ProMax 4.6 771.72 ,?3. CO 0.31 Ib/MMBtu AP -42 28.4 1.4 5.43 5.5 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. t ' ' Pit l 1/24/1 Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 Av(��j'�.` CO LOA AOO 6 1 +ar N•P R�nn: mm� Permit Number: 11 WE1481 AIRS ID Number: 123 /9h/ 001 [Leave blank unless APCD has already assigned a permit tt and AIRS ID] Section 7 (continued) Non -Criteria Reportable Pollutant Emissions Inventory Pollutant Chemical Abstract Service (CAS) Number Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Uncontrolled (lbs/year) Controlleds (lbs/year) Benzene 71432 3.07 lb/MMScf ProMax 43130.5 2156.5 Toluene 108883 2.55 lb/MMScf ProMax 16107.9 805.4 Ethylbenzene 100414 0.14 lb/MMScf ProMax Xylenes 1330207 0.85 Ib/MMScf ProMax 1143.1 57.2 n -Hexane 110543 0.07 lb/MMScf ProMax 236.5 11.8 2,2,4- Trimethylpentane Other: Metif9 540841 67561 0.39 Ib/MMScf ProMax 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Authorized Person (not a vendor or consultant) Roshini Shankaran Name (please print) 1./i 42014 Date Environmental Engineer Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance ❑� Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692.3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-206 - Amine Sweetening Unit APEN • Revision 04/7017 W cola s3 A0O 7 Y Vepwn.en ofP W.v ii:LV x,allh�uu�pn Ma.i Vo VD(' 32 f • tsoaco Hydrocarbon Liquid Loading APEN - Form APCD-208 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Hydrocarbon Liquid Loading only. If your emission unit does not 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.govicdphelapcd. 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: 11 WE1481 AIRS ID Number: 123/9012 /004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: LO (Changing to LO -1) [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: DCP Operating Company, LP O'Connor Plant Site Location: Section 31, T5N, R64W Mailing Address: (Inc hide zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 E -Mail Address2: RShankaran@DCPMidstream.com 3DCPMidstream.com Site Location County: Weld NAICS or SIC Code: 1321 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 'Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. A 100. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017 I I icNif COLORADO D. par., eih4u, Flea,h ntH _+gym n. Permit Number: I1 WE 1481 AIRS ID Number: 123 /9012 / 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source ❑ Request coverage under construction permit ❑ Request coverage under General Permit GPO7 If General Permit coverage is requested, the General Permit registration fee of $25O must be submitted along with the APEN Filing fee. -OR- O MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name O Change permit limit ❑ Transfer of ownership3 0 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 & Notes: Change ID from LO to LO -1. 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: 10/ 09 /2013 / / Will this equipment be operated in any NAAQS nonattainment area? Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Does this source load gasoline into transport vehicles? Is this source located at an oil and gas exploration and production site? If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Does this source splash fill less than 6750 BBL of condensate per year? Does this source submerge fill less than 16308 BBL of condensate per year? O Yes ❑ No O Yes ❑ No ❑ Yes El No El Yes ❑✓ No LI Yes ❑ No ❑ Yes ❑ No ❑ Yes ❑ No Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 2 14 COLORADO P R"��n+N Pytl1� Hwl.li R Envn..m.ni Permit Number: 11WE1481 AIRS ID Number: 123 / 9012/ 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: El Condensate O Crude Oil ❑ Other: 1 ry If this APEN is being filed for vapors disgraced from cargo carrier, complete the following: /, T c.• ''1 -)Q Requested Volume `'" 1 4 Actual Volume Loaded4: -638-385- Bbl/yr Loaded: 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: (eg, "rail tank cars" or "tank trucks") Tank Trucks 276,476 Bbl/yr If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: True Vapor Pressure 0.6 5.0 Psia ® 60 °F Average temperature of bulk liquid loading: Molecular weight of displaced vapors 52.45 66 Lb/lb-mot If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: 4 Requested values will become Bbl/yr Actual Volume Loaded: 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 Set Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 3 I L3a COLORADO Department al P.61ic Heath Envie...gm Permit Number: 11 WE 1481 AIRS ID Number: 123/9012/004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Geographical Information Geographical Coordinates (Latitude/Longitude or LiTM) 40,3522061-104.587772 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp ( F) now Rate (ACM) Velocity [ftisec) LO -1 20 Indicate the direction of the stack outlet: (check one) ❑r Upward ❑ Downward ❑ Horizontal ❑ Other (describe): Indicate the stack opening and size: (check one) I] Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Section 6 - Control Device Information ❑ Loading occurs using a vapor balance system: Requested Control Efficiency ❑ Combustion Device: Pollutants Controlled: Rating: Type: VOC and HAPs MMBtu/hr Enclosed Combustor Make/Model: John ZinkNC-9127791 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency 98 3b Minimum Temperature: Waste Gas Heat Content 3,677 Btu/scf Constant Pilot Light: r❑ Yes ❑ No Pilot burner Rating 0.06 MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested Form APCD•208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 4 I ,COLOR Permit Number: 11 WE 1481 AIRS ID Number: 123/9012/004 [Leave blank unless APED 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, describe the control equipment AND state the overall control efficiency 1% reduction Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SO„ NO„ CO VOC Enclosed Combustor 95 HAPs Enclosed Combustor 95 Other: ❑ Using State Emission Factors (Required for GP07) VOC D Condensate ❑ Crude 0.236 Lbs/BBL 0.104 Lbs/BBL Benzene n -Hexane 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? 2016 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions .Requested Annual Permit Emission Limit(s)5 Uncontrolled (Tons/year) Controlled5 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM SO, NO, 0,138 lb/MMBtu TNRCC 0.14 0.14 0.59 0.59 VOC CO 0.202 0.5496 lb/bbl AP -42 27.98 1.40 64.58 3.24 Ib/MMBtu TNRCC 0.31 0.31 1.20 1.20 Benzene Toluene 0.0027 Ib/bbl LiquidAnahyshs - 'V,62 0.86 _ 0.04 0.0075 lb/bbl Liquid Anaiysis 9.20) O -B , ,65: 2.38 0.12 5 /)lt Ethylbenzene 0.0006 lb/bbl Liquid Analysis t1J30•0,( 1768 0.18 0.01 Xylenes 0.0056 lb/bbl Liquid Analysis dOl Z 11 -6:flep5eyg 1.80 0.09 n -Hexane 0.0145 lb/bbl Liquid Analysis -1 -83-7,ty) 960,10 4 62 0.23 2,2,4-0.00001 Trimethylpentane ylp lblbbl Liquid Analysis —0:000.01 1)700- 3.42E-03 1.71E-04 Other: I 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 211i 5Annual emission fees will be based on actual controlled emissions reported. If source has nut yet started operating, l ve blenk- Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO I Ltxvtmcnld hhlic J HMIh 5Envl.uu.xinl Permit Number: 11 WE1481 AIRS ID Number: 12319012/004 [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 8 - Applicant Certification l 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 Authori -d Person (not a vendor or consultant) Date Dana Stephens NBU/MidCon Air Permitting Manager 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 registration fee of $250 as applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 6 I i NCOLDRgu41i B ivmem1oni Condensate Storage Tank(s) . PE -- 41920/7 Form APCD-205 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loadings, 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: 11WE1481 AIRS ID Number: 123 / 9012 / 005 [Leave blank unless APCD has already assigned a permit fl and AIRS ID] Section 1 - Administrative Information Company Name1: Site Name: Site Location: DCP Operating Company, LP O'Connor Plant Site Location Section 31, T5N, R64W County: Weld Mailing Address: p Code) 370 17th Street, Suite 2500 (Include Zip Code) Denver, CO 80202 NAICS or SIC Code: 1321 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail Address2: RShankaran@DCPMldstream.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. z Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 02/2017 366323 ilJiff COL Ol l C. Permit Number: 11 WE1481 AIRS ID Number: 123 / 9012 / 005 [Leave bLank unless APCD has already assigned a permit !t and AIRS ID] 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 ❑Q MODIFICATION to existing permit {check each box below that applies) ❑ Change in equipment ❑ Change company name d❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit exempt/grandfathered source Additional Info a Notes: Correction in emissions to reflect 4 tanks rather than 8 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 (4) stabilized condensate tanks For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 10/09/2013 ❑ Exploration Et Production (EI:tP) site days/week 52 weeks/year 0 Midstream or Downstream (non EEtP) site Will this equipment be operated in any NAAQS nonattainment area? IS Yes Yes ■ No No Are Flash Emissions anticipated from these storage tanks? ■ IS Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? ❑✓ Yes ■ No If "yes", identify the stock tank gas -to -oil ratio: 0.71 m3/ iter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-i05. ❑ Yes ' No Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? ❑ Yes No U Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 02/2017 WIC4L0H ADO I , Permit Number: 11 WE1481 AIRS ID Number: 123 / 9012 / 005 [Leave blank unless APC] has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/year) Requested Annual Permit Limit4 (bbl/year) Condensate Throughput: 276,476 638,229 From what year is the actual annual amount? Average API gravity of sales oil: 65.35 degrees Tank design: r❑ Fixed roof ❑ Internal floating roof 2016 RVP of sales oil: 10 ❑ External floating roof Storage Tank ID ft of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) TANKS 4 1,600 10/2013 Wells Serviced by this Storage Tank or Tank Battery5 (EaP Sites Only) API Number Name of Well Newly Reported Well ■ 0 4 Requested values wilt become permit limitations. Requested limit(s) should consider future growth. 5 The E&P Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.352206/-104.587772 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (CF) Flow Rate (ACFM) Velocity (ft/sec) TANKS 20 Indicate the direction of the stack outlet: (check one) ▪ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) r❑ Circular ❑ Square/rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches); Interior stack width (inches): Interior stack depth (inches): Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 02/7017 3 1 c OLO ri An Permit Number: 11WE1481 AIRS ID Number: 123 /9012 / 005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make /Model: Combustion Device: Pollutants Controlled: VOC and HAPs Rating: Type: Enclosed Combustor MMBtu/hr VC. ""°%t23• ` Make/Model: Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 John Zink/VD-91 1 Minimum Temperature: Waste Gas Heat Content: Constant Pilot Light: ❑r Yes ❑ No Pilot Burner Rating: 3,677 0.06 Btu/scf MMBtu/hr ❑ Closed Loop System Description of the closed loop system: E Other: Pollutants Controlled: VOC Description: Emissions routed to plant flare during EC DT. Control Efficiency Requested: 95 Section 7 -Gas/Liquids Separation Technology Information (E£tP 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 02/2017 4 Permit Number: 11 WE1481 AIRS ID Number: 123 19012 1 005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) VOC Enclosed Combustor 95 NOx CO HAPs Enclosed Combustor 95 Other: From what year is the following reported actual annual emissions data? 2016 Criteria Pollutant Emissions Inventory Pollutant VOC Emission Factor6 Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Requested Annual Permit Emission Limit(s)4 Controlled Uncontrolled Emissions7 Emissions (Tons/year) (Tons/year) 0.1032 lb/bbl TANKS 4.09d N Ox 0.138 Ib/MMBtu 17.97 0.90 TNRCC 0.05 0.05 32.96 Controlled Emissions (Tonslyear) 1.66 0.18 0.18 CO 0.550 Ib(MMBtu TNRCC 0.20 0.20 0.52 0.52 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor6 Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, I Mfg. etc) g Uncontrolled Emissions Pounds/ ear (Pounds/year) ) Controlled Emissions7 (Pounds) year) Benzene 71432 0.0014 lb/bbl TANKS4.09d 876 44 Toluene 108883 0.0038 lb/bbl TANKS 4.09d 2,426 121 Ethylbenzene 100414 0.0003 lb/bbl TANKS 4.09d TANKS4.09d 181 1,834 9 92 Xylene n -Hexane 1330207 0.0029 lb/bbl 110543 0.0074 Iblbbl TANKS 4.09d 4,711 236 2,2,4- Trimethylpentane 540841 5.47E-06 lb/bbl TANKS4.09d 3.5 0.2 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. ' Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 02/2017 5 1 d COLCrlA6o ii••:i�.b�r�.ri:ni. rl Permit Number: 11 WE1481 AIRS ID Number: 123 / 9012 / 005 [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. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. r • ��81zor� 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 O Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, I!,C, for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd a�oRhPq Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 02/2017 6 I litY � l Fugitive Component Leak Emissions APEN - Form APCD-203 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.Qov/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: 11 WE1481 AIRS ID Number: 123 / 9012/006 [Leave blank unless APCD has already assigned a permit a and AIRS ID] Section 1 - Administrative information Company Name1: Site Name: Site Location: DCP Operating Company, LP O'Connor Plant Section 31, T5N, R64W Mailing Address: 870 17th St, Suite 2500 (Include bp Code) Denver, CO 80202 Permit Contact: Roshini Shankaran E -Mail Address2: RShankaran@dcpmidstream.com Site Location Weld County: NAICS or SIC Code: 1321 Phone Number: (303) 605-2039 7 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. 371087 Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 1 Permit Number: 1 I VVE 14$ I AIRS ID Number: 123 / 9012 / 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source (check one below) -OR - • MODIFICATION to existing permit (check each box below that applies) ❑ Change process 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 - ▪ APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: APEN is being submitted per request to notify that the emission point FUG contains components subject to NSPS 0000 & 0000a. 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: 10/19/2013 For new or reconstructed sources, the projected start-up date is: ❑� Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source hours/day days/week Operation: Facility Type: ❑ Well Production Facility4 ❑ Natural Gas Compressor Station4 El Natural Gas Processing Plant4 O Other (describe): weeks/year 4 When selecting the facility type, refer to definitions in Colorado Regulation No. 7, Section XVII. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 712017 2 I JS .00LO5.6OO Permit Number: 11WE1481 AIRS ID Number: 123 / 9012/ 006 [Leave bLank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Regulatory Information What is the date that the equipment commenced construction? 10/09/2013 & 6/16/2017 Will this equipment be operated in any NAAQS nonattainment area?5 E 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 0000? 0 Yes ❑ No Is this equipment subject to 40 CFR Part 60, Subpart 0000a? El Yes ❑ No Is this equipment subject to 40 CFR Part 63, Subpart HH? 0 Yes ❑ No Is this equipment subject to Colorado Regulation No. 7, Section XII.G? 0 Yes ❑ No Is this equipment subject to Colorado Regulation No. 7, Section XVII.F? ❑ Yes r❑ No Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? ❑ Yes ❑r No 5 See htttK_IIwww__cc2LuFadb.govlccfphc,Istate•irr!p ementation•plans-sips for which areas are designated as attainment/non attainment. Section 5 - Stream Constituents ❑ 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. Stream VOG (wt %) Benzene (wt %) Toluene (wt %) Ethylbenzene (wt %) Xylene (wt %) n -Hexane (wt %) 2,2,4 Trimethylpentane (wt %) Gas 29.42 0.05 0.03 0.0005 0.005 0.3 - Heavy Oil (or Heavy Liquid) _ - ' Light Oil (or Light Liquid) 1 00 Water/Oil _ - - - - - - * Please note that the facility is currently designated an area source of HAP. Once all equipment permitted for the O'Connor 2 train commences operation, the facility will become a major source of HAP. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 !cola RA00 3 ,.:,- Permit Number: 11WE1481 WE 1481 AIRS ID Number: 123 / 9012 / 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Geographical Information Geographical Coordinates (Latitude/Longitude or UTM) 40.352206/-104.587772 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 0000/0000a ✓❑ 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: ❑ No LDAR Program 6 Attach other supplemental plan to APEN form if needed. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 Av,cotprrApo 4I Permit Number: 11WE1481 AIRS ID Number: 123 / 9012 / 006 [Leave blank unless APCD has already assigned a permit /I and AIRS ID] Section 8 - Emission Factor Information Select which emission factors were used to estimate emissions below. If none apply, use the table below to identify the emission factors used to estimate emissions. Include the units related to the emission factor. r❑ Table 2-4 was used to estimate emissions7. ❑ Table 2-8 (< 10,000ppmv) was used to estimate ernissions7. Use the following table to report the component count used to calculate emissions. The component counts listed in the following table are representative of: O Estimated Component Count El Actual Component Count conducted on the following date: October 2017 Service Equipment Type Connectors Flanges Open-Ended Lines Pump Seals Valves Other9 Gas Counts 7736 1144 0 22 1833 9 Emission Factor 4.40E-04 8.60E-04 - 2.86E-02 9.92E-03 1.94E-02 Units lb/hr/source lb/hr/source lb/hr/source lb/hr/source lb/hr/source lb/hr/source Heavy Oil (or Heavy Liquid) Counts - - - - - - Emission Factor - - .. .. - - Units .. - - - - ., - Light Oil (or Light Liquid) Counts 3283 1058 6 0 2676 6 Emission Factor 4.63E-04 2.43E-04 - - 5.51 E-03 1.65E-02 Units lb/hr/source lb/hr/source - - lb/hr/source lb/hr/source 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-453IR- 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 7/2017 CO L OR A 00 Hrt•�IR b �v�len Moni Permit Number: 11WE1481 AIRS ID Number: 123 /9012/ 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Criteria and Non -Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. 2016 From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions and non -criteria pollutant (HAP) emissions from source: Use the data reorted in Section 8 to calculate these emissions. Chemical Name CAS Number Actual Annual Emissions Requested Annual Permit Emission Limit(s) Uncontrolled (tons/year) Controlled10 (tons/year) Uncontrolled (torts/year) Controlled" (tons/year) Voc 82.59 26.4 120.61 38.8 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? f yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name CAS Number Actual Annual Emissions Requested Annual Permit Emission Limit(s) Uncontrolled (lbs/year) Controlled9 (lbs/year) Uncontrolled (lbs/year) Controlled7° (lbs/year) Benzene Toluene 71432 301.79 96.6 2326 780 108883 153.22 49.1 6161 2080 Ethylbenzene 100414 2.72 0.9 454 154 Xylene 1330207 27.16 8.7 4602 1557 n -Hexane 110543 1784.76 571.5 _ 14490 4758 2,2,4 Trimethvlpentane 540841 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-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 6 I AV COLORADO Permit Number: 11WE1481 AIRS ID Number: 123 / 9012/ 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 10 - 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) Roshini Shankaran Date Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: EI,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 Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.cotorado.gov/cdphe/apcd Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD) website at: www_coloraclo_povlcdphelapcd. JUL 192017 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: II VvH 14K AIRS ID Number: 12 3 iqo i '0 (0 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: O'Connor 2 Gas Plant Site Location: Section 31, T5N, R64W Mailing zip Code) Address: 370 17th Street, Suite 2500 (Includ Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1 321 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E•Mail Address2: RShankaranADCPMidstrearr.com 1 Use the full, Legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-200 - General APEN - Revision 1/2017 366333 COLORADO fatTLn�.L. mUcn Permit Number: AIRS ID Number: ! / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action NEW permit OR newly -reported emission source (check one below) ❑r STATIONARY source ❑ PORTABLE source -OR - N MODIFICATION to existing permit (check each box befow that applies) ❑ Change fuel or equipment ❑ Change company name Acid 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 Et Notes: Flare for maintenance and SSM purposes 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 Manufacturer: Zeeco Model No.: HSLF 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 Seasonal use percentage: Dec -Feb: Mar -May: Form APCD-200 - General APEN - Revision 1/2017 days/week weeks/year Jun -Aug: Sep -Nov: cAq! 2I AL):d COLORADO Uep.NnenI (PunUc HaIW btnrlrunnhuIu Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use ❑r Check box if this information is not applicable to source or process From what year is the actual annual amount? Description Design Process Rate (Specify Units) Actual Annual Amount (Specify Units) Requested Annual Permit Limit4 (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) 40.352206/-104.587772 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. (•F) Flow Rate (ACFM) Velocity (ft/sec) FLARE -2 120 Indicate the direction of the stack outlet: (check one) ❑r Upward ❑ Horizontal. ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Upward with obstructing raincap E Circular Interior stack diameter (inches): 16 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): se na Form APCD-200 - General APEN • Revision 1/2017 3 [ 41cV COLORADO 4epa.tp , Permit Number: AIRS ID Number: I I [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment Ft Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTU/hr) Actual Annual Fuel Use (Specify Units) Requested Annual Permit Limit4 (Specify Units) 0.2 (Pilot Only) 107.13 MMscf/yr (Waste/Purge Gas) From what year is the actual annual fuel use data? Indicate the type of fuel used5: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) Nat ► r Fi l ur as ❑ Ultra Low Sulfur Diesel ❑ Propane ❑ Coal ❑� Other (describe): Heating value: IS BTU/SCF (assumed fuel heating value of 138,000 BTUlgallon) (assumed fuel heating value of 2,300 BTU/SCF) Heating value: Residue gas BTU/Ib Ash Content: Sulfur Content: Heating value (give units): 1203 Btu/scf 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 Description Overall Collection Efficiency Overall Control Efficiency (% reduction in emissions) TSP (PM) PM15 PM2.5 SO„ NO, CO VOC Flare 100% 95% Other: HAPs - Flare 100% 95% Form APCD-200 - General APEN - Revision 1/2017 4, AV COLORADO n .,am'4unu: Permit Number: AIRS ID Number: I I [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 re anted in Sections 4 and 6 to calculate these emissions.) Pollutant Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) Requested Annual Permit a Emission Limits) Uncontrolled (Tons/year) Controlled6 (Tons/year) Uncontrolled (Tons/year) Controlled (Tonslyear) TSP (PM) PM,a 7.6 Ib/MMscf AP -42 0.01 0.01 7.6 Ib/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 0.03 0.03 NO, S. / X11 LAP -42 471-7 ii, Gl q,ri co 3D -L 1 %.'11y.,=AP-42 -20705v1X0 20-0.5.;, VDC - 4Ib/MMscf Site -specific s61, (. ,Q Other: tc`' ' ro . rtijr,61rd 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. r„y,,Fki,y) 81. c, `{ " 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 250 lbs/year? II] Yes I]No If yes, use the fol[owin table to report the non -criteria pollutant (HAP} emissions from source: CAS Number8 Chemical Name Overall Control Efficiency Uncontrolled Emission Factor Cf6 15L � Emission Factor Source (AP -42, Mfg. etc) Uncontrolled Actual Emissions abslvear) Controlled Actual Emissions (lbslyear) ?-1.1n-Ps q S % 1i [it) 01 10O l'elm,k, .z^6, yc�( 1 .� { ! . LTA =2) 3 i 9 a Z k �f 16, k110_,,Ae.5 c L 1-S q 35 LI `} ft-. jOireAuh.L. l 4104. 60 'f33.4, g1 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. E12i Form APCD-200 - General APEN - Revision 1/2017 COLORADO Uapmhnxnl ofh. U HmIJ�6Ei.u�ioumaxt Permit Number: AIRS ID Number: r / [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. 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: 0 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 Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692.3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 COLORARO Form APCD-200 - General APEN - Revision 1/2047 6 I Condensate Storage Tank(s) APEN Form APCD-205 JUL 192017 Air Pollutant Emission Notice (APEN) and Application for Construction Permit Ail 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 Loadings, 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/cdpheiair-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: AIRS ID Number: 12.3 / 12. / 0' El [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Hamel: Site Name: DCP Operating Company, LP O'Connor 2 Gas Plant Site Location: Section 31, T5N, R64W Mailing Address: (incluck ZpCode) 370 17th Street, Suite 2500 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1321 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail Address: 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. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 02/7017 386332 J ICOL0RAG0 wTrinrml Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ® NEW permit OR newly -reported emission source ❑ Request coverage under traditional construction permit O Request coverage under a General Permit ❑ GPOI ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. - OR MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment O Change company name ❑ Change permit limit ❑ Transfer of ownership3 ,® Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit exempt/grandfathered source Additional Info €t Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: For existing sources, operation began am Four (4) 1,000 bbl stabilized condensate tanks For new or reconstructed sources, the projected start-up date is: TBD Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 days/week 52 weeks/year ❑ Exploration Et Production (EfP) 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 0 No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? IS Yes • No If "yes", identify the stock tank gas -to -oil ratio: 0.70 m3/ iter Are these storage tanks subject to Colorado OIL and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes Q No • Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes O No • Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 02/2017 2I A COLOFFAd4 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bb(lyear) Requested Annual Permit Limit4 (bbl[ year) ICondensate Throughput: From what year is the actual annual amount? Average API gravity of sales oil: Tank design: E Fixed roof degrees ❑ Internal floating roof 1,642,500 RVP of sales oil: ❑ External floating roof Storage Tank !D # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bb() Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) TBD 4 4,000 Wells Serviced by this Storage Tank or Tank Elattery5 (EEtP Sites Only) API Number Name of Well Newly Reported Well ■ - ❑ ■ M ■ 4 Requested values will become permit limitations. Requested timit(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 UM) 40.352206/-104.587772 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ftlsec) TANKS -2 120 Indicate the direction of the stack outlet: (check one) O Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) O Circular ❑ Square/rectangle ❑ Other (describe): O Upward with obstructing raincap Interior stack diameter (inches): 16 Interior stack width (inches): Interior stack depth (inches): Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 02/2017 3 I A cvRanaov Permit Number: AIRS ID Number: I 1 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor ❑✓ Recovery Unit (VRU): ❑ Combustion ET., Device: Pollutants Controlled: VOC and HAPs Size: Make/Model: Requested Control Efficiency: 100 VRU Downtime or Bypassed (emissions vented): 2 Pollutants Controlled: VOC and HAPS Rating: MMBtu/hr Type: l# e_ s�lIake/Model.ZEECO/HSLF ^r l F 9t) l 0 0,_ Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: Waste Gas Heat Content: Constant Pilot Light: ❑r Yes ❑ No Pilot Burner Rating: 0.20 Btu/scf MMBtu/hr ❑ Closed Loop System Description of the closed Loop system: ❑r Other: Pollutants Controlled: VOC/HAP (2% VRU DT only) Description: Plant Flare Control Efficiency Requested. 95 Section 7 -Gas/Liquids Separation Technology Information (EFtP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Describe the separation process between the well and the storage tanks: -L RA06 Form APCD-2O5 - Condensate Storage Tank(s) APEN - Revision O2/2017 4 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency ('3u reduttloni: Pollutant Description of Control Method(s) ¢ Cl Overall Requested Control Efficiency f% reduction in emissions) V0C Tank emissions controlled by VRLI. Emissions routed to PfsntRare during VRU downtime. 100 (2% DT at 95%( N0x CO ;-?.....!:3), HAPs Tank emissions controlled by VRU. Emissions routed to Po.%.r-mrr during VRU downtime. 100 (2% DT at 95%) Other: From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor6 Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) VOC - e@ O, « Ibibbl TANKS 4.09d 0.08 1.C5S4.7 NOx _ 0.068 Ib/MMl3tu AP -42 0.003 0.003 CO 0.31 Ib/MMBtu AP -42 0.01 0.01 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) { ) Number Emission Factor6 ``� Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg. etc g ) Uncontrolled Emissions (Pounds/year) { y ) Controlled Emissions7 (Pounds/year) Benzene 71432 2 Toluene 108883 (,3() 9 (p Ethylbenzene 100414$'61 Xylene 1330207 1'16°3 S' _ n -Hexane 110543 i t22 t 2,2,4- Trimethylpentane 540841 CI 1 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. P4eag-ii • AP&NCRP-tI lit -exceed 250 Iblyr - Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 02/2017 5 J1�7T�IJI COLORADO Permit Number: AIRS ID Number: [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. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that this source is and wilt be operated in full compliance with each condition of the applicable General Permit. 1 Ir8/2_or� 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: 0 Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, Ii.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 02/2017 C4LOAApP 6 1 I R=.1.=.--....;„ Fugitive Component Leak Emissions APEN - Form APCD- 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,Uovlcclpheitocd. 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: }9 2011 AIRS iD Number: 12 3 /qoi/_/ 012_ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: Site Name: DCP Operating Company, LP O'Connor 2 Gas Plant Site Location: Section 31, T5N, R64W Mailin ge dp Code) d ess: 370 17th Street, Suite 2500 (inc Denver, CO 80202 Permit Contact: Roshini Shankaran E -Mail Address2: RShankaran@DCPMidstream.com Site Location Weld County: NAICS or SIC Code: 1321 Phone Number: (303) 605-2039 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 addreaEd13e3 3 Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 5/2017 1 `caio eoo r Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ® NEW permit OR newly -reported emission source (check one below) -OR- YAA X MODIFICATION to existing permit (check each box below that applies) '5i\%° ❑ Change process or equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership3 D Other (describe below) - OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT Ac norm - ❑ APEN submittal for permit exempt/grandfathered source Additional Info Ft Notes: Add point to existing permit 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: TB D 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: Facility Type: ❑ Well Production Facility4 ❑ Natural Gas Compressor Station O Natural Gas Processing Plant4 ❑ Other (describe): hours/day days/week weeks/year 4 When selecting the facility type, refer to definitions in Colorado Regulation No. 7, Section XVII. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 5/2017 21 tOtdfzs.utl Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Regulatory Information What is the date that the equipment commenced construction? NA Will this equipment be operated in any NAAQS nonattainment area?5 ❑✓ 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 0 No located at this facility? Is this equipment subject to 40 CFR Part 60, Subpart KKK? ❑ Yes ❑r 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? ❑✓ Yes ❑ No Is this equipment subject to 40 CFR Part 63, Subpart HH? ✓❑ Yes ❑ No Is this equipment subject to Colorado Regulation No. 7, Section XII.G? ❑ Yes ❑ No Is this equipment subject to Colorado Regulation No. 7, Section XVILF? ❑ Yes ❑✓ No is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? ❑ Yes No 5 See Fitto: / lwww.roiorado.eov/cdohe/state•irnplementation-clans-sips for which areas are designated as attainment/non- attainment. Section 5 - Stream Constituents ❑r 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- Stream VOC (Wt %) Benzene (wt %) Toluene (wt %) Ethylbenzene (wt %) Xylene (wt %) n -Hexane (wt %) 2,2,4 Trimethylpentane (wt %) Gas 28.09 0.0653 0.0929 0.0103 0.0307 1.4216 0.0628 Heavy Oil (or Heavy Liquid) Light Oil (or Light Liquid) 100 0.2326 0.3308 0.0365 0.1091 5.0607 0.2236 Water/Oil Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 5/2017 .AVil¢ICoLu0n DO Permit Number: AIRS ID Number: I I [Leave blank unless APCD has already assigned a permit ti and AIRS ID] Section 6 - Geographical Information Geographical Coordinates (Latitude/Longitude or UTM) 40.352206/-104.587772 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% tight 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 0 Monthly Monitoring - Control: 96% gas valve, 95% light liquid valve, 86% light liquid pump, 81% connectors ❑ LDAR per Colorado Regulation No. 7, Section XVII.F ❑ Other6: ❑ No LDAR Program 6 Attach other supplemental plan to APEN form if needed. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision ' tv 5/2017 4 I AIT COLORADO Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emission Factor Information Select which emission factors were used to estimate emissions below. If none apply, use the table below to identify the emission factors used to estimate emissions. Include the units related to the emission factor. ❑✓ Table 2-4 was used to estimate emissions'. ❑ Table 2-8 (< 10,000ppmv) was used to estimate emissions'. 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: Service Equipment Type Connectors Flanges Op Li Lines Pump Seals Valves Other9 Gas Counts 15,258 1,031 3,652 61 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) Count8 Emission Factor Units Light Oil (or Light Liquid) Count8 2,524 494 36 1,224 14 Emission Factor 0.000463 0.000243 0.028660 0.005512 0.016535 Units lb/hr/component lb/hr/component Ib/hrlcomponent lb/hr/component lb/hr/component Water/Oil Count8 Emission Factor Units 7 Table 2.4 and Table 2.8 are found in U.S. EPA's 9995 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 5/2017 sew co[O .DD 5 I - ' `G,N.... gY Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] 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? 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-) Chemical Name CAS Number Actual Annual Emissions Requested Annual Permit Emission Limit(s) Uncontrolled (tons/year) Controlledl0 (tons/year) Uncontrolled (tons/year) Controlied1l (tans/year) VOC 134.58 21.52 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: Chemical Name Benzene Toluene CAS Number Actual Annual Emissions Requested Annual Permit Emission Limit(s) Uncontrolled (lbslyear) Controlled9 (fbslyear) Uncontrolled (lbslyear) Controlled1° (lbslyear) 71432 108883 626 100 890 142 Ethylbenzene 100414 Xylene 1330207 294 47 n -Hexane 110543 13,621 2,178 2,2,4 Trimethvloentane 540841 602 96 Other: 10 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. ii Requested values will become permit limitations. Requested limit(s) should consider future process growth, component count variability, and gas composition variability. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 5/2017 6 ICCLOIIARO Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS JD] Section 10 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Vtgl2orl 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: Q 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 Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 5/2017 E71 coLes ADO Nwi M1 Grn�e�i �a.��ni General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control. Division (APCD) website at; www.colorado.pov/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: 11 WE 1481 AIRS ID Number: 123 /9012 /013 [Leave blank unless APCD has already assigned a permit R and AIRS ID] Section 1 - Administrative Information Company Named: DCP Operating Company, LP Site Name: O'Connor 2 Gas Plant Site Location: Section 31, T5N, R64W Mailing Address: 370 17th Street, Suite 2500 (include Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1321 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail Address: 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. Form APCD-200 - General APEN - Revision 1/2017 314099 i COLORADO fati 1 I [TV.T P,�arlmeN of PuLLlc Hul 4 6 Tnri�wimoni Permit Number: 11WE1481 AIRS ID Number: 123 /9012 /013 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑✓ NEW permit OR newly -reported emission source (check one below) ❑✓ STATIONARY source ❑ PORTABLE source - 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 Et Notes: Solar T70 Turbine 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: Used for residue gas compression. Annual operation 8760 hrs/yr. Natural gas compression turbine - one 9,071 hp turbine. Manufacturer: Solar Model No.: T70 Serial No.: TBD Company equipment Identification No. (optional): TURB-1 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: TBD ❑r Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Seasonal use percentage: Dec -Feb: Mar -May: days/week weeks/year Jun -Aug: Sep -Nov: Form APCD-200 - General APEN - Revision 1/2017 2 I AV COLORADO o.N,imeni m focus H.a1ih b Fnui[urirtie�� Permit Number: 1 I WE 1481 AIRS ID Number: 123 /9012/013 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Materia[ Use 0 Check box if this information is not applicable to source or process From what year is the actual annual amount? Description Design Process Rate (Specify Units) Actual Annual Amount (Specify Units) Requested Annual Permit Limit4 (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) 40.352206/-104.587772 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack ID No. Discharge Height Ground Level (feet) Temp. t•F) if') Flow Rate (ACFM) Velocity (ftlsec) TURB-1 45 941 111,056 147 indicate the direction of the stack outlet: (check one) ,❑ Upward E Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Upward with obstructing raincap 0 Circular Interior stack diameter (inches): 48 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches); ❑ Other (describe): Form APCD-200 - General APEN - Revision 1/2017 3 I AV COLORADO Dg',rIinea =iwcuf. Permit Number: 11 WE 1481 AIRS ID Number: 123 /9012/ 013 [Leave blank unless APCD has already assigned a permit # and AIRS 1D] 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) Design Input Rate (MMBTU/hr) Actual Annual Fuel Use (Specify Units) Requested Annual Permit Limit4 (Specify Units) 73 MMBfulhr 609.18 MMscf/yr 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: 1 Q50 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): 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? ❑ Yes E No If yes, describe the control egaipwont AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Collection Efficiency Overall Control Efficiency (% reduction in emissions) TSP (PM) Palo PM2.5 SO, NO„ CO VOC Other: Form APCD-200 - General APEN - Revision 1/2017 4 I AV COLORADO PAM,heF I,',�ima�l Permit Number: 11WE1481 AIRS ID Number: 123 /9012 1013 [Leave blank unless APCD has already assigned a permit # and AIRS 1D] Section 7 (continued) From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: {Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor (Specify Units) Emission Factor Source Mfg. etc Actual Annual Emissions, Requested Annual Permit Emission Limit(s)4 Uncontrolled (Tons/year) Controlled' d' Uncontrolled (Tons/year) ) (Tons/year) Controlled (Tons/year) TSP (PM) 5.85E-3Ib/MMBtu Manufacturer 1.87 1.87 PM10 5.85E-3Ib/MMBtu Manufacturer 1.87 1.87 PM2,s 5 B5E-3 Ib/MMBtu Manufacturer 1.87 1.87 SOx 3.40E-3Ib/MMBtu AP -42 1.09 1.09 NO, CO 3.97E-021b/MMBtu Manufacturer 12.70 12.70 5,51E-021'/MMBtu Manufacturer 17.61 17.61 VOC 2.10E-31b/MMB1u AP -42 0.67 0.67 Other: 4 Requested values will become permit limitations. Requested limits) 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 250 lbs/year? Q Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number' Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (specify units) Emission Factor Source {AP 42, Mfg. etc) Uncontrolled Actual Emissions abs/year) Controlled Actual Emissions' (16slyear) 50-00-0 Formaldehyde 0% 7.10E-4IbtMMBtu AP -42 454 454 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN - Revision 1/2017 zy bcoLoRaoa 5 I eryrxnenl olPElk xca1M1 6 Eneiruninani Permit Number: 11 WE 1481 AIRS ID Number: 123 /9012 / 013 [Leave blank unless APCD has already assigned a permit tt 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. Date Signature of Legally Authorized Person (not a vendor or consultant) 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 Environment Air Pollution Control Division APCD-SS-B1 43O0 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/aped Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-200 - Genera' APEN - Revision 1/2017 TCO L9R hp❑ k• Lff.14F.._—.. General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD) website at: ww w. co to ra do . Pov! cdp h el ap cd. 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: 11 WE 1481 AIRS ID Number: 123 /9012 / 014 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Site Name: Site Location: DCP Operating Company, LP O'Connor 2 Gas Plant Section 31, T5N, R64W Mailing Address: 370 17th Street, Suite 2500 (Include zip Code) Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1321 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail AddressZ: RShankaran@DCPM]dstream.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 a -mail to the address provided. Form APCD-200 - General APEN - Revision 1/2017 374100 COLORADO 1 I y� q b.yn,�en = wtic Xe,Nih b Fnvlianmvnl Permit Number: 11 WE 1481 AIRS ID Number: 123 / 9012 /014 [Leave blank unless APCD has already assigned a permit # and AIRS ID} Section 2- Requested Action • NEW permit OR newly -reported emission source (check one below) ❑r 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: Solar T70 Turbine 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: Used for residue gas compression. Annual operation 8760 hrs/yr. Natural gas compression turbine - one 9,071 hp turbine, Manufacturer: Solar Model No.: T70 Company equipment Identification No. (optional): TURB-2 For existing sources, operation began on: Serial No.: TBD 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 I A COLORADO Permit Number: 11 WE 1481 AIRS ID Number: 123 /9012/014 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use E Check box if this information is not applicable to source or process From what year is the actual annual amount? Description Design Process Rate (Specify Units) Actual Annual Amount (Specify Units) Requested Annual Permit Limit4 (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) 40.352206/-104.587772 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack ID No. discharge Height Above Ground Level (Feet) Temp. (•F) Flow Rate (ACFsJ Velocity (ftAsec) TURB-2 45 941 111,056 147 Indicate the direction of the stack outlet: (check one) ▪ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) E Upward with obstructing raincap E Circular Interior stack diameter (inches): 48 ❑ Square/rectangle ❑ Other (describe): Interior stack width (inches): Interior stack depth (inches); Form APCD-200 - General APEN - Revision 1/2017 3 1 A COLORADO B.,uennmi'I Ll�e Hc�i�MSF ��m.n�nl Permit Number: 11WE1481 AIRS ID Number: 123 /9012/ 014 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment Et Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMHTU/hr) Actual Annual Fuel Use (Specify Units) Requested Annual Permit Limit4 (Specify Units) 73 MMBtu/hr 609.18 MMscf/yr From what year is the actual annual fuel use data? Indicate the type of fuel useds: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 8TU/5CF) E Field Natural Gas Heating value: 1,050 BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTUISCF) ❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content: ❑ Other (describe): Heating value (give units): 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? ❑ Yes ❑r No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Collection Efficiency Overall Control Efficiency (96 reduction in emissions) TSP (PM) PAD PM2,5 SO, NOX CO VOC Other: Form APCD-200 - General APEN - Revision 1 /2017 T �aLoeaoa 4 � xwtie�u„o':�, Permit Number: 11 WE 1481 AIRS ID Number: 123 /9012 /014 [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? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions. Pollutant Uncontrolled Emission Factor (Specify Units) Emission Factor Source (Ap-42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled (Tons year) Controlled' (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) 5.85E-3 [b/MMBtu Manufacturer 1.87 1.87 PM1❑ 5.85E-3 Ib/MMBtu Manufacturer 1.87 1.87 PM2.s 5.85E-3Ib/MMBtu Manufacturer 1.87 1.87 SO, 3.4DE-3Ib/MMBtu AP -42 1.09 1.09 NO, 3 97E-02113/MM Btu Manufacturer 12.70 12.70 CO 6 51E-ozIb/MMBtu Manufacturer 17.61 17.61 VOC 2 10E-3 1b/MMBtu AP -42 0.67 0.67 Other: -0 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 250 lbs/year? ❑✓ Yes ❑ No If yes, use the following table to report the non -criteria pollutant [HAP} emissions from source: CAS Numbers Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (specify units) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions' (fbs/year) 50-00-0 Formaldehyde 0% 7.1DE-4Ib/MMBtu AP -42 454 454 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-20O - General APEN - Revision 1/2017 COLORADO e.,,.n,..a.i wtue ryury4i a Env lmnn.wn Permit Number: 11 WE 1481 AIRS ID Number: 123 /9012 1014 [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. 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, 11.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 Air Pollution Control Division APCD-55-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692.3150 Form APCD-200 - General APEN - Revision 1/2017 6 I All', COLORADO b4a,I'5onlel 1,60r innmen Bailer APEN - Form APCD-220 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. If your emission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www,colerado.govlcdjhefapcd. 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 exemptl permit exempt checklist: https:f /www-colorada ov/pacificfedphefopen-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: 11WE1481 AIRS ID Number: 123 / 9012 / 015 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: DCP Operating Company, LP Site Name: O'Connor 2 Gas Plant Site Location: Section 31, T5N, R64W Mailing Address: (Include lip Code) 370 17th Street, Suite 2500 Denver, CO 80202 E -Mail Address: RShankaran@DCPMidstream.com Site Location County: Weld NAICS or SIC Code: 1321 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 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 rovd. 374 Form APCD-220 - Boiler APEN - Revision 11/2017 1 I A*1 CQLan A6o Permit Number: 11WE1481 AIRS ID Number: 123 / 9012 / 015 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source - OR - ▪ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ 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: A 70% limit on annual fuel use is applied. 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: 9.3 MMBtu/hr regeneration heater, fueled by natural gas Manufacturer:'QP'E-- 14.O cc Model No.: TBD Company equipment Identification No. (optional): HT -01 For existing sources, operation began on: Serial No.: TBD 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 Seasonal use percentage: Dec -Feb: Mar -May: days/week weeks/year June -Aug: Are you reporting multiple identical boilers on this APEN? ❑Yes J No Sept -Nov: 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): Cf.., Form APCD-220 - Boiler APEN - Revision 11/2017 2 I MI co10Fl Apo Permit Number: 11WE1481 AIRS ID Number: 123 /9012/015 [Leave blank unless APCD has already assigned a permit ti and AIRS ID] Section 4 - Stack Information l' 40.362206/-104.587772 Geographical Coordinates (Latitude/Longitude or UTM) Operator Stack ID No. Discharge Height Temp. Above Ground Level ; e fJ (feet) l Flow Rate (ACFM) Velocity ant sec) HT -01 20 550 Indicate the direction of the stack outlet: (check one) LI Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack depth (inches): Section 5 - Fuel Consumption Information Design Input Rate (MMBTU/hr) Actual Annual Fuel Use4 (Specify Units) Requested Annual Permit Limit (Specify Units) 9.3 NA 54.31 MMscf/yr From what year is the actual annual fuel use data? 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: 1,050 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: LI Other (describe): Heating value (give units): 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. Form APCD-220 - Boiler APEN - Revision 11/2017 ICOLctRAOU Permit Number: 11WE1481 AIRS ID Number: 123 / 9012 / 015 [Leave blank unless APCD has already assigned a permit 4 and AIRS ID] Section 6- Criteria Pollutant Emissions Information Attach al( 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 efficien y (% reduction}: Pollutant Control Equipment Description Overall Control Efficiency (% reduction in emissions) TSP (PM) PM15 PMZ.s SO. NOx CO VOC Other: From what year is the following reported actual annual emissions data? Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary Fuel Type (natural gas, #2 diesel, etc.) Pollutant Uncontrolled I Emission I Factor Emission SourceFactor (Specify Units) I (AP -42, Mfg etc) Actual Annual Emissions Requested Annual Permit 4 Emission Limit(s)5 Uncontrolled (Tons/year) Controlled (Tons/year) Uncontrolled (Tons/year) Controlled (Tonslyear) TSP (PM) 0.005 Ib/MMBtu Manufacturer 0.14 0.14 PM10 , PM2 5 ' 5O< 0.005 Ib/MMBtu 0.005 Ib/MMBtu 0.6 Ib/mmscf Manufacturer 0.14 0.14 Manufacturer 0.14 0.14 AP -42 0.02 0.02 NOx 50 Ib/mmscf AP -42 1.36 1.36 CO 84 Ib/mmscf AP -42 2.28 2,28 VOC 5.5 lb/mmscf AP -42 0.15 0.15 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. Form APCD-220 - Boiler APEN - Revision 11/2017 41 iCOLOAA P4 Permit Number: 11 WE1481 AIRS ID Number: 123 / 9012 / 015 [Leave blank unless APCD has already assigned a permit II and AIRS ID] ❑ 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 Fuel Type (#2 diesel, waste oil, etc.) Pollutant Uncontrolled Emission Factor (Spetrfy Units) Emission Factor Source (AP_42 Mfs etc) Actual Annual Emissions Requested -Annual Permit 5 Emission Limit(s) Uncontrolled (Tons! ear y ) Controlled? (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) PM1 6 PM7.5 SO, 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: Pollutant Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled (Tons/year) Controlled (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) PMio PM2.5 SO. NO„ CO VOC Other: 5 Requested values will become permit limitations. Requested limitis) 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. Form APCD-220 - Boiler APB - Revision 11/2017 ,COLORADO • a 1.. Permit Number: 11 WE1481 AIRS ID Number: 123 / 9012 / 015 [Leave Nark unless APCD has already assigned a pemrilt #, and AIRS ID] Section 7 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) equal to or greater than 250 lbs/year? ❑ Yes ® No If ys, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (speeFfy units) Emission Factor Source (AP -41, Mfg. etc) Uncontrolled Actual Emissions Ohs/year) Controlled Actual Emissions? (ibs/year} Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 i�•a�co�on sga :i Permit Number: 11 WE1481 AIRS ID Number: 123 / 9012 / 015 [Leave blank unless APCD has already assigned 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. 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 ❑r 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: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692- 3148 Or visit the APCD website at: https://www.colorado.govicdphe/apcd Form APCD-220 - Boiler APEN - Revision 11 /2017 7 I /1k caLorreov .);Y L .' f / t R Boiler APEN -- Form APCD-220 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. if your emission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorsdo,gov/edhelkpcd. 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: lAtps llwww.colorado.onvlpacific_/cdphelacJen-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: 11 WE 1481 AIRS ID Number: 123 / 9012 / 01 6 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: O'Connor 2 Gas Plant Site Location: Section 31, T5N, R64W Mailing Address: ((ncrude Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 E -Mail Address2: RShankaran@DCPMidstream.com Site Location County: Weld NAICS or SIC Code: 1321 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 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 wilt require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 374098 Form APCD-220 - Boiler APEN - Revision 11/2017 COL 05 A6� ..t laid is Permit Number: 11WE1481 AIRS ID Number: 123 / 9012 / 016 {Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action l NEW permit OR newly -reported emission source OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership3 -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: ❑ Add point to existing permit ❑ Other (describe below) 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: 48.4 MMBtu/hr hot oil heater, fueled by natural gas Fir el- anufacturer: OP abl/tt6 Model No.: TBD Company equipment Identification No. (optional): For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: HT -02 Serial No.: TBD 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 Seasonal use percentage: Dec -Feb: Mar -May: days/week weeks/year June -Aug: Sept -Nov: Are you reporting multiple identical boilers on this APEN? I 1 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): 1 Form APCD-220 - Boiler APEN - Revision 11/2017 2 I R Ra [0iDRACC, Permit Number: 11WE1481 AIRS ID Number: 123 / 9012 / 016 [Leave blank unless APCD has already assigned a permit 11 and AIRS ID] Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.352206/-104.587772 Operator Stack ID No., Discharge Height Temp. Above Ground Level ' (•F) (Feet) Flow Rate (ACFM) - Velocity ffrrsec 1 HT -02 20 350 Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack depth (inches): Section 5 - Fuel Consumption Information Design Input Rate (MMBTUIhr) Actual Annual Fuel Use' (Specify Units) Requested Ann 5a! Permit Limit (Specify Units) 48.4 NA 403.79 MMscf/yr From what year is the actual annual fuel use data? Fuel consumption values entered above are for: ❑f 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: 1,050 BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 8T11/SCF) ❑ Coal Heating value: BTU/lb Ash content: Sulfur Content: ❑ Other (describe): Heating value (give units): 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 vatue, please provide this information in the "other" field. Form APCD-220 - Boiler ADEN - Revision 11/2017 cueoaaao 3 I Aig...:'.':,.. Permit Number: 11WE1481 AIRS ID Number: 123 / 9012 / 016 ,4 — 1e [Leave htank unless APCD has already assigned a permit # and AIRS !DI 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 If yes, ntease describe the control equipment AND state the overall control efficiencreduction): 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? Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary Fuel Type (natural gas, #2 diesel, etc.) Pollutant Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 - Uncontrolled (Tonslyear) Controlled (Tonslyear) Uncontrolled (Tons/year) Controlled (Tonslyear) TSP (PM) 0.005 Ib/MMBtu Manufacturer 1.06 1.06 PM10 0.005Ib/MMBtu Manufacturer 1.06 1.06 PM2.5 0.005 Ib/MMBtu Manufacturer 1.06 1.06 Sax 0.6 Ib/mmscf AP -42 0.12 0.12 NOx 50Ib/mmsef AP -42 10.09 10.09 CO 84 lb/rnmscf AP -42 16.96 16.96 VOC 5.5 Ib/mmscf AP -42 1.11 1.11 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. Form APCD•220 • Boiler ADEN - Revision 11/2017 4 I ay 'OLORaOD Permit Number: 11WE1481 AIRS ID Number: 123 / 9012/ 016 [Leave blank unless APCD has already assigned a permit k and AIRS ID] ❑ Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. ;e If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria emissions table below: Secondary Fuel Type (#2 diesel, oil, waste etc.) Pollutant Uncontrolled Emission (Specify Emission Factor (AP -42, Mfg. ) Actual Annual Emissions 1 (Tonslyear) Requested Annual Permit q Emission Limit(s)5 Uncontrolled (Tonslyear) Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) PM10 PM2.5 S Ox NOx CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: Pollutant Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Controlled'. (Tonslyear) (Tons/year) Uncontrolled (Tonslyear) Controlled (Tons/year) TSP (PM) PM1a PM2.s SOS NOs CO VOC Other: I 5 Requested values will become permit limitations. Requested limits) should consider future process growth. I Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 5 I h7 I:7 COLORADO ra Permit Number: 11 WE1481 AIRS ID Number: 123 / 9012 / 016 [Leave blank unless APCD has already assigned a permit !1 and AIRS ID] Section 7 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) equal to or greater than 250 lbs/year? ® Yes ❑ No If yes, use the following table to report the non -criteria pollutant {HAP} emissions from source: CAS Number Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (specify units) Uncontrolled Emission Factor Actual Source Emissions (AP -42, Mfg. etc) (lbsl ear y ) Controlled Actual Emissions (lbslyear) 110-54-3 n -Hexane 0 % 1.8 lb/MIVAsof AP -42 727 727 �Annua! emission fees will be based on actual controlled emissions reported. if source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 6 I Ie1O6OPAP4 Permit Number: 11 WE1481 AIRS ID Number: 123 / 9012 / 016 (Leave blank unless APCD has already assigned 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. L 114 12- o r 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 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: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-BI 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692- 3148 Or visit the APCD website at: hitps: / twww.coiorado,govlcclphc/aixd Form APCD-220 - Boiler APEN - Revision 11/2017 7 I n, COI,4RAoq Amine Sweetening Unit - Form APCD-206 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 Amine Sweetening 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.colaradclnovlcdphetapcd. 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: H [ 4-g AIRS ID Number: 12..5 /61611/00 [Leave blank unless APCD ilas already assigned a permit # and AIRS ID] Company equipment Identification: AM002 19 2011 [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: O'Connor 2 Gas Plant Site Location: Section 31, T5N, R64W Mailing Address: 370 17th St, Suite 2500 (include zip Code) Denver, CO 80202 E -Mail Address': RShankaran@dcpmidstream.com Site Location County: Weld NAICS or SIC Code: 1321 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 1Please use the full, legal company name registered with the Colorado Secretary of State, This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via email to the address provided. Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 ene 1 I 366330 COtopAna H.N ft Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action © NEW permit OR newly -reported emission source - OR /% MODIFICATION to existing permit (check each box below that applies) S\(‘° ❑ Change fuel or equipment ElChange company name �1 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 Et Notes: Acid gas stream from amine unit controlled by a RIO. During RTO downtime, emissions vented to atmosphere. s 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: Amine treating unit for CO2 removal Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: AMOO2 I I TBD / / ▪ Check this box if operating hours are 8,760 hours per year; if fewer, fillout the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Does this facility have a design capacity less than 2 long tons/day of HZS in the acid gas? Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/7017 days/week Yes Yes 2i AV weeks/year No No cotonAco Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: TBD Model : TBD Serial Number: TBD Reboiler Rating: Indirect MMBtu/hr Absorber Column Stages: Amine Type: ❑ MEA Pump Make and Model: TBD ❑ DEA ❑ TEA stages Q MDEA ❑ DGA # of pumps: 3 Sweet Gas Throughput4: Design Capacity: 230 MMSCF/day Requested: 83,950 MMSCF/year Actual: MMSCF/year 4 Requested values wilt become permit limitations. Requested limit(s) should consider future process growth Inlet Gas: Pressure: 900.5 psig Temperature: 78.14 Rich Amine Feed: Pressure: 895 psfa Temperature: 156 .F Flowrate: 1033.1 Gal/min Lean Amine Stream: Pressure: 932.3 psia Temperature: Flowrate: 945 Gal/min Wt. % amine: Mole Loading CO2 Mote loading H2S 6.1E-5 122 50 0.396 'F Sour Gas Input: Pressure: 900.55 psfa Temperature: 78.14 °F Flowrate: 230 MMSCF/Day NGL Input: Pressure: Flowrate: psia Gal/min Temperature: 'F Flash Tank: ❑ No Flash Tank Pressure: 72.33 psia Temperature: 1558 "F Additional Required Information: ✓❑ Attach a Process Flow Diagram ❑✓ Attach the simulation model inputs It emission report ❑ Attach composition reports for the rich amine feed, sour gas feed, NGL feed, a outlet stream (emissions) ❑ Attach the extended gas analysis (including BTEX Ft n -Hexane, H15, CO2, temperature, and pressure) Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 3 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or IITM) 40.352206/-104.587772 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. CO Flow Rate (ACFM) Velocity (ftlsec) AM002 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe). ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 4 1 ALVI COLoll ADO Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information VRU: Used for control of: Amine flash stream Size: TBD Make/Model: Requested Control Efficiency 100 VRU Downtime or Bypassed 3 ❑ Combustion ** r Device: Used for control of: Acid Gas Stream Rating: 4.09 Type: RTO MMBtu/hr y,•,od �a ia.,_v� Foy r�aar roloc o„y n,. �„im o�� g�s iowrale Make/Model: TBD Requested Control Efficiency: 96 Manufacturer Guaranteed Control Efficiency 99 Minimum Temperature: 550 Waste Gas Heat Content 12.5 Btu/scf s Constant Pilot Light: ❑ Yes 0 No Pilot burner Rating MMBtu/hr [] Other: Used for control of: Flash gas from flash gas vent Description: Control Efficiency Requested During VRU downtime, emissions routed to Plant Flare 95 ** During RTO downtime, acid gas stream emissions are vented to atmosphere. Maximum venting time of 146 hrs/yr. Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 5 IAN ICDLORADO I Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 -Emissions Inventory information Attach all emission calculations and emission factor documentation to this APEN form. is any emission control equipment or practice used to reduce emissions? ® Yes ❑ No If yes, ulease describe the control equipment AND state the overall control efficiency (% reductiorki_ Pollutant PM Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) SOX H2S NO, VOC RTO for amine acid gas / VRU for flash emissions (3% DT to Plant Flare) 96% / 100% (95% during DT) -- - CO HAPs RTO for amine acid gas / VRU for flash emissions (3% DT to Plant Flare) 96% / 100% (95% during DT) Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: I. Criteria Pollutant Emissions Inventory Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled (Tons/year) Controlled5 (Tons/year) Uncontrolled (Tons/year) Controlled (Torts/year) PM 50,E 0.7458 lb/MMScf ProMax - 31.30/--10.01 H2S 0.4159 lb/MMScf ProMax 17.46 0.69/a.29/1,69E-o4 NO„ 0.0680 Ib/MMBtu AP -42 1.33 1.22/--/0.11 VOC 17.2514 Ib/MMScf ProMax 724.13 6.68/2.78/0.84 CO 0.3100 lb/MMBtu AP -42 6.06 5.56/--10.50 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. Please note: The amine controlled emissions shown represent the following scenarios: S1: Acid gas routed to RTO S2: Acid gas to vent during RTO downtime (146 hr/yr) S3: Flash gas to flare during VRU downtime (3%) COL4A Aa4 Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 (continued) Non -Criteria Reportable Pollutant Emissions Inventory Pollutant Chemical Abstract Service (CAS) Number Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg, etc) Actual Annual Emissions Uncontrolled (lbslyear) Control[ed5 (lbs/year) Benzene 71432 1.6656 Ib/MMScf ProMax 139,826 7,323 Toluene 108883 0.7826 lb/MMScf ProMax 65,699 3,477 Ethylbenzene 100414 0.0287 Ib/MMScf ProMax 2,409 126 Xylenes 1330207 0.0588 Ib/MMScf ProMax 4,940 264 n -Hexane 110543 0.2179 Ib/MMScf ProMax 18,296 112 2,2,4- Trimethylpentane 540841 Other: 5A,mual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Applicant Certification [ 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) Roshini Shankaran -4-// glZoi- Date Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: Ei Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692.3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado. gov/cdphe/apcd Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 COLORADO 7 I Iii`..�Xa Glycol Dehydration Unit APEN - Form APCD-20?In. 2017 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 maybe 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.Rovlcdphe/aped. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: � � AIRS ID Number: (13 /q(jl 2,/ 01S" [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: O'Connor 2 Gas Plant Site Location: Section 31, T5N, R64W Mailing Address: (Include Zip Code) 370 17th St, Suite 2500 Denver, CO 80202 E -Mail Address2: RShankaran@dcpmidstream.com Site Location County: Weld NAICS or SIC Code: 1321 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-202 - Glycol Dehydration Unit APEN • Revision 02/2017 366331 yh� COLORADO II 1Sl rape; entekiom, 1 ii�iiiii H[atilkBF�wlionmrnk Permit Number: AIRS ID Number: / f [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ® NEW permit OR newly -reported emission source -OR - N MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name N 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 it 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 Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: D-01 / / 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 Will this equipment be operated in any NAAQS nonattainment area Is this unit located at a stationary source that is considered a Major Source of (HAP) Emissions Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 days/week Yes Yes 7 weeks/year No No COLORADO 2 l �y[ 7,� `Ma[V�7 bcpuho i-.ri��ic MroNh s 1 nr,,R...m Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: Dehydrator Serial Number: Glycol Used: TBD TBD Ethylene Glycol (EG) Model Number: TBD Reboiler Rating: Indirect ❑ Di Ethylene Glycol (DEG) Glycol Pump Drive: 0 Electric ❑ Gas If Gas, injection pump ratio: Pump Make and Model: TBD Glycol Recirculation rate (gal/min): Lean Glycol Water Content: 1.5 0 MMBTU/hr TriEthylene Glycol (TEG) Max: Requested: 40 Wt.% # of pumps: Acfm/gpm 1 (+1 BU) Dehydrator Gas Throughput: Design Capacity: 230 MMSCF/day Requested: 83,950 MMSCF/year Actual: MMSCF/year Inlet Gas: Pressure: 878 psig Temperature: 80 "F Water Content: Wet Gas: lb/MMSCF ❑✓ Saturated Dry gas: 1.6 lb/MMSCF Flash Tank: Pressure: 60 psig Temperature: 147 .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: Attach a Process Flow Diagram Attach GRI-GLYCaIc 4.0 Input Report a Aggregate Report (or equivalent simulation report/test results) Attach the extended gas analysis (including BTEX & n -Hexane, temperature, and pressure) Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO 3ilkY Permit Number: AIRS ID Number: I I [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.352206/-104.587772 Operator Stack ID No, Discharge Height Above Ground Level (Feet) Temp. (.F) Flow Rate (ACFM) Velocity (ftlsec) • D-01 120 Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Circular ❑ Square/rectangle ❑ Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap 16 Interior stack width (inches): Interior stack depth (inches): Form APCD-2O2 -Glycol Dehydration Unit APEN - Revision 02/2017 4 I � COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information Used for control of: 0 Condenser: Type: Make/Model: Maximum Temp Average Temp Requested Control Efficiency ❑ VRU: Used for control of: VOC and HAPs from still vent and flash tank streams Size: Make/Model: Requested Control Efficiency 100 % VRU Downtime or Bypassed 2 ❑ Combustion Device: Used for control of: VOC and HAPs from still vent and flash tank strearra Rating: MMBtu/hr Type: Plant Flare Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: Make/Model: Zeeco ! HSLF 95 Waste Gas Heat Content 1,716 Btu/scf Constant Pilot Light: ❑r Yes ❑ No Pilot burner Rating 0.20 MMBtu/hr Closed ❑ Loop System: Used for control of: Description: System Downtime ❑ Other: Used for control of: Description: Control Efficiency Requested VOC/HAP f/ still vent/flash tank (2% VRU DT only) Plant Flare 95 Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 5 I COLORADO u.putrneno of luny.. Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit N 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 officiency (% reduction), Pollutant Control Equipment Description Overall Requested Control Efficiency (N reduction in emissions) PM SO, 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? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled (Tons/year) Controlled (Tonsfyeor) Uncontrolled (Tonsfyeor) Controlled (Tons/year) PM SO, 3.72E-05 lb/MMscf Mass Balance -- 1.56E-03 NO,, 0.068 Ib/MMBtu AP -42 0.04 0.04 CO 0.310 lb/MMBtu AP -42 0.18 0.18 1.01 VOC 0.479 lb/MMscf GlyCalc 20.12 Benzene 0.072 Ib/MMscf GlyCalc 3.00 0.15 Toluene 0.068 lb/MMscf GlyCalc 2.87 0.14 Ethylbenzene Xylenes n -Hexane 2,2,4- Trimethylpentane 0.027 rb/MMscf GlyCalc 1.12 0.06 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 A. Y COLORADO Departmental Public Hpan a, I Permit Number: AIRS ID Number: f / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Authorized Person (not a vendor or consultant) Roshini Shankaran /r - Date Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: ,❑ Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-55-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692.3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 A///LLL COLORADO 7 I lSL PsP+�enld PoAk ��ZZiYYY NUL�SEnulmnm�nl Hydrocarbon Liquid Loading APEN - Form APCD-208 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Hydrocarbon Liquid Loading only. If your emission unit does not 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/aped, This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 11 WE1481 AIRS ID Number: 123/9012 IN / 1 [Leave Llank unless APCD has already assigned a permit it and AIRS ID] Company equipment Identification: LO -2 - Pressurized Condensate Unloading [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: Site Location: DCP Operating Company, LP O'Connor Plant Site Location Section 31, T5N, R64W County: Weld Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 E -Mail Address2: RShankaran@DCPMidstream.com NAICS or SIC Code: 1311 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 tUse 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. 370691 1 Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017 1 eot� COLORADO Permit Number: 11 WE1481 AIRS ID Number: 123/9012 / (Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source ❑✓ Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN Filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that apanes) ❑ Change fuel or equipment ❑ Change company name ❑ 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) Additional Info Et Notes: Requesting to permit increase in pressurized unloading of raw condensate. 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: Pressurized unloading of raw condensate, For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 10/ 19 /2013 / / Will this equipment be operated in any NAAQS nonattainment area? Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Does this source load gasoline into transport vehicles? Is this source located at an oil and gas exploration and production site? If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Does this source splash fill less than 6750 BBL of condensate per year? Does this source submerge fill less than 16308 BBL of condensate per year? Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 ✓❑ Yes ❑ No O Yes ❑ No ❑ Yes El No ❑ Yes EI No ❑ Yes ❑ No ❑ Yes ❑ No 7 Yes ❑ No i AV oCOLORADO 2 -,.ref . .h A Permit Number: 11WE1481 AIRS ID Number: 123/9012/ (Leave blank uniess APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: ✓❑ Condensate ❑ Crude Oil ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loader?: Bbl/yr iActual Volume Loaded: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth This product is loaded from tanks at this facility into: (eg, "rail tank cars" or "tank trucks") If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: True Vapor Pressure Average temperature of bulk liquid loading: Psia @ 60 °F Molecular weight of displaced vapors Lb/lb-mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume 1,460,000 Loaded5: Bbl/y r Loaded: 4 Requested values will become permit limitations. Requested limit(sl should consider future process growth Bbl/yr Actual Volume Product Density: 38.46 Lb/ft3 Load Line Volume: 0.0491 ft3/truckload Vapor Recovery Line Volume 0.0491 ft3/truckload iVw Form APCD-208 -Hydrocarbon Liquid Loading APED - Rev 02/2017 3 1 .. COLORADO Permit Number: 11 WE1481 AIRS ID Number: 123/9012/ [Leave blank unless APCD has already assigned a permit # and AIRS hD) Section 5 - Geographical Information Geographical Coordinates (Latitude/Longitude or UTM) 40.352206/-104.587772 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. (.F) Flow Rate (ACFfi) Velocity (ftlsec) LO -2 Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Section 6 - Control Device Information ❑ Loading occurs using a vapor balance system: Requested Control Efficiency 100 % ❑ Combustion Device: Pollutants Controlled: Rating: Type: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: MMBtu/hr Make/Model: Waste Gas Heat Content Btu/scf Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 4 I L31tr` COLORADO Permit Number: 11WE1481 AIRS ID Number: 123/9012/ [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 Q No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SO„ NO), CO VOC HAPs Other: ❑ Using State Emission Factors (Required for GP07) VOC 0.236 Lbs/BBL 0.104 Lbs/BBL ❑ Condensate ❑ Crude Benzene n -Hexane 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (nn -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)s . Uncontrolled (Tons/year) Controlled' (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM SOx NO), VOC 1.93 lb/load Eng. Estimate 8.45 8.45 CO Benzene 1.86E-02 lb/load Eng Estimate 0.08 0.08 Toluene 1.84E-02 lb/load Eng. Estimate 0.08 0.08 Ethylbenzene 9.65E-04 lb/load Eng. Estimate 0.00 0.03 0.00 0.03 Xylenes 5.81 E-03 lb/load Eng. Estimate n -Hexane 1.56E-01 lb/load Eng Estimate 0.68 0.68 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-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 5 I AA!' COLORADO 1 Nirr:raroni. Permit Number: 11 WE1481 AIRS ID Number: 123/9012/ [Leave blank unless APED has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. 10/2O/?DlI1- Sig ature 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 O Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No, 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250 as applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692.3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-208 Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 6 A r7 Li Hydrocarbon Liquid Loading APEN - Form APCD-208 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Hydrocarbon Liquid Loading only. If your emission unit does not 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,T3y/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: 11WE1481 AIRS ID Number: 123/9012 /020 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: LO -2 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: Site Location: DCP Operating Company, LP O'Connor Plant Site Location Section 31, T5N, R64W County: Weld Mailing Address: (inciudr•Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 E -Mail Address2: RShankaran@DCPMidstream.com NAICS or SIC Code: 1321 Permit Contact: Roshini Shankaran Phone Number: (303) 605-2039 'Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017 +� COLORADO 1 I ANT NaMeh e.,7! mo�i, Permit Number: 11 WE1481 AIRS ID Number: 123 /9012 /020 •1 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action O NEW permit OR newly -reported emission source 0 Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN Filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ 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) Additional Info It Notes: Condensate loadout for new O'Connor 2 Train 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: / 1 TBD/ 1 Will this equipment be operated in any NAAQS nonattainment area? Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Does this source load gasoline into transport vehicles? is this source located at an oil and gas exploration and production site? If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Does this source splash fill less than 6750 BBL of condensate per year? Does this source submerge fill less than 16308 BBL of condensate per year? 21 Yes 0 No O Yes ❑ No ❑ Yes 0 No O Yes 0 No ❑ Yes El No El Yes ❑ No ❑ Yes ❑ No Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 2I AT COLORADO K;N,"b nu oPni»f Permit Number: 11 WE 1481 AIRS ID Number: 123/9012/020 [Leave blank unless APCD has already assigned a permit # and AIRS ID] A 5 Section 4 - Process Equipment Information Product Loaded: ❑r Condensate ❑ Crude Oil ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Actual Volume Loaded4: 675,250 Bbl/yr Loaded: 4 Requested values wilt become permit limitations. Requested limit(s) should consider future process growth Bbt/yr This product is loaded from tanks at this facility into: (eg, "rail tank cars" or "tank trucks") Tank Trucks If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: 0. Average temperature of bulk liquid loading: 52.45 F True Vapor Pressure 5.0 Psia g 60 °F Molecular weight of displaced vapors 66 Lb/lb mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Actual Volume Loaded5: Bbl/yr Loaded: 4 Requested values will become permit limitations. Requested timitls► should consider future process growth Bbl/yr Product Density: Lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume ft3/truckload Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 3 I A CIF COLORADO Permit Number: 11 WE1481 AIRS ID Number: 123/9012/020 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Geographical Information Geographical Coordinates (Latitude/Longitude or UMM) 40.352206/-104.587772 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp Cr) Flow Rate iaCFM) Velocity (fttsec) LO -2 19 Indicate the direction of the stack outlet: (check one) ❑r Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Section 6 - Control Device Information ❑ Loading occurs using a vapor balance system: Requested Control Efficiency ❑ Combustion Device: Pollutants Controlled: VOC and HAPs Rating: MMBtu/hr Type: Enclosed Combustor Make/Model: TBD Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: 95 98 Waste Gas Heat Content 3,577 Btu/scf Constant Pilot Light: ✓❑ Yes ❑ No Pilot burner Rating 0.06 MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 � r COLORADO 4ItI Permit Number: 11 WE1481 AIRS ID Number: 123t9012/020 [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, describe the control equipment AND state the overall control efficiency (-0 reduction): DP Pollutant Control Equipment Description Overall Requested Control 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 ❑ Condensate 0.236 Lbs/BBL ❑ Crude 0.104 Lbs/BBL Benzene n -Hexane 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -.42, Mfg, etc) Actual Annual Emissions Controlled (Tons/year) Requested Annual Emission omit{s)s Permit Controlled - (Tons/year) Uncontrolled (Tons/year) Uncontrolled (Tons/year) PM sox NO, 0.138 lb/MMBtu TNRCC 0.79 0.79 VOC CO 0.202 lb/bbl AP -42 68.31 3.42 0.5496 lb/MMBtu TNRCC 1.41 1.41 Benzene 0.0027 lb/bbl Liquid Analysis 0.91 0.05 Toluene 0.0075 lblbbl Liquid Analysis 2.52 0.13 Ethylbenzene 0.0006 lb/bbl LquidAnalysis 0.19 0.01 Xylenes 0.0056 lblbbl Liquid Analysis 1.90 0,10 n -Hexane 0.0145 lblbbl LrquidAnaiysis 4.89 0.24 2' Trimethylpentane 1p 1.07E-05 lblbbl Liquid Analysis 3.52E-03 1.81 E-04 Other: 4 Requested values wilt become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 5 I Hr=r- Permit Number: 11 WE 1481 AIRS ID Number: 123/9012 / 020 [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. 1/2-120/3 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 [J Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250 as applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692.3148 Cr visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 AY COLORADO 6 Hery'almeMal➢uElk. 46 Fs.�..a„M�.�, Hello